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204-105
Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.03.28 15:38:43 - 08'00' Sean McLaughlin (4311) Sean McLaughlin 325-196 By Grace Christianson at 1:12 pm, Apr 02, 2025 10-407 DSR-4/2/25 SFD SFD SFD 4/3/2025 *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. JJL 4/7/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.07 15:17:23 -08'00'04/07/25 RBDMS JSB 040825 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: March 28, 2025 Re: N-07A Sundry Request (to replace expired approved sundry) Sundry approval is requested to set whipstock and mill window in well N-07A as part of the drilling and completion of the proposed N-07B CTD lateral. Proposed plan for N-07B Producer: Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line or coil will mill the XN- nipple. E-line will set a 4-1/2" packer whipstock. If unable to set the whipstock, the rig will perform that work. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. The rig will set the 4-1/2" packer 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 land in Zone 2. The lateral will continue in Zone 2/1 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 completely isolate and abandon the parent Prudhoe Pool perforations. 20 AAC 25.112(i) Variance Request: Hilcorp requests to plug the existing perforations via the liner cement job, packer whipstock and/or liner top packer, if the liner lap pressure test fails as an alternate plug placement. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in April 2025) 1. Slickline : Dummy WS drift. Caliper. DGLVs. 2. E-Line : Set Packer Whipstock* @ 10,180' 30 deg ROHS (if not possible, set with rig) 3. Coil : Mill XN nipple 4. Valve Shop : Pre-CTD Tree Work 5. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in May 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2500 psi). 2. Mill 3.80” Window. 3. Drill build section: 4.25" OH, ~174' (35 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2586' (12 deg DLS planned). 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr liner 6. Pump primary cement job: 37 bbls, 15.3 ppg Class G, TOC at TOL*. 7. Freeze protect well to a min 2,200' TVD. 8. Close in tree, RDMO. * alternate plug placement variance request per 20 AAC 25.112(i) Post Rig Work: 1. Slickline : SBHPS, set LTP* (if necessary). Set live GLVs. 2. Service Coil : Post rig RPM log and perforate (200’- 400'). 3. Tie In : Disconnect Injection lines, convert to production line and twin with N-30 w/ SSV eqpt. Trevor Hyatt CC: Well File Drilling Engineer (907-223-3087) Joseph Lastufka ,p This completion will completelyyp p g( p isolate and abandon the parent Prudhoe Pool perforations. Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3-1/8" Pipe / Slip Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip 1 Christianson, Grace K (OGC) From:Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Sent:Friday, March 28, 2025 3:48 PM To:AOGCC Permitting (CED sponsored) Cc:Trevor Hyatt Subject:PBU N-07A (PTD #204-105) 10-403 Sundry Request Attachments:PBU N-07A 10-403.pdf Follow Up Flag:Follow up Flag Status:Flagged Hello, This is a replacement for sundry #323-669 submitted in 12/2023 and approved 1/5/2024 (expired). Please let me know if you have any questions. Thanks! Thanks, Joe Lastufka Sr. Drilling Technologist Hilcorp North Slope, LLC Office: (907)777-8400, Cell:(907)227-8496 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. e Drilling Manager 12/13/23 Monty M Myers 323-669 By Grace Christianson at 4:08 pm, Dec 13, 2023 DSR-12/14/23SFD 12/15/2023 10-407 MGR05JAN24 BOPE test to 3500 psi. Variance to 20 AAC 25.112(i) Approved for alternate plug placement with fully cemented liner on upcoming sidetrack. All drilling within the reservoir. JLC 1/5/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.01.05 11:30:06 -09'00' 01/05/24 RBDMS JSB 010924 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: December 13, 2023 Re: N-07A Sundry Request Sundry approval is requested to set whipstock and mill window in well N-07A as part of the drilling and completion of the proposed N-07B CTD lateral. Proposed plan for N-07B Producer: Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line or coil will mill the XN- nipple. E-line will then set a 4-1/2" packer 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. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 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" packer 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 land in Zone 2. The lateral will continue in Zone 2/1 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 completely 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 the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in Dec 29th, 2023) 1. Slickline : Dummy WS drift. Caliper. DGLVs. 2. E-Line : Set Whipstock @ 10,180' 30 deg ROHS 3. Coil : Mill XN nipple and Window (if window not possible, mill with rig) 4. Valve Shop : Pre-CTD Tree Work 5. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in January 19, 2024) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2500 psi). 2. Mill 3.80” Window. 3. Drill build section: 4.25" OH, ~174' (35 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2586' (12 deg DLS planned). 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr liner 6. Pump primary cement job: 37 bbls, 15.3 ppg Class G, TOC at TOL*. 7. Freeze protect well to a min 2,200' TVD. 8. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post Rig Work: 1. Slickline : SBHPS, set LTP* (if necessary). Set live GLVs. 2. Service Coil : Post rig RPM log and perforate (200’- 400'). 3. Tie In : Disconnect Injection lines, convert to production line and twin with N-30 w/ SSV eqpt. Sundry 323-699 PTD 223-122 plugging the existing perforations via the liner cement job or liner top packer, 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. x Fluids >1% hydrocarbons or flammables must go to GNI. x Fluids >15% solids by volume must go to GNI. Hole Size: x The window and 10’ of formation will be milled/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 N pad is not an H2S pad. H2S reading on N-07A: 16 ppm on 10/1/2013. x Max H2S recorded on N pad: 96 ppm.. x 1 fault crossings expected. x Low lost circulation risk. Reservoir Pressure: x The reservoir pressure is expected to be 3381 psi at 8800 TVD. (7.4 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2500 psi. Ryan Ciolkosz CC: Well File Drilling Engineer (907-244-4357) Joseph Lastufka 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 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: 12/06/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231206 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 13-8 50133203040000 177029 11/15/2023 HALLIBURTON EPX NCIU A-17 50883201880000 223031 11/28/2023 HALLIBURTON RBT PBU 04-46A 50029224340100 223082 11/1/2023 HALLIBURTON RBT PBU 05-26A 50029219840100 201221 11/24/2023 HALLIBURTON PPROF PBU 06-20B 50029207990200 223075 10/18/2023 BAKER MRPM PBU D-01A 50029200540100 197078 10/31/2023 HALLIBURTON RBT PBU N-07A 50029201370100 204105 10/7/2023 BAKER SPN PBU P1-08A 50029223840100 202199 9/22/2023 BAKER SPN PBU P2-56 50029226100000 195162 11/14/2023 BAKER SPN PBU P2-57A 50029221830100 202214 11/1/2023 BAKER SPN Please include current contact information if different from above. T38205 T38206 T38207 T38208 T38209 T38210 T38211 T38212 T38213 T38214 12/6/2023 PBU N-07A 50029201370100 204105 10/7/2023 BAKER SPN Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.06 14:25:58 -09'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU N-07A Mill CIBP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-105 50-029-20137-01-00 10832 Conductor Surface Intermediate Tieback Liner Liner 9098 80 2598 7590 9974 1006 10745 20" 13-3/8" 9-5/8" 7" 4-1/2" 9036 34 - 114 32 - 2630 2045 - 9635 30 - 10004 9826 - 10832 34 - 114 32 - 2629 2045 - 8194 30 - 8512 8358 - 9098 10728 520 2670 4760 5410 / 7020 7500 None 1530 4930 6870 7240 / 8160 8430 10213 - 10639 4-1/2" 12.6# 13Cr80 28 - 9823 8712 - 8973 Structural 4-1/2" Baker S3 Packer 9767, 8307 9767 8307 Torin Roschinger Operations Manager Josh Stephens josh.stephens@hilcorp.com (907) 777-8420 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028282 28 - 8355 N/A N/A 1723 3377 50 75 1266 250 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:54 am, Oct 13, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.10.12 19:45:56 -08'00' Torin Roschinger (4662) DSR-10/13/23 RBDMS JSB 101723 WCB 3-14-2024 ACTIVITY DATE SUMMARY 9/30/2023 CT #9 w/1.75" 0.156" Coil Tubing - Job Scope: Schmoo-Be-Gone, Mill CIBP Travel to N-pad. MIRU, Weekly BOP test. Make up SLB BHA w/3.4" JSN. RIH dry drift, pick up hole, pumping SBG to nozzle. Start jetting SBG through tubing down to tag. Tagged at top of Perfs, 10218'. Could NOT jet SBG thru restriction. ***Continue WSR to 10/1/23*** 10/1/2023 CT #9 w/1.75" 0.156" Coil Tubing - Job Scope: Schmoo-Be-Gone, Mill CIBP POOH, Continue jetting SBG up to surface from tag @ 10218' (top of perfs). Could not jet past top of perfs with SBG Nozzle. LD SLB Tools, PU BOT 3.700" Junk Mill. Let SBG Soak ~3 hours in tubing. Flush tubing with 180 bbls KCl/SafeLube. RIH with BOT Mill. Tag plug at 10293 CTMD. Mill and push down to 10,728' CTMD. POOH while pumping. Pulled heavy at 10234, detained for 40 min. POOH to 10,000'. Attempt to dry drift tag in multiple spots but can pump and pass through easily. Bullhead 320bbbls KCL at 5bpm while POOH. Cap well with 46bbls diesel. L/D BOT milling BHA, RDMO ***Job Completed*** 10/2/2023 T/I/O = 182/18/0 LRS 72 Assist Slickline as Directed (RST / CNL / PNL) Pumped 20 bbls 180* Diesel followed by 83 bbls 200* Seawater down the TBG. ***Job Continued to 10-03-2023*** 10/2/2023 ***WELL S/I ON ARRIVAL*** (Rst / cnl / pnl) DRIFT w/ 34'x3 3/8" DUMMY GUNS w/ 3.66" SWELL RINGS TO 10,037' SLM(Possibly sitting down in dogleg) RAN MULTIPLE GAUGE RINGS & BAILERS AS DEEP AS 10,473' SLM RAN 2.25" LIB TO 10,472' SLM (Impression of metal trash) RAN 2.70" MAGNET TO 10,472'SLM (Recovered several small metal pieces) ***CONTINUED ON 10/3/23 WSR*** 10/2/2023 Assist Slickline - FREEZE PROTECT. Pump 2 bbls of 60/40 down FL. Tags hung, Slickline on location after departure. 10/3/2023 ***CONTINUED FROM 10/2/23 WSR*** (Rst / cnl / pnl) PUSHED OBSTRUCTION FROM 10,473'SLM TO 10,698' SLM w/ 4 1/2" BLB & 3.658" LRS PUMPED 20BBLS DSL, 175BLS WATER,39BBLS DSL FP RAN 3.5" MAGNET TO 10,218' SLM(Unable to work deeper) RAN 30'x2" DMY GUNS w/ 2.16" SWELL & 1.75" S.BLR TO TAG AT 10,715' SLM(No sample) ***WELL S/I ON DEPARTURE*** 10/3/2023 ***Continue Job from 10-02-2023*** Assist Slickline as directed (RST / CNL / PNL) Pumped 101 bbls (for total of 184 bbls) 200* Seawater into TBG to assist SL w/ B&F. Pumped 38 bbls Diesel into TBG for FP. SL in control of well and pad op notified upon LRS departure. 10/5/2023 Assist Eline with SPN log Job postponed Daily Report of Well Operations PBU N-07A CT #9 w/1.75" 0.156" Coil Tubing - Job Scope: Schmoo-Be-Gone, Mill CIBP RIHgg with BOT Mill. Tag plug at 10293 CTMD. Mill and push down to 10,728' CTMD Daily Report of Well Operations PBU N-07A 10/6/2023 ***WELL SHUT IN ON ARRIVAL*** (SPN) PT 3000 PSI RIH DRIFT MAX OD 2.85" MIRU BAKER RU BAKER SPN TOOL LOG 2 SPN PASSES FROM 10720' - 9970' BEGIN BORAX BASELINE PASS ***JOB CONTINUES ON 07OCT23 WSR*** 10/6/2023 T/I/O= 0/0/0 TFS unit 4 Assist Eline (SPN Log) Pumped 3 BBLS 60/40 followed by 665 BBLS KCL for SPN log, JOB CONTINUES ON 10-07-23 10/7/2023 ***CONTINUED FROM 6-OCT-2023 WSR*** FINISH THIRD MIXED PASS BORAX PASSES FIRST PASS 10,700' TO 10,000' SECOND PASS 10,700' TO 10,000' THIRD PASS 10,700' TO 10,000' T-BIRD PUMP 290 BBL KCL AND FP ***WELL S/I UPON DEPARTURE*** 10/7/2023 ***JOB CONTINUES FROM 10-06-23*** TFS UNIT 4 assist E-Line (SPN Log) Pumped 378 BBLS KCL, 196 BBLS Borax To assist Eline in Log. Freeze protected TBG with 29 BBLS Crude and 9 bbls 60/40. Eline in control of ell upon departure. FWHP= 0/0/0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 29, 2020 TO: Jim Regg P.I. Supervisor j� `� SUBJECT: Mechanical Integrity Tests 6 Hileorp North Slope, LLC N -07A FROM: Bob Noble PRUDHOE BAY UNIT N -07A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT N -07A API Well Number 50-029-20137-01-00 Inspector Name: Bob Noble Permit Number: 204-105-0 Inspection Date: 7/20/2020 ✓ Insp Num: mitRCN200721134939 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well N -07A Type Inj W - TVD 8307 Tubing 428 429 428 427 ' - PTD 2041050 Type Test SPT Test psi 2077 IA 101 2302 2231 -; 2220 - -- - BBL Pumped: 2.4 - — BBL Returned: 2 OA 169 - - 256 - 249 247 - --- --- Intmal 4YRTST p/F P Notes: Wednesday, July 29, 2020 Page 1 of I STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations a Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Convert to Injector Ed 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-105 3. Address: P.O.Box 196612 Anchorage, Development D Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20137-01-00 7. Property Designation(Lease Number): ADL 0028282 8. Well Name and Number: PBU N-07A 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 10832 feet Plugs : !�. measured 10279 feet 4,o, tr,, true vertical 9098 feet Junk measured feet j f: measured 9766 Effective Depth: measured 10279 feet Packer feet -��-i�r7 1. 5 ..0'6 true vertical 8774 feet Packer true vertical 9833 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 34-114 34-114 1530 520 Surface 2597 13-3/8"72#N-80 32-2630 32-2629 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10213-10227 feet 10539-10559 feet 10571-10596 feet 10606-10626 feet 10634-10639 feet True vertical depth: 8712-8726 feet feet 8929-8938 feet 8943-8953 feet 8958-8966 feet 8970-8973 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 28-9823 28-8355 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 684 158 1148 156 Subsequent to operation: 4823 100 658 14.Attachments:(required per 20 AAC 25 070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations RI Exploratory ❑ Development 0 Service H Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG m 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: 315-331 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature A 6,,,,,...1 ........_> Phone +1 907 564 4424 Date 8/15/16 Form 10-404 Revised 5/2015 L ��j I (/ RBDMS LV AUG 1 5 2016 Submit Original Only 6 • i 0000000 N ti .- CO N O CD CO 'Cr N- O Ln LC) O N LC) c1 ti N- r- 15 N o 0 0 0 0 0 0 L M M N- co co co • CO O) N CO ‘4- M r- ct CD 00 00 CO C) (` c- 00 Ln N W O O) Ln CO CO N LC) O M N N.- 00 00 O) 00 j I— CO O) N- V N '- LO O Lf) co co co M O CO M N N N- 00 GD OV N N M CO 63 CO 00 N 00 6) OD OO) D V 0 Q ti CO O) CO 0 N Q0 ct N 00 G) I M M M O C) 00 N Z N 00 O) Co a p C3 CD CO 0 CD 1 00 00 (D Z C �' C) M M 00 J OO 65 CO CA C15 mCO N 00 N y- y- N Mr- Ln N 1 1 CO O CD C) CO LU CD 00) C CO io CD LC) O O N- J N CO CA W W CC I— aO - - N U UJ LU W UD � OCOCtYtYZ Z Q W W W W m H D OD Z Z CDCDZzJJI-- • Packers and SSV's Attachment PBU N-07A SW Name Type MD TVD Depscription N-07A TBG PACKER 9766.2 8306.37 4-1/2" Baker S-3 Perm Packer N-07A PACKER 9832.97 8363.83 5" Baker ZXP Top Packer I • • L . o ,- 0 0) � � -0Z o a © w O a 10 -0 2 O j I o W J w e a, E , O ca 0 m E (I) I- o 3 — O < D CO cu * o sz - Z O 0 * _, -cl_ o Q o a) 'u) ' a) > oo � a) c0 m E L— z w ~ 15 w > o `� m o mom 0 w rn � Q g -o • W c = 0 Q ~ C') < .� u� Q c m u, 1-: a) O • CC # 0 o Q C') ° H o . o Q-_o a Q > o m °° 0 ©°�° 2 -onmo_.6-Loow . mw , N o i- = 22 :a, * N N 0w o 0 ( N \ a3i ami a J s a, a O- w L w O Q � � � E �' UQ rnm• N di J _ `� ,_ - c -,-, o_ D w V- \O N IZ _O U L L - Q C *k O ,- N • V' O M < 4) a) N Y6 (2 -0z N W < — U) 0 ° W ' D LL O 0 0 0 �- _c c o >.. ,_N c ��O I O o a, 6m0- so a, v) c _ rI Z U � � � C N -o D OO D - N c < ° c W w Q w O � � >, �^ `off — a) a) - tea) c C .� 2 2:-, co O 2 0 1— = E a) it o o oom o° 30 a 1_ acorn Q 2 v 2v- -- 73 a � �00 o co E10 sort -oH > Q00L0 O D m J L L 11 L M O a) -(I, V c W m _ < C N (n a) j ~ E O(130_--- c) fO O z _ ,_ J N. 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Lo / \ I R a \ \ o / 2 f $ 6 ƒ \ - 2 0 Cl) 0 c 6 0 c & — O 0 in . 0 f / $ % q �_ J E al � � & A 0. * \ / / \ 2 \ / � < = o n a o A / / / k# w .[ _\ 0 9 2 5 & > » ~ I a / 'I— N > / � 2 I � � / k� k / \ _) tO % \ 73- < \ \ < a) " E \ eI Eo Ct �\ / ƒ o 2 § 0 I / (1:1 2\ ¥ / R 0 E G 2 0 \ \ \ / G m ear m Cu D 0 / $ » 0 2 // / 2 / / 7 i _ \ / % $ C * m + = ® ae $ mot a3 / / 2 / e < o o � .2/ "0 -•-• - $ ƒ S / _ O f �� a) . k / 2 ) ƒ / ) E ƒ / 5 ƒ O § � w k ? / 2 •- “, t2 a / - 0 > g e a 6 0 6 y / $ — = m : - 6 .g m 5 2 % o I r 0 0 N N / $ n & " mr \ ƒ / � = � � ^ � ^ R R 1 TREE= 4'FMC VVI3_LFEAB= MCEVOY N -07A -O7IkTY NOTES:***4-1/2"CHROME TBG*** ACTUATOR= BAKER INITIAL KB.ELE 61.40' BF.ELEV= 41.84' KOP= 3100' Max Angle= 66'©10568' Datum MD= 10401' Datum TVD= 8800'SS 2045 H 9-5/8"PBR I 2119' H4-1t2"FES X NP,D=3.813" 13-3/8"CSG,72#,14-80,D=12.347" — 2617' A ► 4 ^2600' —{EST.TOC OF 9-5/8"X 7"ANNULUS ► 4 GAS LFT MANDRELS ► L i 1ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID =3.725" C@ 9811' ► 4 4 3315 3309 13 KBG-2 DMY BK ' 0 05/21/16 4-112" HHES XN NIPPLE ; 3 6313 5578 47 KBG-2 DMY BK ` 0 05/21/16 ► 2 8434 7190 34 KBG-2 DMY BK 0 07/23/04 ► 4 1 9677 8230 31 KBG-2 OMY BK ' 0 07/23/04 4 7"SCAB LNR,26#,L-80,.383 bpf,D=6.276" H 8921' ► 4 TOP OF 7"LNR -- 8924' • 8931' H9-5/1r X 7"UNQUE OVERSHOT 9-5/8'CSG,47#,L-80,0=$.6$1" —{ 9635' I 9746' —4-1/2"FES X NP,D=3.813" C e 9767' —{7"X 4-1/2"BKR S-3 PKR,D=3.875" I 9790' —4-1/2-FEBX NP,D=3.813" I 9811' H 4-112'FES XN NP,D=3.725" 4-1/2"TBG, 12.6#,13CR-80,.0152 bpf,D=3.958" H 9824' 9824' —4-1/2"VWEG,D=3.958" r 9826' ---17"x5*BKR ZXP LNR TOP PKR&HNGR,D=4.42' PERFORATION SUMMARY REF LOG:SLB RST/SIGMA ON 08/04/04 N 9846' I—5"X 4-1/2'XO,D=3.960" ANGLE AT TOP PERF:14°a 10213' Note:Refer to Production DB for historical pert data MLLOtJT{MNDOW 10004'-10031' SIZE SPF I4TERVAL Opn/Sqz SHOT SOZ 2-7/8" 6 10213-10227 0 11/24/15 ` 10279' —�4 1/2"HESCBP(11/25/15) 3-318" 6 10539-10559 S 08/10/04 09/14/13 3-3/8" 6 10571-10596 S 08/10/04 09/14/13 ( I J / OI 10479' —14-1/2"MARKER JNT 2-7/8" 6 10606-10626 C 09/21/13 ►—� �S �� 3-3/8" 6 10634-10639 S 08/10/04 09/14/131 , ' �_ S *PB FS 10213-10227 GASB)ON REF LOG:SLB RESISTIVITY Um 1 LOG ON 07118104 U I 3-1/2"TBG,9.3#,N-80,D=2.992" H 10486' ak `liWir ' PBTD — 10633' WA•... �.a.a.a.a.a.a.a.4AllklliV [7"LNR,29#,N-80,D=6.184' — 10642' •ume PBTD l 10745' '`"f 4-1/2"LNR 12.6#,L-80,.0152 bpf,ID=3.958' — 10832' DATE REV BY COMMENTS DATE REV BY OOMvEJTS PRUDHOE BAY UNT 01/24/77 ORIGINAL COMPLETION 05/25/16 GF/JI D GLV C/O(05/21/16) WELL: N-07A 03121/89 IMO FEAT Nb:"2041050 07/23/04 JAFITCH SIDETRACK(N-07A) API No: 50-029-20137-01 11/25/15 CJNYJMD GLV C/O(11/22/15) SEC 8,T11 N,R13E,2219'FSL&571'FVVL 12/03/15 MRDA D ADPERFS&SET CEP(11/25-26/15) 04/19/16 JMAMJMD GLV 00(04/18/16) BP Exploration(Alaska) • I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,July 20,2016 Jim Regg P.I.Supervisor �&1G� 7/7,1-(/(,,, SUBJECT: Mechanical Integrity Tests / BP EXPLORATION(ALASKA)INC. N-07A FROM: Matt Herrera PRUDHOE BAY UNIT N-07A Petroleum Inspector Src: Inspector Reviewed By:e P.I.Supry 32-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT N-07A API Well Number 50-029-20137-01-00 Inspector Name: Matt Herrera Permit Number: 204-105-0 Inspection Date: 7/16/2016 Insp Num: mitMFH160716185745 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well N-07A - Type Inj 1 W 1TVD 5307 - Tubing 804 804 747 690 PTD 2041050 " Type Test SPT Test psi 2076.75 . IA 257 2480 , 2434 — 2415 Interval f 1rMITA P/F P ./ OA 10 72 - 88 109 , 1 I Notes: Initial MIT for well converted to injector.2500 PSI test pressure per Operator.Operator also directed to monitor for possible correlation ✓ between IA loss and OA gain Wednesday,July 20,2016 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, June 28, 2016 6:35 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, GWO SUPT Special Projects; AK, GWO SUPT Slickline; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad MN; Morrison, Spencer; 'chris.wallace@alaska.gov'; Wellman, Julie Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; McVey, Adrienne; Regg, James B (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel, Troy; Worthington, Aras J Subject: OPERABLE:Injector N-07A (PTD #2041050) High Pressure Breakdown Complete All, Injector N-07A(PTD#2041050) high pressure breakdown was completed June 18th 2016 .A passing MIT-IA conducted May 21, 2016 demonstrates two competent well barrier envelopes.The well is now classified as Operable and may be placed on injection. Plan Forward: 1. Operations: Put on Produced Water Injection 2. Fullbore: AOGCC MIT-IA once thermally stable Please use caution and anticipate annular fluid expansion during well startup. Please call with any questions or concerns, Thanks, Ryan Holt Well Integrity—GWO Alaska (Alternate: Lee Grey) Office: (907)659-5102 SCANNED JUN Email: AKDCWellIntegrityCoordinator@ BP.com 8 2016. From: AK, D&CWell Integrity Coordinator Sent: Sunday, May 22, 2016 To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M FI A! OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad MN; Morrison, Spencer; 'chris.wallace@alaska.gov' \, Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engine K, OPS FF Well Ops Comp Rep; McVey, Adrienne; 'Regg, James B (DOA) (iim.regg@alaska.gov)'; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, Aras J Subject: NOT OPERABLE: Injector N-07A (PTD #2041050) Awaiting High Pressure Breakdown to Establish Injectivity All, i • 110 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, May 22, 2016 7:13 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad MN; Morrison, Spencer;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; McVey, Adrienne; Regg,James B (DOA); Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel, Troy;Worthington, Aras J Subject: NOT OPERABLE:Injector N-07A (PTD #2041050) Awaiting High Pressure Breakdown to Establish Injectivity All, Injector N-07A (PTD#2041050)was converted from producer to injector in November 2015, but failed to take fluid during an injectivity test.A plug was set to isolate the existing perforations, and 14' of new perfs were added uphole. The well still failed to take fluid. Well flowback was attempted to a portable test separator in order to clean up the perf tunnels. During flowback, the well failed to produce more than nominal rate and was shut in on May 4th, 2016. On May 9th, 2016 sustained casing pressure over MOASP was reported, with the inner annulus pressure at 2120 psi. The TxIA communication that resulted in sustained IA pressure above MOASP was resolved by setting dummy gas lift valves, and a passing MIT-IA was performed on May 21St, 2016, confirming two competent wellbore barriers. However, the well still has no injectivity. The well is reclassified as Not Operable. A high pressure breakdown will be attempted in order to establish injectivity. If successful,the well will be reclassified and brought online, and will require an AOGCC-witnessed MIT-IA once stabilized injection is established. Work Completed/Plan Forward: 1. Slickline: Install live gas lit valves—DONE 04/18/16 2. Well Test: Flowback—DONE 05/4/16 SCANNED MAY 2 5 2016 3. Downhole Diagnostics:TIFL—FAILED 05/11/16 4. Slickline: Set Dummy GLV's—DONE 05/20/16 5. Fullbore: Assist Slickline, perform MIT-IA to 2890 psi—PASSED 5/21/16 6. Fullbore: High Pressure Breakdown 7. Operations: Put on produced water injection 8. Downhole Diagnostics: AOGCC-witnessed MIT-IA Please reply if in conflict with proposed plan. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) Office: (907)659-5102 1 • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, May 09, 2016 5:27 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad MN; Stone, Christopher; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Munk, Corey; McVey, Adrienne; Odom, Kristine; Morrison, Spencer; AK, D&C Well Testing WSL; Regg, James B (DOA); AK, D&C Well Integrity Coordinator Subject: UNDER EVALUATION (UPDATE):Injector N-07A (PTD #2041050) SUSTAINED CASING PRESSURE INNER ANNULUS OVER MOASP All, Injector N-07A (PTD#2041050) was converted from producer to injector in November 2015, but failed to take fluid during an injectivity test. A plug was set to isolate the existing perforations, and 14' of new perfs were added uphole. The well still failed to take fluid. Well flowback was attempted to a portable test separator in order to clean up the perf tunnels. During flowback, the well failed to produce more than nominal rate and was shut in on May 4th 2016. On May 9th, 2016 sustained casing pressure over MOASP was reported with the inner annulus pressure at 2120 psi. The well remains reclassified as Under Evaluation. Suspected tubing by inner annulus pressure communication will be resolved in conjunction with continuation of well work intervention to establish injectivity. It will require an AOGCC- witnessed MIT-IA prior to being re-classified as Operable. Plan Forward: 1. Slickline: Install live gas lit valves—DONE 4/18/16 2. Well Test: Flowback—DONE 5/4/16 3. DHD:TIFL 4. Further diagnostics as required. 5. Operations: Put on produced water injection ��N�E� JUi'J 2, 0 ZQ�� 6. Fullbore: AOGCC-witnessed MIT-IA Please reply if in conflict with proposed plan. Thank You, Jack Lau (-1lternate:)Adrienne McVey BP Alaska-Well Integrity Superintendent W: 907.564.5102 C: 907.943.0296 H: x2376 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Friday, February 26, 2016 4:02 PM To: Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; Parks, Kevin D;Vohra, Prachi Subject: Injector N-07A (PTD #2041050)Injector Conversion Chris, Per our conversation earlier today,water Injector N-07A(PTD#2041050) is a well that has been recently converted from a producer to a water injector.The well was perforated on November 25, 2015, however a subsequent injectivity test was unsuccessful.The plan forward is to produce the well for up to 4 weeks to clean the zone of debris with a well test unit,taking flow returns down an adjacent well's flow line, The production rates will be turned into the state for appropriate allocation and then the well will be returned to injection.The well is not perceived to have any downhole integrity issues, as an internal MIT-IA to 4,000 psi passed on November 22, 2015 post conversion. Once well has a stable injectivity pattern, an AOGCC witnessed MIT-IA will be performed for compliance testing. Please call with any questions. Thank you, Kevin Parks (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator Global Wells GW Organization Office: 907.659.5102 WIC Email:AKDCWeIllntegrityCoordinator@bp.com SCANNED MAR 1 7 2016 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, January 19, 2016 11:08 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;Vohra, Prachi;AK, OPS Well Pad MN;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Sayers, Jessica; Dickerman, Eric; Regg,James B (DOA);AK, D&C Wells Fullbore Coordinator Subject: NOT OPERABLE:Injector N-07A (PTD#2041050)Injector Conversion All, Injector N-07A(PTD#2041050)was recently converted from Producer to WAG injector under Sundry#315-331. Due to low injectivity, this well is currently unavailable to be placed on injection. The well has been reclassified as Not Operable and added to the Quarterly Not Operable Injector report until ready to be brought online for updated AOGCC state testing. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) SCANNED MAY 2 7 2316 BP Alaska-Well Integrity Coordinator G\&„ WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com 1 Af—o o' — /05— Loepp, Victoria T (DOA) From: Bailey, Denise G <denise.bailey@bp.com> Sent: Thursday, June 25, 2015 2:18 PM To: Loepp, Victoria T (DOA) Subject: Clarification to Sundry#315-330, 315-331 &315-332 Follow Up Flag: Follow up Flag Status: Flagged When I submitted the 10-403's& associated documents for the conversion of N-01A, N-07A& N-27 from producers to injectors, it specified that the AOGCC witnessed MITIA will be at 4000 psi. This was incorrect-the AOGCC witnessed MITIA will be at 2500 psi. Please advise if this affects the sundry approval and/or what additional documentation you need. Thanks, Denise Bailey H,N, D&Q Pad Engineer (907)564-4749 denise.bailey@bp.com 9, 12O\5 II 1 pF TH �wP��\����s THE STATE Alaska Oil and Gas „�,;, ALASKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 LAS11P 2 SCANNSCANNED 0 2015 Fax: .alas a.g5 v ED JULt1 8 www.ao cc.alaska. ov Denise Bailey Pad Engineer BP Exploration (Alaska), Inc. c2 O P.O. P Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU N-07A Sundry Number: 315-331 Dear Ms. Bailey: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this/r day of June, 2015 Encl. RECEIVED STATE OF ALASKA MAY 2 7 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION IF A16\6 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown❑ Suspend❑ Perforate❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program❑ Plug for Redrill El Perforate New Pool❑ Repair Well El Re-enter Susp Well El Other: Convert to Injector - H 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: BP Exploration(Alaska), Inc. Exploratory ❑ Development ❑ 204-105-0 - 3.Address. Stratigraphic H Service H 6.API Number: P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20137-01-00 - 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? _ PBU N-07A - Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028282 ' PRUDHOE BAY, PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10832 . 9098 ' 10745 9036 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#H-40 32.74-112.74 32.74-112.74 Surface 2585 13-3/8"72#N-80 32.24-2617.15 32.24-2616.83 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner See Attachment • See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: 'Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 28.45-9812.41 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program H BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 5 y ii a p 15 OIL ❑ WINJ H WDSPL ❑ Suspended ❑ 16.Verbal Approval: "r Date: GAS ❑ WAG ❑ . GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown [' Abandoned ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Denise Bailey Email Denise.Bailey©BP.Corn Printed Name Denise Bailey Title Pad Engineer i Signature /�! I Phone 564-4749 Date SP 7)1S Prepared by Garry Catron 564-4424 COMMISSION USE ONLY 1 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315- 33l Plug Integrity ❑ BOP Test LJ Mechanical Integrity Test ii., Location Clearance ❑ Other: ;fGv/G ietrifr e-53 rel /✓LCT- /A ' "- d 4f f - -- Sfa6i /ii .-, �G/ ✓ e'c fig 1 Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: /D 4D 4 i / APPROVED BY /// �y`J /� Approved by: COMMISSIONER THE COMMISSION Date: (� / (i'TL 6, //G / - ORIGINAL 5ORIGINAL 7,,. , ,. b - `r Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date ot�j proval. Submit Form and Attachments in Duplicate — RBDMS-3 JUN 2 5 2015 6 o� r 0 0 a (z) o D c0 voocovcoa? U � = J J M J Z M d) Q O O O O O O O co (NI CO O N I� O p LU N- r` N N- U • CD 0 0 0 0 0 0 L M N- CO CO CO M D u) N CO v o) v co — N COcoaovo0 (L) N CO O N N- O CO O O CA V Q CO N O LO CO co N- co o) CO N CO I- Q O C) CO O ~ co CD LC) Lc) CD N CO Q CO CO O CO CO M N N co f- >, H- L • N co a) C N M O M g- aQ Co c- 00 O O M N Q `- co 6) O N O Q C1 O • Q F- co O LU N (N co U Q M M O co O) M N N O CO O O CO O C2 CD O c M CO J Z CO N CO N- CO CV - N N r N ao N N M N O r-- �' O a) o to to V' O) O CO CD in a) co 00 0) LC) O CD LC) 1"-- CO OO r- <- N O) Wct F— Q Q CHQQ W caD QU O Q Cr CC CC C Z Z W W W W m O ~ ~ Z Z D J U Z Z J J (n H Perforation Attachment ADL0028282 Well Date Perf Code MD Top MD Base TVD Top TVD Base N-07A 9/14/13 SQZ 10539 10559 8929 8938 N-07A 9/14/13 SQZ 10571 10596 8943 8953 N-07A 9/21/13 APF 10606 10626 8958 8966 N-07A 9/14/13 SQZ 10634 10639 8970 8973 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0028282 Well Facility Type MD Top Description TVD Top N-07A PACKER 9767 4-1/2" Baker S-3 Perm Packer 8307 N-07A PACKER 9834 5" Baker ZXP Top Packer 8364 Area of Review PBU Wells N-01A (API No: 50-029-20079-01) N-07A (API No: 50-029-20137-01) N-27 (API No: 50-029-233656-00) This Area of Review is required prior to the conversion of N-01A, N-07A and N-27 from producers to WAG injectors. This AOR discusses wells within 1/4 mile of each well's entry point into the Sag River formation. Current Status: N-01 A is currently an operable producer. The last well test on 05/02/2015 indicated 590 bopd, 57% watercut, and 21,281 scf/bbl GOR. N-07A is currently an operable producer. The last well test on 10/06/2013 indicated 0 bopd, 100% watercut. N-27 is currently an operable producer. The last well test on 04/26/2015 was 655 bopd, 28%watercut, and 33,962 scf/bbl GOR. All three of these wells are scheduled to be converted to WAG injectors in 2015 as part of the N-pad UZI (Updip Zone 4 Injection) Project. The UZI Project targets remaining oil where the gas cap has expanded into zone 4, and the gravity drainage process is less efficient. The UZI Project achieves improved recovery through pattern injection of water and/or MI. The area of UZI potential is generally identified as immediately upstructure of the existing WF/EOR area. If planned facility work to install MI and water injection headers is completed as scheduled, N-07A will be ready for injection as early as Q3 and N-01 A and N-27 in Q4 2015. N-01 A N-01A Completion: N-01A is a conventional (max angle is 68°) well that was sidetracked in September 2004 in zone 4. It was side-tracked with future UZI injection potential in Z4. It is currently being pre-produced while waiting for approval and construction of the UZI project. N-01 A is completed with 4-1/2", L-80 tubing (wellbore schematic Figure 1). To convert it to an injector, a plug will be set above the existing zone 4 perforations to ensure zonal isolation and new perforations will be shot in the bypassed oil lens in zone 4. The original well was drilled in 1970 and it was sidetracked in 2004. A CBL shows that the cement behind the original 9-5/8" casing was poor. However during the sidetrack in 2004, a new 7" liner was installed from 8,968'MD to 7181' MD' with a 7" scab liner cemented in place from 7181' to 2426'MD. The liner was cemented with 35 bbls of 15.8 ppg Class G cement. The estimated TOC is 7,884'MD. There are no cement bond logs for this section of pipe, but no abnormalities occurred with this cement job. pp 4-1/2"tubing was installed from surface to TD @ 9748'MD. It was cemented with 27 bbls of 15.8 ppg Class G cement. No abnormalities occurred with this cement job although—15 bbls were circulated back to surface. Operation of N-01A as a WAG injector is not seen as an issue as long as the well passes an MIT-IA. The most recent integrity tests are: Dec. 22/2012—MIT-T to 2,500 psi passed(plug @ 8,807'MD) 12/21/2012—MIT-IA to 2,500 psi passed 1/29/2004—MIT-OA to 2,500 psi - passed N-01A Area of Review The wells within 1/4 mile of N-01 A are listed in the table below. The measurements were made at the closest points between the wells within the Prudhoe Oil Pool. Three individual wells (including the N-01 parent) enter the AOR and the tables below summarize conditions. PBU Well API Number Distance Annulus integrity Name (ft) N-01A 50-029-20079-01 ---- TOC calc to be above injection zone behind 7" N-01 50-029-20079-00 1010 7/24/1974 CBL indicated fair cement quality above the Sag. The cement was poor quality in most places - however there was a good section (50') of cement existing (between 8,660- 8,710), combined with production history that had no evidence of barium scaling (which would be indicative of communication with the Cretaceous). These factors indicate zonal isolation. N-14B- 50-029-20594-70 1230 Only plugback is in AOR & it was cemented. PB1 However the TOC for the 7" liner of the parent well is calc to be above injection zone N-17 50-029-20898-00 1280 TOC calc to be above injection zone behind 9- 5/8" Well Name Csg Hole Volume of Cement Csg Top of size Size shoe Sag (MD) depth (MD) N-01A 7" 8-1/2" 35 bbls of 15.8 ppg Class G 8,968 8,957 N-01 9-5/8" 12-1/4" 9,309 8,613 82 bbls of Class G cement 310 bbls Class G gel N-14B-PB1 7" 8-1/2" PB: 8 bbls of 17 ppg class G 9,405 9,524 7" Liner: 59 bbls of premium Class G 15.7 ppg N-17 9-5/8" 12-1/4" 206 bbls 15.8 ppg Class G 8,720 8,758 23 bbls 15.7 ppg Arctic Set I NOTE: All calculated TOC's assume 30%washout of hole. N-07A « �// �e.fG11i` �Al, ftN-07A Com letion: 52- eD�Gv✓• ��,He1 P Ioy�'C oiofred ?4-f ,%r�QCf,va �iO���r "11 6'4/4— N-07A is a conventional (max angle is 66°) well that was sidetracked in July 2004 in zone 2B and 2C. It was side-tracked with future UZI injection potential in Z4, and was pre-produced while waiting for approval of the UZI project. N-07A was online as a producer from 2004 until 2013 when it reached high GOR. An unsuccessful squeeze was attempted in mid-2013 and the well has been offline since. N-07A is completed with 4-1/2", 13-Cr tubing & 4-1/2", L-80 liner(wellbore schematic Figure 2). To convert it to an injector, a plug will be set above the zone 2 perforations to ensure zonal isolation and new perforations will be shot in the bypassed oil lens in zone 4. The original well was drilled in 1974 and it was sidetracked in 2004. CBL's were run in 1974 and 1985. Both confirmed good cement for the 9-5/8" casing above 10,150'MD, with the TOC above 9,650'MD. The 9-5/8" casing was cemented with 1270 sacks of Howco Light cement and 41 bbls of Class G cement. As part of the July 2004 sidetrack, a 7" scab liner was installed from surface to 8,921' MD. This was cemented with 106 bbls of 12.5 ppg Litecrete followed by 57 bbls of 15.8 ppg Class G cement. A 4-1/2" L-80 liner was run from 9,826' to 10,832'MD and cemented with 27 bbls of 15.8 ppg Class G cement. No cement bond logs were run in the liner as the tubing wasn't pulled. However a Borax log to look for channeling was run in 2006 and it indicated some channeling around the current perforations only. Operation of N-07A as a WAG injector is not seen as an issue as long as the well passes an MIT-IA. The most recent integrity tests are: 7/7/2013 MIT-IA to 2500 passed 9/17/2013 —cmt sqz— MIT-T to 1500 psi passed 7/22/2004 - MIT-T to 3500 psi passed 3/24/2001 —MIT-OA to 1500 psi passed N-07A Area of Review The wells within 1/4 mile of N-07A are listed in the table below. The measurements were made at the closest points between the wells within the Prudhoe Oil Pool. Two individual wells (including the N-07 parent) enter the AOR and the tables below summarize conditions. PBU Well API Number Distance Annulus integrity Name (ft) N-07A 50-029-20137-01 3/29/85 CBL indicated TOC above 9,650'MD with a good bond N-07 50-029-20137-00 95 3/29/85 CBL indicated TOC above 9,650'MD with a good bond N-20A 50-029-21320-01 600 The 9-5/8" casing doesn't have good cement (according to CBL) in the N-20 parent wellbore. However the casing and parent wellbore is outside the AOR. Only the liner of N-20A sidetrack is in the AOR. There are no CBL's or Borax logs to show quality of cement in liner- however after 11 years of production, the well is still competitive and there's no communication with the GOC in the heel. This means that the -2000' of cement(based on volumes pumped) above top perfs provides isolation from the heel (and thus parent well). Well Name Csg Hole Size Vol Cement Csg Top of size shoe Sag (MD) depth (MD) N-07A 7" 8-1/2" 41 bbls of Class G 10,642 10,005 1270 sacks of Howco Light N-07 7" 8-1/2" 41 bbls of Class G 10,642 9,998 1270 sacks of Howco Light N-20A 4-1/2" 6" 70 bbls of Class G cement 12,585 9,315 NOTE: All calculated TOC's assume 30% washout of hole. • N-27 N-27 Completion: N-27 is a conventional (max angle is 26°) well that was rotary drilled and completed in November 2007 in zones 3 & 4. It was drilled with future UZI injection potential in Z4 ' and was pre-produced while waiting for approval of the UZI project. N-27 is completed with 4-1/2", 13-Cr tubing and 4-1/2", L-80 liner(wellbore schematic Figure 3). To convert it to an injector,the wireline retrievable plug (set in 2008 to isolate water in zone 3 perfs) will be pulled if possible, a new plug will be set above the existing zone 4 perforations (to ensure zonal isolation) and new perforations will be shot in the bypassed oil lens in zone 4. When the well was drilled and completed in 2007, a 4-1/2" L-80 liner was run from 8,795 to 9,503'MD and cemented with 24 bbls of Class G cement. The 7" casing was run from 26' to 8,967'MD and cemented with 132 bbls of 12 ppg Lite Crete and 38 bbls of 15.8 ppg Class G. A CBL was run on September 12, 2007 in the 7" casing and it indicated an adequate cement bond with the TOC at 6,350'MD. A subsequent CBL run on November 28, 2007 showed a good cement bond in the liner. Operation of N-27 as a WAG injector is not seen as an issue as long as the well passes an MIT-IA. The most recent integrity tests are: 8/16/2011 MIT-IA to 3000 psi passed 7/9/2011 —MIT-OA to 1200 psi passed No MIT-T N-27 Area of Review The wells within 1/4 mile of N-27 are listed in the table below. The measurements were made at the closest points between the wells within the Prudhoe Oil Pool. Two individual wells enter the AOR and the tables below summarize conditions. PBU Well API Number Distance Annulus integrity Name (ft) N-27 50-029-23365-00 9/12/2007 CBL indicated TOC @ 6,350'MD with an adequate bond N-16 50-029-20886-00 710 TOC calc to be above rejection zone behind 9- 5/8". — N-30 50-029-23523-00 1200 TOC calc to be above injection zone behind 7" Well Name Csg Hole Vol Cement Csg Top of size Size shoe Sag (MD) depth (MD) N-27 7" 8-1/2" 132 bbls of Litecrete&38 bbls of 8,967 8,964 Class G N-16 9-5/8" 12-1/4" 296 bbls Class G with gel 13.2 ppg 9,686 9,688 102 bbls Class G 15.8 ppg 23 bbls Arcticset 15.7 ppg N-30 7" 8-1/2" 47.3 bbls 15.8ppg Class G 9,151 9,150 NOTE: All calculated TOC's assume 30%washout of hole. Plan Forward: 1) Obtain Sundry for conversion of all three wells to WAG injection. 2) Complete installation of produced water and MI headers. 3) Complete downhole work to convert wells to injectors. 4) Place N-07A on water injection in Q3 2015 (depending on timing of completion of surface work) 5) Place N-01A on MI in Q4 2015 6) Place N-27 on water injection in Q4 2015 7) AOGCC witnessed MIT-IA to 4000 psi on each well after injection has stabilized. ' TREE= 4"CM/ 3131ELL)-1EAD- —I/CEVOYSAFETY NOTES:*"'000A HAS 1140 CSG MAX AC:IUA TOR- HAKHRC N-Olik 1MT-000A 1200 PSr"' KB REV- 62 1cr "*4-1,2"CHROME leG'" Bi an/- 431 ___.... KOP= 39012 — I..-1-1-0-0"--1-113-3/6"-t7iFKR1 Max Angle= 68'0j)St27T Cuturn AO= 94137' 2187' 14-112 FES X NIP,0=3.813* Datum IVO= MOD SS . imi2291. 1.--tio.N4'ru PKIii 170'CPA.1330/944 1(.48/1-1-40,In-19 174 i f 20110'-1 —d 1 9.17at J-1192..4'x 9 Sttr:_nli) F I 10-1/4-CS(3,55,50 14 00 Li.9 451" 1-- 2426" ,,--- $ I. 2426' I-170P OF Cl/OPM(r runack 1 NFT1 I 0 WI I fiT MD 11/1, (MN,TYR WV 7tAiCh p)tril IATE 'il. 5 3268 3 KDG2I001.t. 81 16 01/2E031 13-3/8"CSG 684,K-55,D=12 415' 1 4200'_ 11ii 4 5596 5589 0 .1(13G2 IDLE BK 21) 0626/13' li 3 7208 7201 2 'ICBG2 OW BK 0 12/21/12; -- - - r 2 /935 /908 2/ KBC.2 UNN BK o 0004/04 Minimum ID..3.725"@ 8807' . i, 1 W89 8397 NT K141,2 OW UK 0 I:Y21/121 i - 14-112"HES XN NIPPLE ..., 1i II 7171' 7*BKR TEBACK SEAL ASSY w/02T PORTS.0=6 Pr 17"TACK CSG 268,140 Bit,0=6.276' I--: 7181. 7171* 9-5/8'X 7'BKR ZXP EAR TOP FKR 1 S 141C LNR HNGFL 13=6.261' i MILL0421 WII4UOW 1318 7332' I wi-sysTocK H 7316' I la-cor F7SV(117•1511.40 H 71111P IlL iip „---47,47,i7j-I4-1/r(-ES X NP,ID=3413"[ --444144--- 11843 S11113(07/03/04) I 1 7814* I n is„ -----_---87W It'x 4-1/2"BKRS-3 FKR ID ...4..... 11110, __ se 1--- --10"/-ES X NE,I) 3813 0 '-•=1 •-='-' 1111b1, 8803' I {4 tir IRS XN MP,ID [9-518'CsG,479,N4O.In-8 881' --t 5309' .1 _8818' I 7"X 5"9KR ZXPLNli TOP PKR A 4-111014R iteotealAW: MGR.0=3.968' A 1 --=- _. ------- \ 8819' 4 1/2'WIG, TERFORATIONSUWARV ---.4.4--- • D=3.968'LOG:SIAS-81-CS ON 10/09110(t4-017) WffsWirf 444646.4.464 \ ---8838' I 5"X 4-V2"X0. ANGLE AT TOPFERF 67-09355* \ 0=3.958" We.Refer to Produchon DB kit historical per(data 4-1/2"TBG 12 64,13CRTC11. d 8819'J SIZE SW 1 NTERVAL S481)7 WOE SW Ott.?bpt u 3-3/8' 6 ! 9355 93/5 0 01125106 2-716' 6 ' 9380 9394 0 04.126./06 17't UT.7814.1 an Sin. 0367 4," ID-6?71r I ' 8988. 2-7/8' 6 9380-9420 0 09/18/04 2-7/8" 8 9394•9417 0 02/18,06 7.710' 6 *130-9455 0 00123/04 .4ilj I ° H 98 414‘..i*.— v.,- , [4.1/2'TBG,12.84,L-80 07-14.0152 big.0=3.958' [H 97418"7 — _ DATE REV BY1 COMMENTS DATE Fla/By CODATINTS, 11 FRUTICE RAY UMT '107/24774 'ORIGINAL COMPLETION 12/27/12 RICT(JM) GI V C20-SFT XXN R UG(17)21-7' WM ROM 4 08/10917 sR610 01r28/13 1181.180 INCE 00(01/12/13) 1 pavir No'2041130 08107104 MOS SICETRACK(N-01A) 01r28/13 AINJMD PULL ON RUG&GLV 00(01/24 All Nu 50-079-200/9-01 04/26/013 altilPJC 4PEIV CORRECTION(2/18/06) SEC 8.Ti IR.R13E 1519'FSL 8556'Mt 04/26106 GJ1YPJC ADFERF 09/05/08 JCIPJC!FEW(07/25/08) BP Thspiorielart(Alaska) ...„ .-- Figure 1 —N-01A Wellbore Schematic fF 4`1-140 SAFETY NOTES:"""4-112-CHROME TBG"• • WRIT-EA ID= 1/ VOY N-O7A ACTUATOR= BAKER MIALKB.ELE 61.40• BF.ELEV= 41 84' KOR- 3100 Max Angle- 66"at 10568' Crum LID= 10401' 1_----2045'--_I--9-518•I33RJ DatumTVO= 88000 SS • I 2119' I 14-1/2'NES).NP,[7 3 913' (13-38'CSCt.721,N-80,D=12347" H 2817' ' 4 1 —260W 1 TEST TOC OF 9 U r X r Ah1M I i,3 1 1 GAS Li1 MAN3RIS 1 ST 111 TVn nFV TY Iii VI V I AWN Q TWIN Minimum-ID=3,725"0/9811' 4 3315 3300 13 KI3G2 CONE BK 16 00/18/13 lip 3 6313 5578 47 ICBG 2 SO BK 20 09/18113 4-1/2"HES XN NIPPLE ,Il 2 8414 7100 34 KBG2 0611 BK 0 07/23134 •; 1 9677 8230 31 KBG-2.. GMI BK 0 07/23/34. " (T SCA B LNR 26x1,L-80..383 b4f.O=8276" I CR 8921' I '� I-roe of r LM4 8924' , « .. 8931' I-19.51 15`x r UNOUEOVERSSF(T I i9-618•C:8(3,4/11,L-a0,u:a-6a1. 9635• 11 I 9746• H4-12-HFSXIIF,13=3813- I CI 14 L 9767' I jrX4-N2'SKRS-3PPR ID=3.875' 8790' -{4-U2'IfsXlf' -3.$I3' I .._.9811'—I-I4-112-HES XN NP•D=3.725' j �4-112'TBC.12.8*,13C11-88, 0152 bpf D=3.958" I-.-I 8824' I 9824' 4-1/2'WLI D=3.958' 9826.1-I 7`X 5"SKR ZXP LNR TOP PKR&HNGR,D m 4.47 I PET4•"OR Al)N SUMMARY 9846' H 5'X 4-1/2'XO.D.3 980' 1 REF LOG SLB RST/SIGMA ON 0104/04 ANGLE AT TOP FERE 65°@ 10606' i _....,_.._......_.-.._-..-... Note:Refer to Production DB for hisklrcal pert data I Mil OUT WNJOW 10004'-10031' SIZE SIF INTERVAL Opn/Sgz SHOT T SQZ 3-3/8" 6 10539-10559 S 08/10104 09114/13 3 3/8' 6 10571 10596 S 08/10104 09114/13 7.MI" 6 10606.10676 0 09/?1/13 `` 10479' -{4112'MARKHd,K�fT i 3-3/8" 6 106310639 S 06/1(604 109'14113 TREE= 4-1116'CIN • WFLLIEAO--N- ti FNIC1 SAFETY NOTES "4-1R"CHROME 150 WELL 'ACTUATOR. BAKER N-27 1W INNED TO N-06 FLOW LINO" KB.ELEV= 716' BF ELEV= 458'+ K0P 503' 991' H95)8"TAM PORT COLLAR,10-8 75" Max ANle- 26'42180'{ Mum MD= 8/62'112'Fi0= I 2201' Ha-1,71. MumCC 8800'551 122 0'CONDUCTOR,91.58.1+40 ID=19 124 108" 1 I9-518-C5G,478,1460 BTC-M,D=666" I—I 3222' GAS LIT MANDRELS Sr NC TVD DEV TYPE VLV LATCH FIAT DATE 4 3811 3631 15 K802 COME BK 16 09)07111 3 6100 5827 16 K802 SO BK 2D 09)07711 V CSG 268,L-90 To XO TO L-80 BTC-M H 4714' I—K SK 2 7637 7301 17 KBG2 01.8f BK 0 08716711 1 8629 8254 14 1(8122 DRAY BK 0 08116111 1 8707' H4-1}2'HESXNP10=3813" I Minimum IO(N-27)=3.726"@ 8792' 4-1I2 HES XN NIPPLE g 25. { 8728' 7R"BKFS-3RM.0=3.87x ) I g---"{—117-1T—HI-1-42`HES X 141)-0;378-1-3"1 ' , 8792' 4.105'HES XN MP.0=3 725"I 8796' T'X 5"BKR C-2 ZXP LTP,ID=4 440" I TOP OF T_LNR 1--L 8798' \ 8804' I--{4-1(2"AUG.ID=3.956- 4-1I2'TAG 12 66,{SCR-IC VAM TOP 8804' L ED (�� I 0152 WA.D=3958" 8813' H 7171:X 5"17RFLDC-LOCK FOR,ID=4.440 I 8823' HS'X 4-12"x0,D-3 940" I7'CSG.269,L-80 OTC-IA ID.6 278 8987' ` f--{ 9039' H4112'reek WES JOn-r PERFOR111ON SUMMARY REF LOG SL8 MJICAGR ON 08/30107 R ANGLE AT TOPPFRF 12'@ 9144' Note.Rater to Production O8 for hworical peri Ma SIZE SFF NTERVAL Opr/Sgz DATE 3-378" 6 9144-9164 0 1127108 2-718' 6 9172-9192 0 11)2607 H I 9208' I--.389'WRP(07.03109) I 2-718' 6 9214-9219 C 11)2807 LI FWD 9417' Immo 111111111 14.1/2'TBG,12.69,L STM, 0152 4,0 10.3 958'I 9503' 814.1,4. DATE REV BY COMM34TS DATE REV BY CONVENTS PRUDHOE BAY UNIT 89)13107 MES ORIGINAL COMPLETION 09/01708 JLJIPJC GLV 040)08025/08) IMILL N-27 1126,7 JWIPJC GLV GO 12)04408 TFAIPJC PERFORATIONS(111271081 PFRMT No 2071040 12!15)07 TELJPJC PEf1FORATONS(1128A7) 07131109 RRI?PJC SETMP(07)03)09) AR No 50-023-233656-00 D1/14107 OLWPJC ORLG DRAFT CORRECTIONS 08/17/11 GJ84 PJC GLV C10(8716111) SEC 8,TI 1 N R13E 2285'FSL 8571'FAIL 03419708 JCR/PJC DRLG DRAFT CORRECTIONS 0903/11TA7 PJC GLV CIO(09)07111) 07718708 KSBIJMJ GLV GO(07706108) 03729412'LFALIND T'CSG DEPTH CORRECTION BP Exploration(Alaaky Figure3—N-27 Wellbore Schematic N-Pad UZI Injector 114 Mile Radius Map F., 7, 4-1413 0 500 1000 ` 1 rr -i U.S.surveyors feet ` 14A 09A 5970000 13 ' 148P:. 1'I i .41IN 014 4.�..�1-04A 14B •,,,,,,4,, (: ii'IL:IIL: 5989000,,, ,,,, , 5966000 ,�w / -20A 1 ,' . -20 ' • ,'sA ``ON♦ `` _ ', -02 -02A 5967000 ' • ` 1 27 i r , -21 5968000 r e. / •` -16 12 -__31\.___3 • L i -09 — — ' 5965000 5A I til-21A ‘e... , 05 I 632000 634000 636000 638000 640000 Figure4—Map showing wells within 0.25 mi radius from N-01A,N-07A & N-27 Roby, David S (DOA) From: Bailey, Denise G <denise.bailey@bp.com> Sent: Wednesday,June 10, 2015 3:38 PM To: Roby, David S (DOA) Cc: Richmond, Diane M; Lastufka,Joseph N Subject: RE: Sundry applications for conversion of PBU N-01A (PTD204-113), PBU N-07A (PTD 204-105), and PBU N-27 (PTD 207-104) Please see my answers below. Please call at 907-564-4749 if you need further clarification. Thanks, Denise Bailey H, N, D&Q Pad Engineer (907) 564-4749 denise.bailey@bp.com From: Roby, David S (DOA) [mailto:dave.robvTalaska.gov] Sent: Tuesday, June 09, 2015 11:08 AM To: Bailey, Denise G Subject: Sundry applications for conversion of PBU N-01A (PTD204-113), PBU N-07A (PTD 204-105), and PBU N-27 (PTD 207-104) Denise, I'm reviewing your application to convert the three subject wells from producers to injectors and have a couple of questions for you. 1) If I'm looking at things correctly it appears that you're establishing a new flood patern and that these wells will be the initial injectors in this pattern, is this correct?Yes—these will be UZI (updip zone 4 injection)patterns. 2) It's pretty much a no brainer to convert the N-07A well to an injector since it has watered out but the other two wells are still pretty decent producers with reasonable GORs and water cuts. Why were these specific wells chosen for conversion? BP has had the idea for an UZI project in development for 8+years. There is oil stranded on the shale lenses that these injectors would sweep towards producers surrounding them. To complete this project,we've drilled new injectors(N-28& N-29) and are in the process of installing an MI and PW header to tie-in the converted producers&new injectors. The UZI injection on N-pad (including N-01A, N- 07A, N-27, N-28&N-29)is meant to cover most of N-pad, particularly the areas where lenses have been seen in surrounding wells. The UZI reserves model indicates that the incremental reserves recovered by converting N-27&N-01A(and losing current production)are greater than if we leave them as producers. N- 27 well was drilled as a future injector-we just pre-produced it while waiting for the UZI project to materialize. N-01A was side-tracked earlier than N-27, but its secondary objective was to maintain options for UZI injection. The UZI project has been sanctioned by partners and has been included in the GPB IPA Plan of Development for the last few years. Thanks in advance, 1 Dave Roby • Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 CONFIDENTIALITY NOTICE This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Dave Roby at(907)793-1232 or dave.robv alaska.Qov. 2 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0 y... - 1 OSWell History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 1111111111111111111 ,,;t..CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ~skettes, No. I o Maps: o Greyscale Items: o Other, NolType: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: D Other:: BY: ~ Date q t /6/ Ob 151 m,P 111111111111111111I Project Proofing BY: ~ Date ~/l5 lob 151 Mf 1 I Scanning Preparation I x 30 = 30 + ~ = TOTAL PAGES~ Count does not include cover sheet) ,p BY: Date: 151 1111111111111111111 Production Scanning Stage 1 Page Count from Scanned File: 50 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: l/ YES BY: CMariQ Date: q 11~/ó0 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 151 VV1 f NO BY: Maria Date: 151 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 111111111111111111I BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA RECEIVED AIIOCA OIL AND GAS CONSERVATION COMMON • OCT "f 203 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Repair WellLj Plug Perforations Lj Perforate U OtherLj AQGCc Performed: Alter Casing ❑ Pull Tubing0 Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development o Exploratory ❑ 204-105-0 • 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20137-01-00 . 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028282 • PBU N-07A • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL • 11.Present Well Condition Summary: Total Depth measured 10832 feet Plugs measured None feet true vertical 9098.38 feet Junk measured None feet Effective Depth measured 10745 feet Packer measured See Attachment feet true vertical 9035.73 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"94#H-40 30-110 30-110 1530 520 Surface 2598 13-3/8"72#N-80 30-2628 30-2627.68 4930 2670 Intermediate 7591 9-5/8"47#L-80 2055-9646 2054.79-8203.58 6870 4760 Production 8904 7"26#L-80 27-8931 27-7594.84 7240 5410 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10539-10559 feet 10571 -10596 feet 10606-10626 feet 10634-10639 feet True Vertical depth 8929.37-8937.89 feet 8942.89-8953.3 feet 8957.5-8966.44 feet 8970.26-8972.72 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 28-9824 28-8356.09 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10539'-10559',10571'-10596', 10634'-10639' �gq y Treatment descriptions including volumes used and final pressure: SCANNED 1,V t,xt 4 :a :}01 11 Bbls 12%HCL,816 psi;68 Bbls OrganoSeal,50 Bbls SqueezeCrete,2477 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 604 28303 2549 0 1193 Subsequent to operation: 14 698 144 1109 150 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 • Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil SI • Gas U WDSPL.[J GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email Garry.Catronc BP.Com Printed Name Garry Catron Title PDC PE Signature Y v41 Phone 564-4424 Date 10/17/2013 L g L°/ z v/e3 RBDMS OCT 17 20 Form 10-404 Revised 10/2012 0 0 A /l / Submit Original Only • • Packers and SSV's Attachment ADL0028282 SW Name Type MD TVD Depscription N-07A PACKER 9767 8234.8 4-1/2" Baker S-3 Perm Packer N-07A PACKER 9833 8291.6 4-1/2" Baker ZXP Packer Casing / Tubing Attachment ADL0028282 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H-40 30 - 110 30 - 110 1530 520 INTERMEDIATE 7591 9-5/8"47# L-80 2055 - 9646 2054.79 - 8203.58 6870 4760 LINER 1055 7" 29# L-80 8949 - 10004 7609.05 - 8511.64 8160 7020 LINER 1006 4-1/2" 12.6# 13Cr80 9826 - 10832 8357.81 - 9098.38 8430 7500 PRODUCTION 8904 7"26# L-80 27 - 8931 27 - 7594.84 7240 5410 SURFACE 2598 13-3/8" 72# N-80 30 - 2628 30 - 2627.68 4930 2670 TUBING 9796 4-1/2" 12.6# 13Cr80 28 - 9824 28 - 8356.09 8430 7500 • • • i b 0 3 cE � O °; � 3 a) C g _ �- c0 ° u) QO t. co N ca C) Q .Q ■ (n J U ' O\ L N 7 - Z a) U) � r > a) co co co O O .0 � Q v1 a) O N N j ._ v7 J O a) co ci t O O O Q 'Li. = (n LUr 45 c) N 0 00 >0 > LLI (IS L �1 _ L : Q � c00 d 2 v N U .CN OU NLL a) co u., O5 j U) - L LPL Q V) Q >> L L Q.. 0 J O E a- 00 < C ° 0) Q co F- .2 Q- J I U N co co a- > N Q Y co Q 0 C N a) W m c o L u) (ti N a c6 3 a, c•J O O C (.5 a) L 4) M M •.Q-0 a)E C (AQW p c 2 2 �m (3 > = > 7 ca a) c Q ° j ..... d >O a p O ) a c O i J0 al k � , D 0 a) D m H Q • N p c Z� n� o _ d = o-H o 2 2 2 z f- 3 Q- W o Z 0 °- o , O N ? '.0 a.= n -1 -Jin Zr) _, � a (0 - _ m ca N 3 0 _ CO O Q 3 cJi) O - °-N— o 0 10— U a) `- �_ emu) �'• C N a) J 0 Q c U) * (U C) co 0 .2 o co Q O c 73 •- = . v) O 2 0Zcc W - C ° O ' - oQ �c e) U) d w II co o 3 a) < o p � X = � m :`15 rna U o = (n Q m = a QOm Q J oz t * - cn M J � (!1 N a) N oZf V � J t O a) Q � O � 'N O �_ (n � U � � L~L � � O N(n � Q N = MM = Z O N cr)0- a Q} pW C � Q rn I" o H H C) � m W LL _ Q • co o Iii m O ,- o o (/� V m Z J U) O Q N U- 43 iQ _jW ,- cn c O 22 � mMapJ _ 0 N E a) N a Qd io - ,r o , °' ?, joom � i Q 3 � @�Op * o * � QW cn .- :rH - > OOQ oa ca .� � N � � r a) � Q O L ct L � I— � H O = � ~ .n E ns U © � (n m CO o' — 0_ca CI Q xNOJZO ~o a) WQ > > (/) 3 � 05LU CC. ' TD U � a a• ' -Q = o c � O _a a) Q _Q JZQZN > W v7 'O 3O II U 0 ' > C) O pN ©HUJ . � = OJ JQ JOaa_ el N ooa � � � •° H Q � � cO c o � oCL Cl Z YYOW �J 2 2 — 3 N a) (n • � � a) •CL c DW ? � 1 o0NmmaQQQ WO , Q .N nov 0-otS � Dv u) Ems = c JWU ~ ti_ LU � QQ , Q I lLQU _M — Qo1-n > E 3W o jE2 > U � O N* W DD W c W � D ? 0 p c •VO 6 o > H 0p N : FN � * Q : * H .— -o * Ua- a- (nJ (AJa- * I— C Z o — U) U � a- 3ONLL M M M M M M r r- _ _ r r O O O O O O CN N N N N 11.3 CO 7 Co CO ti N 63 Daily Report of Well Operations ADL0028282 CTU 8 w/ 1.75" CT. Scope;Acidize. Gel and Cement Squeeze RIH to 6000 ft. park coil to pump organoseal. Have cementers load CT volume 31 bbls with FW. Pumped 10 bbls FW ahead of organoseal 68 bbls. followed 10 bbls FW down CTBS. at 3 bbls/min. W.H. 0 psi IA 433 psi.. Pumped 126 bbls of diesel, 4.5 bbls/min.at W.H. 1900 psi. Pump off line WH. 288 psi. positive wellhead pressure RIH to jet fresh water across perfs until cement reaches bottom perf.open choke lay in 50 bbls of squeezecrete 1:1 from 10,728' PUH to safety 7,000'. Close choke begin increasing squeeze pressure. Squeezed 5.7 bbls behind pipe. Held 2500 psi for 1 hour and pressure bled 133 psi, bumped the pressure back up to 2500 psi and it bled 51 psi in 30 minutes. Called the squeeze good and cleaned out with 1.25ppb down to TD and layed in powervis up to 9800' ctm. Continued out of hole at 80%washing jewelry. Freeze prottected the well from 2250' to surface with 50/50 methanol. Washed the BOPs at surface. Blow down the reel with N2. 9/14/2013 ***job complete*** T/I/0=294/521/131. (MIT T to 1500 psi/ Post Squeeze) MIT T to 1500 psi. PASSED. Tbg lost 40 psi in first 15 minutes & 9 psi in second 15 minutes. Total loss=49 psi. Bleed tbg pressure down to 9/17/2013 238 psi. FWHP=238/529/131. Swab, SSV, &wing valves closed. Master, IA, & OA open. ***CONT FROM 09/17/13 WSR***(post GSO-organoseal-squeeze-crete) D&T W/20'x 2-7/8" DMY PERF GUNS, 4-1/2"XN-LOCATOR & S. BAILER LOC XN-NIP @ 9813' SLM /9811' MD (--2' correction to md). NO SAMPLE SET DOWN @10,161' SLM, DRIFT W/20'x 2-7/8" DMY PERF GUNS (removed xn-loc& bailer) SET DOWN @ 10,390' SLM DUE TO DOG LEG RAN 10' x 2-7/8" DMY PER GUN &TAG TD @ 10,726' SLM/ 10,724' MD (corrected) SET 4-1/2"WHIDOON C-SUB ON XN-NIP @ 9813' SLM (9811' MD) • PULLED ST#3 BK-DGLV @ 6306' SLM (6313' MD), ST#4 BK-DGLV @ 3300' SLM (3315' MD) SET ST#4 BK-LGLV(1500 tro/ 16/64" ports) @ 3300' SLM (3315' MD) SET ST#3 BK-OGLV(20/64" ports) @ 6306' SLM (6313' MD) PULLED 4-1/2" EMPTY WHIDDON C-SUB FROM XN-NIP @ 9813' SLM (9811' MD) 9/18/2013 ***WELL LEFT S/I, PAD OP NOTIFIED*** Daily Report of Well Operations ADL0028282 ***WELL SHUT-IN ON ARRIVAL***(E-LINE PERFORATE) INITIAL T/I/0=300/600/50 PSI RIH WITH UPCT/2.88" HSD 10 'PJ OMEGA GUN PERFORATED INTERVAL 10616'-10626' RIH WITH UPCT/2.88" HSD 10' PJ OMEGA GUN PERFORATED INTERVAL 10606'-10616' LEFT WELL SHUT-IN, HAND OVER WITH DSO PRIOR TO DEPARTURE. FINAL T/I/0=200/400/50 PSI 9/21/2013 ***JOB COMPLETE*** • • TREE= 4"FMC SA*NOTES:***4-1/2"CHROME TBG'** I WELLHEAD= MCEVOY -07/k 'ACTUATOR= BAKER MIAL KB.ELE 61.40' — BF.ELEV= 41.84' KOP= 3100° Max Angle= 66"@ 10568' Datum MD= 10401' Datum TV O 8800'SS I 2046' I�� "PBR I I I 2119' H4-1/2"I XNF',U=3.813" I 113-3/8"CSG,72#,N•80,D=12.347" H 281r ii ; I -260(i.1-1 EST.TOC OF 9-5/8"X T UL ■ ANNUS ► j GAS LFT MANDRELS o s ! IST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID =3.725" 9811' i '4 4 3315 3309 13 KBG-2 DONE BK ' 16 09/18/13 ■ 3 6313 5578 47 KBG-2 SO BK ' 20 09/18/13 4-1/2" HES XN NIPPLE ■ 2 8434 7190 34 KBG-2 DMY BK ' 0 07/23/04 ► r 1 9677 8230 31 KBG-2 DMY BK ' 0 07/23/04 • • ► 1 7"SCAB LM,26#,L-80,.383 bpf,D=6.276" 8921' • ►i •I TOP OF 7"LNR Ft_ 8924' } 8931' 9-5/8"X r UMQUE OVERSHOT I 9-5/8"CSG,47#,L-80,D=8.881" H 9635" I ' ■ I 8746' H4-1/2"FES X NP,D=3.813" 0 ►i I 976T H7"X 4-1/2"BKR S-3 PKR,D=3.875" I I 9790' H4-1/2'Hey X P6',D=3.813" I I I 9811' H4-1/2"HES XN NE;D=3.725" I 4-1/2"TBG,12.6#,13C11-80,.0152 bpf,D=3.958" —I 9824" I 9824' H 4-1/T WLEG,D=3.958" I 'r 8826' H7"X 5"BKR ZXP LNR TOP PKR&HNGR,D=4.42" I PERFORATION SUMti kRY 8846' H5"X 4-1/2"XO,0=3.960' I REF LOG:SLB RST/SIGMA ON 08/04/04 ANGLE AT TOP PERF:65°@ 10606' Note:Refer to Production DB for historical pert data MLLOUI'VIONCOW 10004'-10031' SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 3-3/8" 6 10539-10559 S 08/10/04 09/14/13 3-3/8" 6 10571-10596 S 08/10/04 09/14/13 /I 10479' IH4-1/2"MARK82JONf I 2-7/8" 6 10606-10626 0 09/21/13 3-3/8" 6 10634-10639 S 08/10/04 09/14/13 ►- II ■ 3-1/2"TBG,9.3#,N-80,D=2.992" H 10486' ` , PBTD 10833' r4�4������itt4�4 .�. .IL`s ►.1.1.1.1.1.1.1.1 17"LNR 29#,P180,D=6.184" 10642' •."IP w PBTD H 10745' I G�� I4-1/2"LNR 12.6#,L-80,.0152 bpf,D=3.958' I— 10832' I DATE REV BY COMENTS DATE REV BY COMvENTS FRIDHOEBAY UNIT 01/24/77 ORIGINAL COMPLETION 09/26/13 VUEC{JMD GLV C/O(09/19/13) WELL: N-07A 03/21/89 RWO 09/26/13 ATO/JMD ADPERFS(09/21/13) PERMIT No:I041050 07/23/04 JAF/TLH SIDETRACK(N-07A) AR Pb: 50-029-20137-01 08/03/04 KSB/TLH GLV CIO SEC 8,TUN,R13E,2219'FSL&571'PM. 07/30/12 PJH'JM) ADDED FEW REF DATE(07/26/12) 09126/13 JGL.IAD GMT SOZ(09/14/13) 11 BP Exploration(Alaska) • • ~~~ c~~ ~' MICROFILMED 03/01/2008 DC~ NQT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\A~icrafilm_Marker.doc OPERABLE: N-07A (PTD #2040) restored integrity • Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, November 19, 2007 5:30 PM To: NSU, ADW Well Integrity Engineer; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Regg, James B (DOA); Maunder, Thomas E (DOA); Starck, Jennifer L Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer ~~~~ !~ 4 Z~(v ~~7 Subject: OPERABLE: N-07A (PTD #2041050) restored integrity l All, Recently N-07A (PTD #2041050} was classified as Under Evaluation due to a failed TIFL. Slickiine recently set DGLVs in STA # 3 4 and fullbore conducted an MIT-lA to 3000 psi. This subsequent MlT-IA passed confirming that tubing /= integrity has been restored. With restored integrity, N-07A has been reclassified as Operable. Gas lift valves may be set to kick off the well. Thank you, Anna Dube From: NSU, ADW Well Integrity Engineer Sent: Wednesday, November 14, 2007 3:53 PM -.,; "~ NOV ~ ~ 200?` ~.~w To: GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; James Regg; Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Warren, Mike; NSU, ADW WL & Completion Supervisor Cc: NSU, ADW Well Integrity Engineer; Roschinger, Torin T.; Lau, John, Jack Subject: N-07A (PTD #2041050) Under Evaluation for sustained casing pressure - TxIA communication AI I, Well N-07A (PTD #2041050) has been found to have sustained casing pressure on the IA. The wellhead pressures were 1430/2040/73 psi on 11/13/07. A subsequent TIFL failed on 11/14/07. The well has been classified as Under Evaluation and may be produced under a 28-day clock. The plan forward for this well is as follows: D: TEFL -FAILED 2. S: Set DGLVs in STA # 3 & 4 3. F: MIT-IA to 3000 psi, LLR if fails A wellbore schematic and a 90-day TIO plot have been included for reference. /~ 11 /26/2007 • C~ b'OOO ~ 'dOO > b'O -7- 'dl -i- ~ql t S~~ _ ~ ~, LOOU6U4L LOOUbWL6 100U6UOL LOOUbtJOI LOOU6U6 LDOU£W6 LOOU6U8 LOOUbU9 0 ....................... ~4J dALL.LJ?~l t'L,~ -'~ l~t~~ ~~~_ t 000' L dS't7'dW b'1 000 Z ,. 000' £ ^ooo.uuuo.....u 000'b TREE = 4" FMG WELLHEAD= MGEVflY ACTUATOR = __.. _ ~ _ KB. ELEv -. ~~BAKER ~.~.m ._~ ti1.~10' BF. ELEV = KC}P - 41.84' 3100' _ Max Angle =~f Daiun~ iJeD --~ 6f~ ~ 10568' 10401' Datun7 TV D = 8800' SS 13-3,''8" GSG; 72#, N-80: iD = 12.347„ ~--~ 2617° r NOTES: *** 4-1 /~" CHROME TBG *** 2045" 9-518" PBR 2119' 4-112" HES X NIP, ID = 3.813 M2600" EST. TOG flF 9-5?8" X 7" ANNUl.,L1S GAS LIFT MANDRELS ST MD TVD DEV TYPE VL11 LATCH PORT DATE 4 3315 3309 13 KBG-2 DOME BK 16 08/03/04 3 6313 5579 47 KBG-2 SO BK 20 08103!04 2 8434 7190 34 KBG-2 DMY BK 0 07123104 1 9677 8230 31 KBG-2 DMY BK 0 07!23104 $931' 9-518" X 7" LINIQUEOVERSHOT 9746' 4-112" HES X NIP, ID = 3.813': 9767° 7" X 4-112" BKR S-3 PKR, ID = 3.875" 9790' 4°112" HES X NIP, ID = 3.813° 9$11® 4-112" HES XN NIP, ID = 3.725" ~4-1,'2" TBG, 12.6#, 13CR-80, .0152 bpf, tD = 3.958" ] PERFORATION SUMMARY Fir F l._C RST'S(t:~,1A Ott XXiXX!04 ANGLE AT TOP PERF: 64° @ 10539' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL flpnlSgz DATE 3-3.-8" 6 10539 - 10559 O 08110r'04 3-318" 6 10571 - 10596 O 08110!04 3-3'8" 6 10634 - 10639 O 08%10?04 3-1,''2`° TBG, 9.3#, N-80, ID = 2.992" 104$6' PBTD 10633' 7" LNR, 29#, N-80; ID = 6.184" °°-r--1064.2' ~$~~.° -~4-112" WLEG; [D = 3.958" 9$26' 7'° X 5'° BKR ZXP LNR TOP PKR & HNGR, ID = 4.42" 9$46" 5"' X 4-1i2" XO, ID = 3.960„ A41LLOtJT UJINDOW 10004' - 10031' X479® 4-1 i2" MARKERJOIIVT PBTD --~ 1 t~7~ 4-112° LNR 12.6, L-80, .0152 bpf; ID = 3.958" 10832" DATE REV BY COMMENTS 01124177 C}RIGINRL CCIMPLECIC#N 03121189 ~F20 __W__. 07123!04 JAFITLH SIC3ETRACK {N-Q7A) 08,r03r04 KSHiTLH GLV Gf0 DATE~1 BY~ GOMtv1EN7S PRUDHOE BAY UNCf VdELL: N-07A PERMIT No: 2041050 API No: 50°029-20137-01 SEC 8, T11 N, R13E, 2219' FSL & 571' FV±rL BP Explara#lon (A3aska} Scblumbepgep NO. 4210 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AI'( 99503-2838 A TTN: Beth ~NED APR 1 0 2007 t964-/öS -# i45150¡ Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Loa Description Date -. BL Color CD W-25 10980555 RST (REDO) 05/02/05 1 N··07A 11296715 RST 09/11/06 1 1 F-06A 11258688 RST 03/03/06 1 1 18-16B 11588702 MCNL 12/27/06 1 1 00-09 11320999 RST 08/02/06 1 1 X·15A 10928631 MCNL 05/11/05 1 1 00-09 11223132 RST 08/02/06 1 1 3-17F/K-30 10728392 MCNL 03/12/04 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 M""""_ AI< '''''U ATTN: Beth ê Received by:.. I'--. RECEIVED Date Delivered: APR 0 6 7007 AI~ Oil & G~ C{)fIS. Commission AnchoragE'; -$' 04/05/07 . . Sc~luInbepgep NO. 4058 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth [)Cf~J - /óC Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay WII CI CD J b# D B e 0 Log escnption Date L o or H-34 11477963 LDURST 11/07/06 1 y-01B 11485468 MPPROF W/DEFT & GHOST 11/07/06 1 2-08/K-16 11487771 LDL 11/12/06 1 X-03A 11485772 MPPROF W/DEFT & GHOST 11/09/06 1 DS 09-51 11477933 INJECTION PROFILE 11/06/06 1 15-45A 11485469 MPPROF & INJECTION PROF 11/09/06 1 N-o-7 A 11296715 PROD PROFILE W/GHOST 09/10/06 1 DS 09-31C 11483591 INJECTION PROFILE 11/20/06 1 G-06A 11422979 SCMT 11/01/06 1 P2-59A 11414775 SCMT 11/05/06 1 NGI-06 11414773 USIT 11/01/06 1 A-43 11414774 USIT 11/03/06 1 01-26A 11001225 RST-SIGMA OS/24/05 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Alaska Data & Consulting Services "" G.mbo' S'_, S,;. ø "",,,,,,,,.. AK "50~2 ATTN: Beth ê Received by: I / f\--.----. Date Delivered: NO" ? 9 ?om) I~ 11/28/06 . . PBU N-07 A . . Andy, No open hole logging data was submitted for PBU N-07 A, API 50-029-20137-01. Please send over bluelines, reproduceables, and digital logging data for this well as soon as possible. TNX Howard I of I 9112/20069:51 AM lD ~ DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Permit to Drill 2041050 Well Name/No. PRUDHOE BAY UNIT N-07A Operator BP EXPLORATION (ALASKA) INC A~;±02'~i1~~~ Y MD 10832, TVD 9098"" Completion Date 8/10/2004 /' Completion Status 1-01L Current Status 1-01L UIC N -_.~--~- -------,-~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~--~-~-- _.._"--'.~ DATA INFORMATION Types Electric or Other Logs Run: DIR / GR / RES Well Log Information: Log/ Electr Data Digital Dataset ~ __ Med/Frmt Number Name T~ D Asc Directional Survey ~~_. Directional Survey Well Cores/Samples Information: (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval Start Stop . OH/ CH Received Comments 8/6/2001 8/6/2004 -l _~J Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y Gb Chips Received? '~ Formation Tops ~N &/N Daily History Received? Analysis Received? ~ -~.._-_.~.- ~-_. . ~~--~ ---_.~ Comments: -_._~~-----~ ~- Date: ! ~ ~~~~-= Compliance Reviewed By: e STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COMMI SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG .-. ~ 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20MC 25.105 20MC 25.110 CASING, LINER AND CEMENTING RECORD 8m-iNG Ji:PTH Mf.)~r;p-IN(,l[ !:PTI11'\1PH6t..Ê V\lT..peRFT.GRADE:TOI? IDOIIUMTOP BOTTOMSiiÊ 20" 94# H-40 Surface 100' Surface 13-3/8" 72# N 80 Surface 2618' Surface 9-5/8" 47# N-80 Surface 9635' Surface 7" 29# N-80 8923' 10004' 7589' 7" 26# L-80 27' 8931' 27' 4-1/2" 12.6# L-80 9826' 10832' 8358' 23. Perforations open to Production (MD + TVD of TOE and 124. Bottom Interval, Size and Number; if none, state' none"): 2-7/8" Gun Diameter, 6spf MD TVD 10539' - 10559' 8929' - 8938' 10571' - 10596' 8943' - 8953' 10634' - 10639' 8970' - 8973' o GINJ 0 WINJ 0 WDSPL No. of Completions 2, Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3061' SNL, 4709' WEL, SEC. 08, T11 N, R13E, UM Top of Productive Horizon: 3037' SNL, 979' WEL, SEC. 08, T11N, R13E, UM Total Depth: 2976' SNL, 1157' WEL, SEC. 08, T11 N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 634414 y- 5968123 Zone- ASP4 TPI: x- 638143 y- 5968215 Zone- ASP4 Total Depth: x- 637964 Y- 5968273 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: DIR I GRI RES 22. C~~~G MD One Other 5. Date Comp., Susp., or Aband. 8/10/2004 6. Date Spudded 7/18/2004 7. Date T.D. Reached 7/19/2004 8. KB Elevation (ft): 72.25' 9. Plug Back Depth (MD+ TVD) 10745 + 9036 10. Total Depth (MD+TVD) 10832 + 9098 11. Depth where SSSV set (Nipple) 2119' MD 19. Water depth, if offshore NIA MSL 100' 24" 2618' 18-1/2" 8193' 12-1/4" 8512' 8-1/2" 7595' NIA 9098' 6" SIZE 4-1/2", 12.6#, 13Cr TVD 25. ACID, - Revised: 09/21/04, Put on Production 1b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-105 13. API Number 50-029-20137-01-00 14. Well Name and Number: PBU N-07 A 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028282 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 4..", I~IT ,.v,vvn 122 sx Permafrost 3786 sx Permafrost II 1270 sx Howco Lioht, 200 sX 'G' 460 sx Class 'G' Liner Tieback: 285 sx Lite, 276 sx 'G' 132 sx Class 'G' iTjEl'r\lê3 DEPTH SET (MD) 9824' " PACKER SET (MD) 9767' ~" DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect with 75 Bbls Diesel Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE GAs-McF 2,984 GAs-McF 17,904 WATER-BBl 208 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): September 17, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BBl 9/18/2004 4 TEST PERIOD -+ 377 Flow Tubing Casing Pressure CALCULATED ....... Oll-BBl Press. 25~ 780 24-HoUR RATE""'" 2,261 WATER-BBl 1,248 CHOKE SIZE I GAS-Oil RATIO 90° 7,917 Oil GRAVITY-API (CORR) 26.5 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach ~wt,~- if necessary). Submit core chips; if none, state "none". RËCt::.\ V ¡::'L.I None@!i'1))2t? 0 RJ , G I f\. ¡f A· L 5£ P '2 1 2004 .. S~~l ~;; iì)t:J;' I ,. J I \! CommIsSIon . & Gas cons. .~ ~M L._^~ 27. Gf (; · 28. .. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10005' 8513' None Shublik 10046' 8549' Sadlerochit 10132' 8632' Top CGL 10326' 8814' Base CGL 10458' 8894' 25P 10591' 8951' 24P 10729' 9025' 22P 10765' 9050' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /C,' T'tl T h· I A . t t Terrie Hubble I e ec nlca SSIS an Date 09·?{~O PBU N-07 A Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Ken AI/en, 564-4366 204-105 Permit No. I A roval No. 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only · STATE OF ALASKA . ALASKA ~L AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil DGas D Plugged D Abandoned D Suspended DWAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 181 Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to ~ Number BP Exploration (Alaska) Inc. 8/10/2004 ·~105 3. Address: 6. Date Spudded 13. API Number ~ P.O. Box 196612, Anchorage, Alaska 99519-6612 7/18/2004 50-029-20137- 1-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 7/19/2004 PBU N-07 A 3061' SNL, 4709' WEL, SEC. 08, T11N, R13E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 3037' SNL, 979' WEL, SEC. 08, T11N, R13E, UM 72.25' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2976' SNL, 1157' WEL, SEC. 08, T11N, R13E, UM 10745 + 9036 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 634414 y- 5968123 Zone- ASP4 10832 + 9098 Ft ADL 028282 TPI: x- 638143 y- 5968215 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 637964 y- 5968273 Zone- ASP4 (Nipple) 2119' MD 18. Directional Survey 19. Water depth. if offshore 20. Thickness of Permafrost 181 Yes DNo N/A MSL 1900' (Approx.) 21. Logs Run: DIR I GR I RES 22. CASING, LINER AND CEMENTING RECORD ~~~~~i :;)$'TII\!Q. .SET"rII\!$DEPTH iT\IQ ~~E;i i ii··i i V'/T. PER ;:T. ·..GAADE lOP ~rrOM TOP I BOTTOM iii PIII,,,n 20" 94# H-40 Surface 100' Surface 100' 24" 122 sx Permafrost 13-3/8" 72# N 80 Surface 2618' Surface 2618' 18-1/2" 3786 sx Permafrost II 9-518" 47# N-80 Surface 9635' Surface 8193' 12-1/4" 1270 sx Howco LiQht. 200 sx 'G' 7" 29# N-80 8923' 10004' 7589' 8512' 8-1/2" 460 sx Class 'G' 7" 26# L-80 27' 8931' 27' 7595' N/A Liner Tieback: 285 sx Lite, 276 sx 'G' 4-1/2" 12.6# L-80 9826' 10832' 8358' 9098' 6" 132 sx Class 'G' 23. Perforations open to Production (MD + TVD of TOE and 24.i J61N~ .·i.ii.· ··¡·i..i ii.·.··... Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6spf 4-1/2", 12.6#,13Cr 9824' 9767' MD TVD MD TVD 10539' - 10559' 8929' - 8938' 25. ð819·.··.. 10571' - 10596' 8943' - 8953' .....~.._.. ii· 10634' - 10639' 8970' - 8973' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect with 75 Bbls Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production Yet N/A Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-McF WATER-BSl CHOKE SIZE GAS-Oil RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED ~ Oll-Bsl GAs-McF WATER-BSl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips' if none, state "none". RECEIVED rèüMPLETJON SEP 1 ~~ ?H\\~ None \ zlJ¥~ ~, ! ~~~~~t'... SfP ... 9 2004 \ ~F¡EJ) (,I:::' ¡' ~. I"'\f"'\If"ltd ^ I Alaska Oil & Gsa. rA_ ---_. ,.. Form 10-407 Revised 12/2003 ~~.II .,uu~~ ·w, .vlOn I D'UN "~VW:KS Anch r· o age G 28. GEOLOGIC MARKERS 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD rvD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10005' 8513' None Shublik 10046' 8549' Sadlerochit 10132' 8632' Top CGL 10326' 8814' Base CGL 10458' 8894' 25P 10591 ' 8951' 24P 10729' 9025' 22P 10765' 9050' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ T'tl T h· I As . t t D t Nì Terrie Hubble .......-, 0 I e ec nlca 515 an a e U'í PBU N-07 A 204-105 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. I A roval No. Drilling Engineer: Ken Allen, 564-4366 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Printed: 7/27/2004 11 :48:29 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-07 N-07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 7/2/2004 Rig Release: 7/22/2004 Rig Number: Spud Date: 6/17/1974 End: 7/22/2004 7/7/2004 06:00 - 00:00 18.00 MOB P PRE Disconnect mud & service lines. Bridle up & lower derrick. Move Shop, Pit Complex & Satellite Camp to N Pad. Start to move Sub - some problems with soft A Pad access road. Matted same and began moving Sub. 7/8/2004 00:00 - 10:45 10.75 MOB P PRE Move Sub from A-Pad to N-Pad. 10:45 - 20:00 9.25 RIGU P PRE Mat around cellar& spot Sub over Well. Spot Pit Complex & Shop. Hook up interconnect. Berm Cellar. Inspect & raise Derrick. Raise cattle chute, bridle down. Hook up blocks to Top Drive. R/U Top Drive & rig floor. Begin taking on both fresh water & sea water. RIG ACCEPTED @ 20:00 HRS. 7/8/2004. 20:00 - 22:00 2.00 RIGU P PRE Clean Rig. Derrick down move in rain flooded all walkways. Mopped up and made safe. Continued taking on seawater. 22:00 - 22:30 0.50 WHSUR P DECOMP R/U secondary kill line to tubing annulus valve on wellhead. 22:30 - 23:30 1.00 WHSUR P DECOMP R/U DSM lubricator & pull BPV. RID DSM. 23:30 - 00:00 0.50 CLEAN P DECOMP R/U Circulating lines. Test to 3000 psi. Displace diesel freeze protect to 8.4 ppg seawater. 7/9/2004 00:00 - 01 :30 1.50 CLEAN P DECOMP Displace Freeze protect diesel with 8.4 ppg seawater @ 5 BPM /140 psi. Circulate until clean. Monitor well - allow to balance. Well stable & dead. 01 :30 - 02:30 1.00 WHSUR P DECOMP Set TWC & test from below to 1000 psi. 02:30 - 04:30 2.00 WHSUR P DECOMP N/D Tree & adapter flange. Check Tubing hanger - BTC threads in excellent condition - screw in XO 9 1/2 Turns. Function all LDS to insure full travel. 04:30 - 07:00 2.50 BOPSU DECOMP N/U BOPE. 07:00 - 12:00 5.00 BOPSU DECOMP R/U & test BOPE to 250 psi. low & 3500 psi. high. R/D test equipment. 12:00 - 13:00 1.00 BOPSU DECOMP Pull flow riser, re-cut to fit & reinstall same. 13:00 - 14:00 1.00 PULL DECOMP R/U DSM lubricator. Pull TWC. R/D DSM. 14:00 - 14:45 0.75 PULL DECOMP M/U landing joint. BOLDS, Pull Hanger to floor. Up wt 75K to 110K. 14:45 - 16:00 1.25 PULL P DECOMP Circulate @ 5 BPM, 50 psi. while R/U to UD tubing. 16:00 - 19:30 3.50 PULL P DECOMP Pull & UD 46 Jts of 4 1/2" Tubing. 19:30 - 20:15 0.75 PULL P DECOMP SSSV would not pull through collapsed ThermoCase " casing @ 125'. Pulled 185K to wedge SSSV into collapsed area in order to pull with casing. 20:15 - 00:00 3.75 PULL P DECOMP PJSM. R/ U Schlumberger E-Line. RIH with 215/16" Jet Cutter and shoot @ 102'. POH w/ tools. Remove top sheave from blocks. Pull on tubing - not parted. Pull 130K - tubing parted. RID SWS. 7/10/2004 00:00 - 00:30 0.50 PULL P DECOMP POH with 3 Jts and 7' stub of 4 1/2" Tubing. Recovered 1 clamp for total of 24. (26 run originally - 2 left in well) Encapsulaed control line was not cut with tubing and remains in hole. 00:30 - 02:00 1.50 PULL P DECOMP Rig down tubing tongs and clear floor. Utilize blocks to pull control line. Recovered approximately 100 ft. each of dual control line, wire rope strand and sleeve. 02:00 - 04:00 2.00 BOPSU P DECOMP Nipple down BOPE. 04:00 - 04:30 0.50 WHSUR P DECOMP Rig up bleed tank & bleed 30 psi. of gas pressure off 103/4" X 133/8" Annulus. 04:30 - 07:00 2.50 WHSUR P DECOMP Nipple down Tubing Head. Remove 9 5/8" pack-off and secure slips to casing stub. Function Lock down screws. Cahnge out 1 Lock down screw.. 07:00 - 10:00 3.00 BOPSU P DECOMP Nipple up Spacer Spool and BOPE. Printed: 7/27/2004 10:45:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-07 N-07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 7/2/2004 Rig Release: 7/22/2004 Rig Number: Spud Date: 6/17/1974 End: 7/22/2004 Pressure test BOPE breaks to 1500 psi. Pick up 9 5/8" fishing spear with pack-off to recover Thermo Case" Casing. 12:00 - 13:00 1.00 FISH P DECOMP RIH with spear assy. Pull casing from PBR at 2045'. Pulled 315 K (189K over) to unseat hanger. Pulled casiing to the floor with the slips attached to the stub and removed same. 13:00 - 14:30 1.50 CHEM P DECOMP R/U Little Red to pump. Pump 50 Bbls, 185 degree, MAPCO 200 down annulus. Spear packoff leaking. 14:30 - 15:30 1.00 FISH P DECOMP R/U false bowl for 11 3/4" casing. Land casing, remove spear and change out pack-off cup rubber. 15:30 - 17:30 2.00 CHEM P DECOMP Continue reverse circulating with Little Red hot oil unit pumping for a total of 100 Bbls of 185 degree MAPCO 200 down annulus. Switch to pump down the casing and pump 57 Bbls MAPCO 200 the long way down casing taking returns through choke and gas buster. Rig down Little Red. Open Annular and and pump down casing with 120 degree seawater treated with 2 drums of Safe Surf-O. Safe -Surf 0 at surface after only 55 bbls pumped. Calculate that there is a hole in Therm 0 Casing at 125'. 17:30 - 18:00 0.50 FISH P DECOMP Lay down spear fishing assy. 18:00 - 19:30 1.50 FISH P DECOMP R/U to pull casing. Break out stump. Threads are pemium Hydril not Buttress. R/D casing equipment & P/U Spear. Engage spear and pull casing to retrieve 9.65' pup Jt. as per casing tally. NO PUP JT. Therm 0 Casing are 9 5/8" Hydril flush Joint, requiring a lifting sub. UD Fishing tools. 19:30 - 21 :00 1.50 FISH N WAIT DECOMP Locate and secure Hydril Pin by Buttress Box, 3' long lifting sub. 21 :00 - 00:00 3.00 FISH P DECOMP Utilizing lifting sub to pull 11 3/4" X 9 5/8" Therm 0 Casing. Found 4 1/2 tubing fish inside collapsed Jt of casing. Used mechanical cutter to cut off 7' of tubing sticking out of top of third Jt. Pulled third Jt and discovered 1/3 of jt to be collapsed with a what appears to be a large gash through both casings. RIU false bowl on top of casing and break out SSSV on 4 1/2" tubing fish just below third joint. 7/11/2004 00:00 - 00:30 0.50 FISH P DECOMP Lay down 2 jts 4 1/2 "tubing and 20.5' stub. Stub has extemely clean chemical cut. All 4 1/2 tubing recovered from first cut at 2100'. Top of remainder of 41/2" tubing fish at +/- 2100'. 00:30 - 01 :30 1.00 FISH P DECOMP R/U to circulate - unable to make up circ. head into 103/4" Jt. - threads galled. POH 1 Jt and M/U Circ head. (160' off PBR) 01 :30 - 04:30 3.00 CLEAN P DECOMP PJSM with all personnel. Pressure test Little Red hot oil unit lines to 1500 psi. Pump 50 Bbls, 180 degree, MAPCO 200 down annulus at 2 BPM 150 psi. Switch lines and pump an additional 50 bbls MAPCO 200 down casing. Switch to Rig and pump 120 degree seawater treated with Safe Surf 0 down casing at 5.75 BPM with 190 psi. Circulated out Arctic pack through gas buster & over shakers. Well bore cleaned up nicely. 04:30 - 10:00 5.50 FISH P DECOMP POH with 103/4" Casing fish - 44 Jts. Taking 40K ftllbs to break connections. C/O Elevators & power tongs. UD 2 jts 9 5/8" Csg, ported collar & seal assembly. 10:00 - 12:00 2.00 FISH P DECOMP Clear floor of casing equipment and clean same. Load pipe shed with 4" drill pipe & BHA. Printed: 7/27/2004 10:45:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-07 N-07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 7/2/2004 Rig Release: 7/22/2004 Rig Number: Spud Date: 6/17/1974 End: 7/22/2004 7/11/2004 12:00 - 13:30 1.50 FISH P DECOMP Make up Fishing BHA #2 - 4 1/2" Overshot Assembly. 13:30 - 15:30 2.00 FISH P DECOMP RIH picking up 4" drill pipe. Tag fish @ 2088' 15:30 . 15:45 0.25 FISH P DECOMP Unable to swallow fish without pump. Wash over and engage fish with overshot. Pull 170K - Fish free. 15:45 - 19:30 3.75 FISH P DECOMP Circulate @ 6.5 BPM - 350 to 400 psi. Gas migrating up. also seeing Arctic Pac over shakers. Shut down pumps. Monitor well - Stable. 19:30 . 21 :00 1.50 FISH P DECaMP POH wI Drill Pipe. 21 :00 - 22:30 1.50 FISH P DECaMP Stand back Drill Collars. Release fish from overshot. UD fishing tools. 22:30 . 00:00 1.50 FISH P DECOMP I POH laying down 4 1/2" tubing. 7/12/2004 00:00 . 05:00 5.00 FISH P DECOMP POH laying down total of 201 Jts 41/2" tubing, XO & 15' long stub of 3 1/2" tubing. 05:00 - 06:00 1.00 BOPSU P DECaMP M/U BOP jetting tool. Jet wash BOP & Casing Head. 06:00 - 07:00 1.00 WHSUR P DECOMP I Set test plug. Test lower BOP & Casing head flanges to 3500 I psi. Pull test plug. Run Wear Bushing. 07:00 - 07:30 0.50 CLEAN P DECOMP Service Top Drive. 07:30 - 09:00 1.50 CLEAN P DECOMP I P/U & M/U Scraper I Polish Mill BHA. 09:00 - 10:30 1.50 CLEAN P DECaMP RIH and tag bottom of 9 5/8" PBR @ 2071 '. 10:30 . 11 :00 0.50 CLEAN P DECOMP I PJSM wI all personnel. R/U Little Red to pump MAPCO 200. Test lines to 2700 psi. 11 :00 - 13:30 2.50 CLEAN P DECOMP Break circulation wI seawater @ 5 BPM - 100 psi. Rotating @ 80 RPM. Dress PBR & pump 50 Bbls, 180 degree, MAPCO 200 followed by 100 Bbls of 120 degree seawater. Increase rate to 6.5 BPM - 165 psi. Pump until clean. 13:30 - 15:00 1.50 EVAL P DECOMP Shut in & Test all casing. Pressured up to 3000 psi. Injecting @ 1 BPM. started taking fluid @ 2600 psi. Shut down pumps & lost 1000 psi in 10 minutes. 15:00 - 17:00 2.00 CLEAN P DECOMP POH & UD Scraper I Polish Mill Assembly. 17:00 - 19:00 2.00 EVAL P DECOMP RIH w/2 stands of 61/4" DC's, P/U 95/8" RTTS and RIH on DP to 2300". 19:00 - 19:30 0.50 EVAL P DECaMP Circulate DP volume @ 4 BPM - 55 psi. 19:30 - 21 :00 1.50 EVAL P DECOMP Set RTTS @ 2109. Attempt to test down DP. Circulating valve open. Make numerous attempts to close valve with no success. 21:00·23:15 2.25 EVAL N DFAL DECOMP POH with RTTS UD. MIU Champ III Packer & RIH to 2300' 23: 15 - 00:00 0.75 EVAL P DECOMP Circulate DP volume. Set Packer @ 2108'. Test 9 5/8"casing ,7" casing & cement plug. Started taking fluid @ 2325 psi. Shut down pump. Lost 400 psi in 5 minutes then only 100 psi in next 20 minutes. 7/13/2004 00:00 - 01 :30 1.50 EVAL P DECaMP Test down backside to 3000 psi - testing 133/8" casing & 9 158" Lap. Good Test. Hold & Chart for 30 minutes. 01 :30 - 03:00 1.50 EVAL P DECOMP POH & UD 9 5/8" Champ III Packer. 03:00 - 04:00 1.00 EVAL P DECOMP Clear & clean rig floor, service rig. 04:00 - 06:30 2.50 EV AL P DECOMP PJSM R/U SWS. MIU 6.05 Gauge ring & junk basket. RIH. Could not get through 7" seal assy stub @ 8918. POH for slightly smaller gauge ring. Recovered 1 SS control line band and some rubberin JB. 06:30 - 08:30 2.00 EVAL P DECOMP CIO Gauge ring to 5.975". RIH to 10,083. POH retrieved more rubber from control line bands. 08:30 - 11 :30 3.00 PXA P DECOMP M/U 7" EZSV, Gamma Ray & CCL. RIH to 10,046. Hung up. Set EZSV @ 10,046'. POH wI E-Line & Tools. 11 :30 - 12:00 0.50 PXA P DECOMP Close Blind rams attempt to test below to 3000 psi. No test- taking fluid @ 2350 psi. Printed: 7/27/2004 10:45:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-07 N-07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 7/2/2004 7/22/2004 Spud Date: 6/17/1974 End: 7/22/2004 7/13/2004 12:00 - 14:30 2.50 EVAL P DECOMP M/U & RIH with 8.48" Gauge Ring & JB in 9 5/8" casing. Tag 7" stub @ 8,918'. POH & RID SWS. 14:30 - 21 :00 6.50 EVAL P DECOMP P/U, M/U & RIH with 95/8" Champ III Test Packer, P/U DP from shed. RIH to 8904' 21 :00 - 22:30 1.50 EVAL P DECOMP Break circulation & fill lines. Set Champ @ 8900'. Test below Packer to 3000 psi. - Good Test. Test down annulus from surface to packer. Pumping away @ 2325 psi. Shut down and lost 500 psi in 10 minutes. Bleed off and release Champ Packer. 22:30 - 00:00 1.50 EVAL P DECOMP POH with Champ Packer. 7/14/2004 00:00 - 00:45 0.75 EVAL P DECOMP POH with Champ III Packer to 6036'. 00:45 - 02:00 1.25 EVAL P DECOMP Set Champ Packer @ 6,040'. Pressure down DP testing from 6,040 below. Pumping away @ 2350 psi. Bleed off same as before. Pump down annulus pressuring up to 3000 psi. Casing good from 6,040 to surface. Leak is in 9 5/8" casing between 8,900' and 6,040'. Bleed pressure and release Champ III. 02:00 - 04:30 2.50 EV AL P DECOMP POH and UD Champ III Packer. 04:30 - 06:00 1.50 CLEAN P DECOMP P/U & M/U Baker overshot Dressing assembly. 06:00 - 10:00 4.00 CLEAN P DECOMP RIH with Baker Dressing I Washover assembly to 8,838'. 10:00 - 12:30 2.50 CLEAN P DECOMP Wash over & dress 7" Casing stub @ 8923' (DD). 242 GPM @ 450 psi. Rotating @ 120 RPM. Torque on bottom = 5 to 7K, off bottom = 3.5K, P/U Wt. = 177K, Dn Wt. = 150K, Rot Wt.= 165K. Circulate Hi-Vis Sweep @ 580 GPM 12020 psi. Pump dry job. 12:30 - 16:00 3.50 CLEAN P DECOMP POH to BHA standing all back. 16:00 - 18:00 2.00 CLEAN P DECOMP UD Baker Dressing Mill BHA. 18:00 - 19:30 1.50 CASE P DECOMP Pull Wear Bushing. CIO top rams to 7". Set test plug & test door seals to 3500 psi. Pull test plug. 19:30 - 21:30 2.00 CASE P DECOMP Rig up to run 7" Casing. PJSM with all personnel. 21 :30 - 00:00 2.50 CASE P DECOMP MIU Unique Overshot, Float Collar, Insert Landing Collar & ES Cementer with associated pup jts. Make up 1 st full Jt of 7", 26#, L-80, BTC-M Casing. Fill casing with Franks tool & check float - OK. Continue running 7" Casing. 7/15/2004 00:00 - 08:00 8.00 CASE P DECOMP Run 218 Jts 7",26#,L-80, BTC-M Casing to 8903'. 08:00 - 09:00 1.00 CASE P DECOMP Make up Jt. # 219. Pump @ 168 GPM 1188 psi. & Wash over 7" Stub @ 8925'. Wash 8' to 8933'. Set down 10K. Pick up String 2' to set Unique Overshot @ 8,931'. 09:00 - 10:00 1.00 CASE P DECOMP UD Franks Tool, Drop ES opening ball & RIU Cement Head. 10:00 - 11 :00 1.00 CASE P DECOMP Circulate ball down to landing collar. ES Cementer opened with 2000 psi. Circulated through ES Cementer @ 6 BPM I 280 psi & at 7 BPM I 388 psi. 11 :00 - 14:00 3.00 CASE P DECOMP PJSM with all - CO.Man Toolpusher, MI Eng., Dowell & Vac Truck drivers. Perform Cement job as follows: Test Dowell Cement Lines to 3000 psi. With rig pumps - pump 263 Bbls MAPCO 200 @ 5 BPM 1250 psi. Switch to Dowell & pump 106 Bbbls. (285 sX), 12.5 ppg, 2.09 yield, Lead Slurry @ 6 BPM. Follow with 57 8Bls,(276 sX), 15.8 ppg, 1.16 yield Tail Slurry. Drop closing plug and chase with 5 bbls water to clear Dowell lines. Switch to rig pumps and displace with 340 Bbls Seawater. ES Printed: 7/27/2004 10:45:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-07 N-07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 7/2/2004 Rig Release: 7/22/2004 Rig Number: Spud Date: 6/17/1974 End: 7/22/2004 7/15/2004 11 :00 - 14:00 3.00 CASE P DECOMP Cementer closed @ 2560 psi.- hold for 5 minutes. Bleed & Check Float - OK. 10 Bbls Good MAPCO 200 to surface. CIP @ 13:50 14:00 - 15:00 1.00 CASE P DECOMP RID Cement Head, Flush Stack, Pump seawater out of 7" casing down to Casing Head. 15:00 - 16:00 1.00 CASE P DECOMP NID BOP. Pick up Stack. Set Slips with 180K String Weight. 16:00 - 18:00 2.00 CASE P DECOMP R/U Cameron 'Wachs" Casing Cutter & cut off casing to specs. UD Jt # 219 and 0.82' of Jt # 218. 18:00 - 20:00 2.00 CASE P DECOMP Set back BOP Stack onto stump. Remove spacer spool from cellar. Install tubing Spool. 20:00 - 21 :00 1.00 CASE P DECOMP Plastic pack void to energize inner seal and test Pack-Off & Flange to 4300 psi. 21 :00 - 22:30 1.50 CASE P DECOMP N/U Tubing Spool & BOP 22:30 - 23:30 1.00 CASE P DECOMP Remove 7" Casing rams from Stack & Install 3 1/2" X 6" Variables. 23:30 - 00:00 0.50 CASE P DECOMP RU to test. Run test plug. 7/16/2004 00:00 - 00:30 0.50 CASE P DECOMP Test Upper Pipe Rams, Tubing Spool & Flanges to 250 psi. Low & 3500 psi. High. Pull Test Plug. 00:30 - 01 :00 0.50 CASE P DECOMP Install Wear Bushing & P/U 3 1/2 elevators. 01 :00 - 03:30 2.50 CASE P DECOMP P/U & M/U & RIH with Cleanout BHA: 6" Bit, BIS, 6.059" String Mill, Bumper Sub, Oil Jars, 9 ea. 4 3/4" De's, XO, 18 Jts of 4" HWDP. 03:30 - 05:15 1.75 CASE P DECOMP P/U, M/U & RIH with 69 Jts 4" DP. 05:15 - 07:30 2.25 CASE P DECOMP RIH with stands of 4" from derrick to 8683'. 07:30 - 08:30 1.00 CASE P DECOMP Break circulation. wash down to TOC @ 8850' 08:30 - 11 :00 2.50 CLEAN P DECOMP Drill Cement, Plug, ES Cementer, Landing Collar & Float Collar @ 340 GPM 11350 psi., Rotating @ 80 RPM. Torque = 7500 on bottom. PU Wt. = 235K, Dn Wt = 140K, Rot Wt = 160K 11 :00 - 13:00 2.00 CLEAN P DECOMP Tag EZSV @ 10,046'. Set down 10K - Plug moved down hole to 10,078' - Set down 25K - OK. Pump Hi-Vis Sweep & Circulate until clean. Pump @ 525 GPM I 2230 psi. 13:00 - 14:00 1.00 CASE P DECOMP R/U to test 7" Casing. Test 7" Casing to 3500 psi, Hold & Chart for 30 minutes. RID Test Equipment. 14:00 - 15:00 1.00 CLEAN P DECOMP Displace Wellbore with 8.4 ppg. FloPro Mud @ 525 GPM I 2050 psi. 15:00 - 16:00 1.00 CLEAN P DECOMP POH to 8874'. 16:00 - 17:30 1.50 CLEAN P DECOMP Cut & Slip 139' of Drilling Line. Service Top Drive. 17:30 - 21 :00 3.50 CLEAN P DECOMP POH to BHA. 21 :00 - 22:00 1.00 CLEAN P DECOMP Break out & UD Clean out BHA. 22:00 - 00:00 2.00 STWHIP P WEXIT M/U Whipstock I Milling BHA & orient MWD. 7/17/2004 00:00 - 05:30 5.50 STWHIP P WEXIT RIH with Whipstock I Milling Assembly @ 90 to 120 seconds per stand to 10,025' 05:30 - 06:00 0.50 STWHIP P WEXIT Break circulation and orient Whipstock to 89 degrees left of highside. 06:00 - 06:30 0.50 STWHIP P WEXIT Set whipstock with 12K down wt. Set 25K down to shear out. TOW = 10,004' 06:30 - 11 :30 5.00 STWHIP P WEXIT Mill Window from 10,004' to 10,016'. Mill open hole to 10,031' wI 250GPM @ 1550 psi. TO = 6 to 10K WOB = 2 to 6K milling casing & 10 to 14K milling in formation. Rotating @ 112 RPM. Up Wt. = 187K, Dn Wt. = 155K, Rot Wt = 165K. 11 :30 - 13:00 1.50 STWHIP P WEXIT Circulate Hi-Vis Sweep. Work milling assembly through Window with and without rotation. Window is Clean. Total Printed: 7/27/2004 10:45:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-07 N-07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 7/2/2004 Rig Release: 7/22/2004 Rig Number: Spud Date: 6/17/1974 End: 7/22/2004 7/17/2004 11 :30 - 13:00 1.50 STWHIP P WEXIT metal recovered = 188 Ibs. Continue C&C until clean & balanced. 13:00 - 13:30 0.50 STWHIP P WEXIT Perform FIT. - 8.5 ppg Mud, 8515 TVD, 665 psi surface pressure = 10.02 ppg EMW FIT. 13:30 - 17:00 3.50 STWHIP P WEXIT Monitor Well - Static. Pump dry job. POH to Milling BHA. 17:00 - 19:30 2.50 STWHIP P WEXIT POH & UD Milling BHA. Upper string mill in full gauge. 19:30 - 20:30 1.00 STWHIP P WEXIT Pull Wear Bushing, Jet wash BOP & tubing Head. Re-Install Wear Bushing. 20:30 - 22:00 1.50 STWHIP P WEXIT P/U & M/U 2 degree Directional Drilling BHA. Orient & Surface test MWD. 22:00 - 22:30 0.50 STWHIP P WEXIT Service Top Drive & Rig. 22:30 - 00:00 1.50 STWHIP P WEXIT RIH with wI Directional Drilling BHA. 7/18/2004 00:00 - 02:30 2.50 STWHIP P WEXIT RIH to 9,950'. 02:30 - 03:00 0.50 STWHIP P WEXIT Break circulation. Take SPR's. Orient MWD 90 Deg. Left. Shut down pumps and slide through window with no problems. 03:00 - 14:00 11.00 DRILL P PROD1 Directional Drill 6" Hole from 10,031' to 10,415'. 250 GPM I 2040 psi. on bottom & 1750 psi. off bottom, WOB = 15 to 40K, Up Wt = 205K, Dn Wt = 155K. All slide - All down. AST = 7.57 Hrs. 14:00 - 15:00 1.00 DRILL P PROD1 Spot Hi-Vis Sweep around BHA & Pump out of the hole to 9,945'. 15:00 - 16:00 1.00 DRILL P PROD1 Circulate Hi-Vis Sweep out of hole @ 250 GPM & 1700 psi. Rotating @ 80 RPM wI 3000 ftllbs Torque. 16:00 - 20:00 4.00 DRILL P PROD1 Monitor Well, Pump dry job. POH to BHA. 20:00 - 20:30 0.50 DRILL P PROD1 Download MWD I LWD. 20:30 - 22:00 1.50 DRILL P PROD1 Change out motor to 1.5 Degree Air Drill PDM, C/O Bit. RIH wI BHA #3 & sutface test MWD. 22:00 - 00:00 2.00 DRILL P PROD1 RIH with BHA # 3. 7/19/2004 00:00 - 02:30 2.50 DRILL P PROD1 RIH to 9,950', filling pipe every 2500'. 02:30 - 15:00 12.50 DRILL P PROD1 Slide through window and on to bottom with no problems. Directional Drill 6" Hole from 10,415' to 10,832'.250 GPM I 1720 psi. WOB = 20 to 40K, Up Wt = 21 OK, Dn Wt = 155K, Rot Wt.= 168K. Torque on bottom = 5K, Torque off bottom = 4.5K, RPM = 80. ART = 1.81 Hrs. AST = 7.54 Hrs. 15:00 - 16:30 1.50 DRILL P PROD1 Circulate Hi-Vis Sweep @ 275 GPM & 1880 psi. rotating @ 110 RPM wI 4000 ftllbs of torque. Spot Lube Pill through open hole. 16:30 - 21 :00 4.50 DRILL P PROD1 POH to Window, pump dry job, drop rabbit wI tail & POH to BHA. 21 :00 - 22:00 1.00 DRILL P PROD1 Lay down BHA. 22:00 - 00:00 2.00 CASE P PROD1 R/U to run 4.5" Production Liner. PJSM with all Hands. M/U, Bakerlok & RIH wI Shoe Track. 7/20/2004 00:00 - 01 :00 1.00 CASE P PROD1 Run 4.5", 12.6#, L-80 BTC-M Production Liner - 23 Jts + 20' Marker, 'HMC" Liner Hgr & 'ZXP' liner Top Packer wI C-2 running tool. M/U XO, 10' DP Pup + 1 Jt DP. Rig down casing equipment. 01 :00 - 06:00 5.00 CASE P PROD1 Circulate liner volume @ 4 bpm. 145 psi. Up weight = 48k down weight = 48k. Continue RIH with 4.5" liner on 4" DP to 9,949' fill pipe every 10 stds. 06:00 - 07:00 1.00 CASE P PROD1 Circulate bottoms up at 9,949' staging pumps up to 6 bpm @ 930 psi. Up weight = 183k down weight = 155k. Make up cement head on joint of DP and lay on skate. 07:00 - 08:30 1.50 CASE P PROD1 Continue to RIH from 9,949' to 10,715'. Wash from 10,715' to Printed: 7/27/2004 10:45:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-07 N-07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 7/2/2004 Rig Release: 7/22/2004 Rig Number: Spud Date: 6/17/1974 End: 7/22/2004 7/20/2004 07:00 - 08:30 1.50 CASE P PROD1 10,832' Up weight =205k down weight = 160k 08:30 - 09:30 1.00 CEMT P PROD1 Circulate 1.5 bottoms up. PJSM with Co Rep, Toolpusher, Cementers and all rig personei. 09:30 - 11 :00 1.50 CEMT P PROD1 Pump 5 bbls of water test lines to 4,000 psi, pump 1~ water pre flush followed by 15 bbl 9.5 ppg Mud push, 7 Is of 15.8 ppg class G cement, wash up lines down ris , rop DP dart and displace with rig pumps at 6.5 bpm. latched up liner wiper plug with calculated strokes, bumped plug pressure up to 4,000 psi to set liner hanger. hold pressure apply 50k down to set hanger, bleed off pressure and check floats. rotate string 20 turns to the right, apply 1000 psi to DP, picked up until pressure bled off to exposing rotaing dog sub, circulate 10 bbls at 2.5 bpm to move cement up the hole. Set down 45k to set ZXP liner top packer twice. Rotate string at 15 rpm slack off 25k to ensure packer set. 11 :00 - 11 :30 0.50 CEMT P PROD1 Circulate bottoms up at 6 bpm. (7 bbls cement to surface) 11 :30 - 12:00 0.50 CEMT P PROD1 Lay down cement head and joint of 4" DP. 12:00 - 13:30 1.50 CEMT P PROD1 Displace well to seawater at 6 bpm @ 1750 psi 13:30 - 20:30 7.00 CEMT P PROD1 POH, rack back 50 stands of 4" DP, lay down 198 jts. 20:30 - 21 :30 1.00 RUNCO RUNCMP Rig up testing equipment, Test 4.5" liner to 3,500 psi for 30 min. record on chart. Rig down test equipment. 21 :30 - 23:00 1.50 RUNCMP Rig up 4.5" chrome tubing equipment, pull wear ring, Make dummy run with tubing hanger. 23:00 - 23:30 0.50 RUNCMP PJSM with CO Rep, Toolpusher, Baker, and rig crew, run completion. 23:30 - 00:00 0.50 RUNCMP Make up and run 4.5" 12.6# 13CR Completion Tail Assy, 'X' Nipple Assy and Baker S-3 Packer Assy. Bakerlok all connections below Packer. 7/21/2004 00:00 - 12:00 RUNCMP Held PTSM, Continue running 4.5" 12.6# 13CR VAM-TOP Tubing as per running order. Torque to 4,400 Nibs. Ran a total of 228 joints plus jewelry. Up weight = 235k, down weight = 120k 12:00 - 14:30 2.50 RNTBH P TUBHGR Picked up joints # 229 & 230 to space out tubing, bottomed out in tieback extension 4.5' high. Pulled above the tieback, rotated pipe 3/4 turn to right while slacking off, stacked out in the same place, repeated this two more times with the same results. Lay down joints 228 -230, and make up 3 space out pups totaling 21.84' pickup joint 228, make up landing joint and hanger land tubing and RILDS. 14:30 - 15:30 1.00 CONDH P OTHCMP Rig up and reverse circulate 67 bbls clean seawater with corrosion inhibitor, followed by 117 bbls seawater with no additives, at 3 bpm with 270 psi. 15:30 - 16:30 1.00 CONDH OTHCMP Lay down landing joint, rig down tubing handling equipment. 16:30 - 00:00 7.50 CONDH OTHCMP Rig up Schlumberger slick line unit, RIH and pull RHC plug in XN nipple, run 3.7" gauge ring to ensure tools will pass through Tieback extension, ran gauge ring to 10,738', POH with gauge ring, and install RHC plug in XN nipple. 7/22/2004 00:00 - 01 :00 1.00 SIT P WHDTRE Held PTSM, POH with slick line, drop 1 7/8" ball and rod, back out landing joint, rig up to set and test packer. 01 :00 - 03:00 2.00 SIT P WHDTRE Pressure up on tubing to 3,500 and set packer, hold for 30 min. record on chart, bled tubing pressure to 2,000 psi. Pressure up on annulus to 3,500 psi. and hold for 30 min. record on chart. Bled annulus pressure to zero, bled tubing pressure to zero. Printed: 7/27/2004 10:45:51 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-07 N-07 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 7/2/2004 Rig Release: 7/22/2004 Rig Number: Spud Date: 6/17/1974 End: 7/22/2004 09:00 - 10:30 1.50 WHSUR P Pressure up on annulus to shear DCk valve in GLM #3 valve sheared at 2,300 psi. Pumped through valve both ways. WHDTRE Rig down test equipment, and blow down high pressure lines. WHDTRE Install TWC, test from below to 1,000 psi. WHDTRE Nipple down riser and BOPS. WHDTRE Nipple up adapter flange and tree, test to 5,000 psi. WHDTRE Rig up DSM lubricator and pull TWC, rig down lubricator. WHDTRE Rig up Little reds and test lines to 2,500 psi. Pump 75 bbls diesel down 4.5" X 7" annulus to freeze protect tubing and annulus to 2,200' @ 3 bpm 1,800 psi. WHDTRE U-Tube diesel from annulus to tubing, zero pressure, rig down Little Reds. WHDTRE Install BPV and test from below to 1,000 psi. WHDTRE Blow down high pressure lines, secure well, (Move Pits) 03:00 - 03:30 03:30 - 04:00 04:00 - 05:00 05:00 - 07:30 07:30 - 08:00 08:00 - 09:00 0.50 BOPSU 0.50 BOPSU 1.00 BOPSU P 2.50 WHSUR P 0.50 WHSUR P 1.00 WHSUR P 10:30 - 11 :00 11 :00 - 12:00 0.50 WHSUR P 1.00 WHSUR P Release Rig @ 12:00 hrs. 7/22/2004 Printed: 7/27/2004 10:45:51 AM e e N-07A Prudhoe Bay Unit 50-029-20137 -01-00 204-105 Accept: Spud: Release: Ri: 07/08/04 07/18/04 07/22/04 Nabors 7ES POST RIG WORK 08/02/04 RIGGED UP & PRESSURE TESTED SURFACE EQUIP. 08/03/04 PULLED BALL & ROD FROM RHC PLUG BODY @ 9787' SLM. PULLED DGLV FROM STA #3 @ 6303', DCK FROM STA #4 @ 3302' & SET GENERIC GL DESIGN. PULLED RHC PLUG BODY FROM XN-NIP @ 9788' SLM. DRIFTED W/2 7/8" DUMMY GUN TO 10719' SLM. NOTIFY PAD OP. WELL LEFT SI. 08/04/04 LOGGED RST FROM TD @ 10730 TO 9900 AS REQUESTED IN PROGRAM AND TRANSMITTED ASCII DATA FILES TO TOWN FOR PERFORATION PICKS. LOGGED FIRST PASS THROUGH NEW TUBING COMPLETION JEWELRY AND TIED INTO BHCS GAMMA RAY IN ZONE ABOVE SIDETRACK. NO PROBLEMS RIH OR POOH. WELL LEFT SHUT IN. PAD OPERATOR NOTIFIED. 08/10/04 PERFORATE 50 FT OVER THREE INTERVALS WITH 2-7/8' POWERJET 2906 HMX GUNS, 6 SPF. INTERVAL 1: 10634 - 10639 INTERVAL 2: 10571 - 10596 INTERVAL 3: 10539 - 10559 NOTIFY PO TO POP WELL. JOB COMPLETE. O"bP " ',< ..,r.\.", ",,', Report Date: 20-Jul-04 Client BP Exploration (Alaska) Field: Prudhoe Bay Unit - WOA Structure I Slot: N-P AD 1 N-07 Well: N-07 Borehole: N-07 A UWIIAPI#: 500292013701 Survey Name I Date: N-07A 1 July 20, 2004 TortI AHD I 001/ ERO ratio: 303.980' /4684.89 ft/6.229 / 0.515 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatlLong: N 70.32085193, W 148.91024198 Location Grid N/E YIX: N 5968123.000 flUS, E 634414.000 ftUS Grid Convergence Angle: +1.02612276' Grid Scale Factor: 0.99992052 N-07 A Survey Report Survey I DLS Computation Method: Minimum Curvature 1 Lubinski Vertical Section Azimuth: 88.860' Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 72.26 ft relative to MSL Sea Bed I Ground Level Elevation: 43.75 ft relative to MSL Magnetic Declination: 25.090' Total Field Strength: 57587.049 nT Magnetic Oip: 80.855' Declination Date: July 16, 2004 Magnetic Declination Model: BGGM 2003 North Reference: True North Total Corr Mag North .) True North: +25.090' Local Coordinates Referenced To: Well Head Schlumberuer e Comments Surface Location 410.86 0.75 258.00 338.59 410.85 -1.34 1.37 -0.30 -1.33 0.42 0.42 -1.00 5968122.67 634412.67 N 70.32085110 W 148.91025279 BP _CB_GYRO_MS 510.86 1.08 259.00 438.58 510.84 -2.91 2.97 -0.62 -2.90 0.33 0.33 1.00 5968122.33 634411.11 N 70.32085024 W 148.91026548 BP _CB_GYRO_MS 610.86 1.00 255.00 538.57 610.83 -4.69 4.78 -1.02 -4.67 0.11 -0.08 -4.00 5968121.89 634409.35 N 70.32084913 W 148.91027981 BP _CB_GYRO_MS 710.86 0.92 258.00 638.55 710.81 -6.32 6.46 -1.42 -6.29 0.09 -0.08 3.00 5968121.47 634407.73 N 70.32084805 W 148.91029301 BP _CB_GYRO_MS 810.86 0.75 242.00 738.54 810.80 -7.69 7.90 -1.89 -7.66 0.29 -0.17 -16.00 5968120.97 634406.38 N 70.32084676 W 148.91030406 BP _CB_GYRO_MS 910.86 0.75 208.00 838.53 910.79 -8.60 9.17 -2.78 -8.54 0.44 0.00 -34.00 5968120.07 634405.51 N 70.32084434 W 148.91031123 BP _CB_GYRO_MS 1010.86 0.33 175.00 938.53 1010.79 -8.90 10.09 -3.64 -8.83 0.51 -0.42 -33.00 5968119.20 634405.24 N 70.32084198 W 148.91031352 BP _CB_GYRO_MS 1110.86 0.50 149.00 1038.53 1110.79 -8.66 10.81 -4.30 -8.58 0.25 0.17 -26.00 5968118.55 634405.50 N 70.32084017 W 148.91031150 BP _CB_GYRO_MS 1210.86 0.67 141.00 1138.52 1210.78 -8.08 11.83 -5.13 -7.98 0.19 0.17 -8.00 5968117.73 634406.11 N 70.32083791 W 148.91030669 BP _CB_GYRO_MS 1310.86 0.92 140.00 1238.51 1310.77 -7.22 13.21 -6.20 -7.10 0.25 0.25 -1.00 5968116.67 634407.01 N 70.32083499 W 148.91029953 BP _CB_GYRO_MS 1410.86 0.92 170.00 1338.50 1410.76 -6.59 14.78 -7.61 -6.44 0.48 0.00 30.00 5968115.28 634407.69 N 70.32083115 W 148.91029421 BP _CB_GYR_ 1510.86 1.00 181.00 1438.48 1510.74 -6.50 16.45 -9.27 -6.32 0.20 0.08 11.00 5968113.62 634407.85 N 70.32082660 W 148.91029321 BP _CB_GYR 1610.86 0.92 188.00 1538.47 1610.73 -6.66 18.13 -10.94 -6.45 0.14 -0.08 7.00 5968111.95 634407.75 N 70.32082205 W 148.91029423 BP _CB_GYRO_MS 1710.86 1.17 177.00 1638.45 1710.71 -6.76 19.94 -12.75 -6.50 0.32 0.25 -11.00 5968110.14 634407.73 N 70.32081709 W 148.91029471 BP _CB_GYRO_MS 1810.86 1.42 160.00 1738.43 1810.69 -6.32 22.19 -14.93 -6.03 0.46 0.25 -17.00 5968107.96 634408.24 N 70.32081113 W 148.91029084 BP _CB_GYRO_MS 1910.86 1.00 161.00 1838.41 1910.67 -5.65 24.30 -16.92 -5.32 0.42 -0.42 1.00 5968105.98 634408.99 N 70.32080569 W 148.91028510 BP _CB_GYRO_MS 2010.86 0.58 162.00 1938.40 2010.66 -5.24 25.68 -18.23 -4.88 0.42 -0.42 1.00 5968104.69 634409.45 N 70.32080212 W 148.91028153 BP _CB_GYRO_MS 2110.86 0.67 149.00 2038.39 2110.65 -4.80 26.76 -19.21 -4.42 0.17 0.09 -13.00 5968103.71 634409.92 N 70.32079944 W 148.91027782 BP _CB_GYRO_MS 2210.86 1.00 143.00 2138.38 2210.64 -4.00 28.22 -20.41 -3.59 0.34 0.33 -6.00 5968102.53 634410.77 N 70.32079616 W 148.91027112 BP _CB_GYRO_MS 2310.86 1.17 129.00 2238.36 2310.62 -2.71 30.10 -21.75 -2.28 0.31 0.17 -14.00 5968101.21 634412.11 N 70.32079251 W 148.91026043 BP _CB_GYRO_MS 2410.86 1.00 135.00 2338.34 2410.60 -1.32 32.00 -23.01 -0.87 0.20 -0.17 6.00 5968099.98 634413.55 N 70.32078906 W 148.91024900 BP _CB_GYRO_MS 2510.86 1.42 148.00 2438.32 2510.58 -0.08 34.10 -24.68 0.41 0.50 0.42 13.00 5968098.34 634414.85 N 70.32078451 W 148.91023868 BP _CB_GYRO_MS 2610.86 1.58 135.00 2538.29 2610.55 1.51 36.71 -26.70 2.04 0.37 0.16 -13.00 5968096.34 634416.52 N 70.32077897 W 148.91022545 BP _CB_GYRO_MS 2710.86 1.67 117.00 2638.25 2710.51 3.75 39.52 -28.34 4.31 0.52 0.09 -18.00 5968094.74 634418.82 N 70.32077450 W 148.91020702 BP _CB_GYRO_MS 2810.86 4.00 75.00 2738.13 2810.39 8.42 44.28 -28.10 8.98 2.98 2.33 -42.00 5968095.07 634423.48 N 70.32077516 W 148.91016918 BP _CB_GYRO_MS SurveyEditor Ver 3.1 RT-SP3.03-HF4.00 Bld( d031rt-546 ) N-07IN-07\N-07AIN-07A Generated 8/4/2004 11 :45 AM Page 1 of 4 Comments Survey Tool Model 2910.86 6.17 70.00 2837.73 2909.99 16.89 53.14 -25.36 17.40 2.21 2.17 -5.00 5968097.96 634431.85 N 70.32078265 W 148.91010093 BP _CB_GYRO_MS 3010.86 7.83 63.00 2936.98 3009.24 28.11 65.31 -20.43 28.52 1.86 1.66 -7.00 5968103.09 634442.88 N 70.32079612 W 148.91001078 BP _CB_GYRO_MS 3110.86 9.33 57.00 3035.86 3108.12 41.12 80.21 -12.92 41.39 1.74 1.50 -6.00 5968110.83 634455.61 N 70.32081663 W 148.90990647 BP _CB_GYRO_MS 3210.86 10.67 53.00 3134.34 3206.60 55.51 97.57 -2.93 55.58 1.51 1.34 -4.00 5968121.06 634469.62 N 70.32084392 W 148.90979142 BP _CB_GYRO_MS 3310.86 13.00 54.00 3232.21 3304.47 72.25 118.08 9.25 72.08 2.34 2.33 1.00 5968133.54 634485.89 N 70.32087720 W 148.90965770 BP _CB_GYRO_MS 3410.86 15.17 56.00 3329.20 3401 .46 92.47 142.41 23.18 92.03 2.22 2.17 2.00 5968147.82 634505.59 N 70.32091526 W 148.90949599 BP _CB_GYRO_MS 3510.86 18.00 61.00 3425.03 3497.29 117.13 170.93 37.99 116.39 3.17 2.83 5.00 5968163.07 634529.69 N 70.32095572 W 148.90929846 BP _CB_GYRO_MS 3610.86 19.00 58.00 3519.87 3592.13 144.76 202.66 54.11 143.71 1.38 1.00 -3.00 5968179.67 634556.71 N 70.32099975 W 148.90907699 BP _CB_GYRO_MS 3710.86 21.00 58.00 3613.83 3686.09 174.12 236.86 72.23 172.72 2.00 2.00 0.00 5968198.31 634585.38 N 70.32104926 W 148.90884188 BP _CB_GYRO_MS 3810.86 23.50 59.00 3706.38 3778.64 206.80 274.72 92.00 205.01 2.53 2.50 1.00 5968218.65 634617.31 N 70.32110326 W 148.90858012 BP _CB_GYRO_MS 3910.86 25.00 61.00 3797.55 3869.81 242.77 315.79 112.52 240.58 1.71 1.50 2.00 5968239.80 634652.51 N 70.32115930 W 148.90829174 BP _CB_GYRO_MS 4010.86 26.00 62.00 3887.81 3960.07 281.01 358.84 133.05 278.42 1.09 1.00 1.00 5968261.00 634689.97 N 70.32121540 W 148.90798502 BP CB GYRO MS 4110.86 29.00 60.00 3976.50 4048.76 321.80 405.00 155.47 318.77 3.14 3.00 -2.00 5968284.14 634729.91 N 70.32127663 W 148.90765787 BP =CB=GYR_ 4210.86 32.33 62.00 4062.51 4134.77 366.90 455.99 180.15 363.39 3.48 3.33 2.00 5968309.61 634774.08 N 70.32134405 W 148.90729618 BP _CB_GYR 4310.86 35.00 63.00 4145.73 4217.99 416.57 511.42 205.73 412.56 2.73 2.67 1.00 5968336.06 634822.78 N 70.32141392 W 148.90689756 BP _CB_GYRO_MS 4410.86 37.50 66.00 4226.38 4298.64 470.44 570.54 231.13 465.93 3.06 2.50 3.00 5968362.42 634875.68 N 70.32148332 W 148.90646488 BP _CB_GYRO_MS 4510.86 40.83 67.00 4303.90 4376.16 528.84 633.68 256.29 523.85 3.39 3.33 1.00 5968388.61 634933.13 N 70.32155205 W 148.90599537 BP _CB_GYRO_MS 4610.86 43.17 70.00 4378.22 4450.48 591.57 700.58 280.77 586.10 3.08 2.34 3.00 5968414.20 634994.93 N 70.32161891 W 148.90549071 BP _CB_GYRO_MS 4710.86 45.50 72.00 4449.74 4522.00 658.09 770.46 303.50 652.18 2.72 2.33 2.00 5968438.10 635060.58 N 70.32168098 W 148.90495505 BP _CB_GYRO_MS 4810.86 47.00 76.00 4518.91 4591.17 727.88 842.68 323.37 721.59 3.26 1.50 4.00 5968459.21 635129.63 N 70.32173525 W 148.90439230 BP _CB_GYRO_MS 4910.86 48.25 76.00 4586.30 4658.56 799.90 916.55 341.24 793.27 1.25 1.25 0.00 5968478.36 635200.97 N 70.32178405 W 148.90381121 BP _CB_GYRO_MS 5010.86 49.83 79.00 4651.86 4724.12 873.93 992.06 357.56 866.99 2.76 1.58 3.00 5968496.00 635274.37 N 70.32182861 W 148.90321362 BP _CB_GYRO_MS 5110.86 51.67 78.00 4715.13 4787.39 950.10 1069.50 373.01 942.86 2.00 1.84 -1.00 5968512.80 635349.96 N 70.32187078 W 148.90259849 BP _CB_GYRO_MS 5210.86 53.25 78.00 4776.06 4848.32 1027.97 1148.79 389.49 1020.42 1.58 1.58 0.00 5968530.67 635427.20 N 70.32191579 W 148.90196974 BP _CB_GYRO_MS 5310.86 55.75 82.00 4834.14 4906.40 1108.38 1230.18 403.58 1100.57 4.10 2.50 4.00 5968546.19 635507.08 N 70.32195425 W 148.90131998 BP _CB_GYRO_MS 5410.86 56.83 80.00 4889.64 4961.90 1190.78 1313.36 416.60 1182.72 1.98 1.08 -2.00 5968560.68 635588.98 N 70.32198979 W 148.90065398 BP _CB_GYRO_MS 5510.86 50.75 81.00 4948.69 5020.95 1270.56 1394.01 429.94 1262.26 6.13 -6.08 1.00 5968575.44 635668.25 N 70.32202619 W 148.90000919 BP _CB_GYRO_MS 5610.86 50.83 81.00 5011.91 5084.17 1347.32 1471.49 442.06 1338.79 0.08 0.08 0.00 5968588.92 635744.55 N 70.32205926 W 148.89938877 BP _CB_GYRO_MS 5710.86 51.25 82.00 5074.79 5147.05 1424.43 1549.25 453.55 1415.69 0.88 0.42 1.00 5968601.79 635821.23 N 70.32209062 W 148.89876532 BP _CB_GYRO_MS 5810.86 47.17 83.00 5140.10 5212.36 1499.66 1624.94 463.45 1490.73 4.15 -4.08 1.00 5968613.03 635896.07 N 70.32211762 W 148.89815695 BP _CB_GYRO_MS 5910.86 41.00 89.00 5211.93 5284.19 1569.04 1694.45 468.50 1560.02 7.44 -6.17 6.00 5968619.32 635965.26 N 70.32213138 W 148.89759522 BP _CB_GYRO_MS 6010.86 40.50 94.00 5287.71 5359.97 1634.20 1759.70 466.80 1625.23 3.30 -0.50 5.00 5968618.79 636030.48 N 70.32212671 W 148.89706658 BP _CB_GYRO_MS 6110.86 42.50 92.00 5362.60 5434.86 1700.28 1825.96 463.36 1691.40 2.40 2.00 -2.00 5968616.54 636096.69 N 70.32211726 W 148.89653023 BP_CB_GYR. 6210.86 44.75 93.00 5434.99 5507.25 1769.13 1894.95 460.34 1760.32 2.35 2.25 1.00 5968614.75 636165.65 N 70.32210897 W 148.89597151 BP _CB_GYR 6310.86 47.17 92.00 5504.50 5576.76 1840.86 1966.82 457.22 1832.13 2.52 2.42 -1.00 5968612.91 636237.50 N 70.32210039 W 148.89538936 BP _CB_GYRO_ 6410.86 49.83 93.00 5570.75 5643.01 1915.60 2041.71 453.94 1906.94 2.76 2.66 1.00 5968610.97 636312.35 N 70.32209138 W 148.89478286 BP _CB_GYRO_MS 6510.86 50.50 93.00 5634.81 5707.07 1992.18 2118.50 449.92 1983.63 0.67 0.67 0.00 5968608.33 636389.09 N 70.32208034 W 148.89416122 BP _CB_GYRO_MS 6610.86 49.25 93.00 5699.26 5771.52 2068.45 2194.96 445.92 2059.98 1.25 -1.25 0.00 5968605.69 636465.50 N 70.32206936 W 148.89354221 BP _CB_GYRO_MS 6710.86 45.25 94.00 5767.12 5839.38 2141.62 2268.38 441.45 2133.26 4.07 -4.00 1.00 5968602.55 636538.84 N 70.32205711 W 148.89294816 BP _CB_GYRO_MS 6810.86 43.17 93.00 5838.80 5911.06 2211.12 2338.10 437.19 2202.86 2.19 -2.08 -1.00 5968599.53 636608.50 N 70.32204540 W 148.89238400 BP _CB_GYRO_MS 6910.86 40.83 92.00 5913.11 5985.37 2277.89 2405.01 434.25 2269.70 2.43 -2.34 -1.00 5968597.79 636675.37 N 70.32203733 W 148.89184214 BP _CB_GYRO_MS 7010.86 39.00 93.00 5989.81 6062.07 2341.92 2469.17 431.47 2333.80 1.94 -1.83 1.00 5968596.15 636739.51 N 70.32202966 W 148.89132250 BP _CB_GYRO_MS 7110.86 39.33 96.00 6067.35 6139.61 2404.75 2532.32 426.51 2396.74 1.92 0.33 3.00 5968592.32 636802.53 N 70.32201606 W 148.89081224 BP _CB_GYRO_MS 7210.86 39.83 96.00 6144.42 6216.68 2467.98 2596.04 419.85 2460.11 0.50 0.50 0.00 5968586.80 636866.00 N 70.32199781 W 148.89029857 BP _CB_GYRO_MS 7310.86 40.75 96.00 6220.70 6292.96 2532.14 2660.70 413.09 2524.42 0.92 0.92 0.00 5968581.19 636930.41 N 70.32197929 W 148.88977724 BP _CB_GYRO_MS 7410.86 41.25 98.00 6296.17 6368.43 2597.08 2726.30 405.09 2589.53 1.40 0.50 2.00 5968574.36 636995.65 N 70.32195737 W 148.88924944 BP _CB_GYRO_MS 7510.86 41.00 98.00 6371.50 6443.76 2662.01 2792.07 395.93 2654.66 0.25 -0.25 0.00 5968566.37 637060.93 N 70.32193230 W 148.88872147 BP _CB_GYRO_MS SurveyEditor Ver 3.1RT-SP3.03-HF4.00 Bld( d031rt-546) N-07\N-07IN-07 AIN-07 A Generated 8/4/2004 11 :45 AM Page 2 of 4 Comments Survey Tool Model 7910.86 36.50 114.00 6686.70 6758.96 2897.48 3038.01 333.45 2891.42 2.38 0.00 4.00 5968508.15 637298.75 N 70.32176137 W 148.88680230 BP _CB_GYRO_MS 8010.86 35.00 114.00 6767.85 6840.11 2950.37 3096.44 309.69 2944.80 1.50 -1.50 0.00 5968485.35 637352.54 N 70.32169639 W 148.88636971 BP _CB_GYRO_MS 8110.86 34.83 112.00 6849.86 6922.12 3002.60 3153.67 287.33 2997.47 1.16 -0.17 -2.00 5968463.93 637405.60 N 70.32163524 W 148.88594273 BP _CB_GYRO_MS 8210.86 34.17 111.00 6932.27 7004.53 3054.87 3210.31 266.56 3050.17 0.87 -0.66 -1.00 5968444.12 637458.66 N 70.32157846 W 148.88551562 BP _CB_GYRO_MS 8310.86 33.50 110.00 7015.33 7087.59 3106.62 3265.99 247.06 3102.32 0.87 -0.67 -1.00 5968425.55 637511.15 N 70.32152513 W 148.88509292 BP _CB_GYRO_MS 8410.86 33.50 112.00 7098.72 7170.98 3157.74 3321.18 227.28 3153.84 1.10 0.00 2.00 5968406.70 637563.01 N 70.32147104 W 148.88467533 BP _CB_GYRO_MS 8510.86 34.00 114.00 7181.87 7254.13 3208.43 3376.73 205.57 3204.97 1.22 0.50 2.00 5968385.91 637614.52 N 70.32141167 W 148.88426090 BP _CB_GYRO_MS 8610.86 34.75 112.00 7264.41 7336.67 3259.95 3433.18 183.52 3256.94 1.36 0.75 -2.00 5968364.80 637666.87 N 70.32135137 W 148.88383969 BP _CB_GYRO_MS 8710.86 35.50 113.00 7346.20 7418.46 3312.65 3490.72 161.50 3310.10 0.95 0.75 1.00 5968343.74 637720.40 N 70.32129114 W 148.88340889 BP _CB_GYRO_MS 8810.86 36.50 114.00 7427.10 7499.36 3366.08 3549.50 138.06 3364.00 1.16 1.00 1.00 5968321.26 637774.71 N 70.32122703 W 148.88297205 BP CB GYRO MS 8910.86 38.00 114.00 7506.70 7578.96 3420.87 3610.02 113.44 3419.29 1.50 1.50 0.00 5968297.64 637830.43 N 70.32115971 W 148.88252390 B~CB~GYR_ 9010.86 37.50 113.00 7585.77 7658.03 3476.51 3671.24 89.03 34 75.43 0.79 -0.50 -1.00 5968274.24 637887.00 N 70.32109294 W 148.88206889 BP _CB_GYRO_MS 9110.86 32.83 114.00 7667.50 7739.76 3528.86 3728.82 66.10 3528.24 4.71 -4.67 1.00 5968252.26 637940.21 N 70.32103023 W 148.88164086 BP _CB_GYRO_MS 9210.86 28.00 107.00 7753.74 7826.00 3575.75 3779.39 48.19 3575.50 5.98 -4.83 -7.00 5968235.20 637987.77 N 70.32098125 W 148.88125787 BP _CB_GYRO_MS 9310.86 27.17 106.00 7842.37 7914.63 3619.87 3825.69 35.03 3619.89 0.95 -0.83 -1.00 5968222.85 638032.39 N 70.32094525 W 148.88089803 BP _CB_GYRO_MS 9410.86 29.33 103.00 7930.46 8002.72 3665.45 3873.01 23.23 3665.71 2.58 2.16 -3.00 5968211.86 638078.41 N 70.32091294 W 148.88052666 BP _CB_GYRO_MS 9510.86 32.00 104.00 8016.47 8088.73 3714.78 3924.01 11.31 3715.30 2.72 2.67 1.00 5968200.83 638128.19 N 70.32088031 W 148.88012477 BP _CB_GYRO_MS 9535.86 32.17 105.00 8037.65 8109.91 3727.57 3937.29 7.98 3728.15 2.23 0.68 4.00 5968197.74 638141.11 N 70.32087120 W 148.88002057 BP _CB_GYRO_MS 9560.86 32.00 105.00 8058.83 8131.09 3740.33 3950.57 4.55 3740.98 0.68 -0.68 0.00 5968194.53 638153.99 N 70.32086180 W 148.87991661 BP _CB_GYRO_MS 9585.86 31.75 106.00 8080.06 8152.32 3752.98 3963.77 1.02 3753.70 2.34 -1.00 4.00 5968191.23 638166.77 N 70.32085214 W 148.87981350 BP _CB_GYRO_MS 9610.86 31.50 105.00 8101.35 8173.61 3765.54 3976.88 -2.49 3766.33 2.32 -1.00 -4.00 5968187.96 638179.46 N 70.32084255 W 148.87971112 BP _CB_GYRO_MS 9635.86 31.50 106.00 8122.67 8194.93 3778.05 3989.94 -5.98 3778.92 2.09 0.00 4.00 5968184.69 638192.11 N 70.32083300 W 148.87960910 BP _CB_GYRO_MS 9660.86 31.00 107.00 8144.04 8216.30 3790.41 4002.91 -9.66 3791.35 2.88 -2.00 4.00 5968181.23 638204.61 N 70.32082292 W 148.87950831 BP _CB_GYRO_MS 9710.86 31.50 107.00 8186.78 8259.04 3815.06 4028.85 -17.24 3816.16 1.00 1.00 0.00 5968174.10 638229.54 N 70.32080217 W 148.87930727 BP _CB_GYRO_MS 9810.86 30.50 109.00 8272.50 8344.76 3863.71 4080.35 -33.14 3865.14 1.44 -1.00 2.00 5968159.08 638278.80 N 70.32075866 W 148.87891029 BP _CB_GYRO_MS 9910.86 29.75 109.00 8358.99 8431.25 3910.83 4130.53 -49.48 3912.59 0.75 -0.75 0.00 5968143.59 638326.53 N 70.32071396 W 148.87852568 BP_CB_GYRO_MS Tie-In Survey 9910.86 29.75 109.00 8358.99 8431.25 3910.83 4130.53 -49.48 3912.59 0.54 -0.54 0.00 5968143.59 638326.53 N 70.32071396 W 148.87852568 BP _CB_GYRO_MS Top Window (lnterp) 10005.00 30.93 109.94 8440.24 8512.50 3955.34 4178.08 -65.34 3957.42 1.35 1.25 1.00 5968128.54 638371.64 N 70.32067058 W 148.87816236 BP _BLIND Base Window (lnterp) 10017.00 30.99 107.14 8450.53 8522.79 3961.15 4184.26 -67.30 3963.27 12.01 0.50 -23.33 5968126.68 638377.52 N 70.32066521 W 148.87811493 BP _BLIND First MWD+IFR+MS 10027.31 28.75 107.14 8459.47 8531.73 3966.03 4189.39 -68.81 3968.18 21.73 -21.73 0.00 5968125.26 638382.45 N 70.32066107 W 148.87807517 BP _MWD+IFR+MS 10058.88 19.84 104.40 8488.22 8560.48 3978.42 4202.37 -72.39 3980.65 28.44 -28.22 -8.68 5968121.91 638394.98 N 70.32065127 W 148.87797410 BP MWD+IF_ 10090.89 10.62 96.14 8519.07 8591.33 3986.60 4210.75 -74.06 3988.86 29.52 -28.80 -25.80 5968120.38 638403.22 N 70.32064670 W 148.87790753 BP _MWD+IFR 10122.01 2.96 32.95 8549.98 8622.24 3989.90 4214.17 -73.69 3992.16 31.01 -24.61 -203.05 5968120.81 638406.51 N 70.32064770 W 148.87788081 BP _MWD+IFR+MS 10154.14 5.94 331 .42 8582.02 8654.28 3989.60 4216.46 -71.54 3991.81 16.25 9.27 -191.50 5968122.96 638406.13 N 70.32065360 W 148.87788360 BP _MWD+IFR+MS 10185.20 9.67 281.81 8612.82 8685.08 3986.31 4220.43 -69.59 3988.49 23.69 12.01 -159.72 5968124.85 638402.77 N 70.32065892 W 148.87791056 BP _MWD+IFR+MS 10219.26 14.34 265.74 8646.14 8718.40 3979.31 4227.47 -69.32 3981.48 16.74 13.71 -47.18 5968125.00 638395.75 N 70.32065968 W 148.87796739 BP _MWD+IFR+MS 10251.54 20.59 281.45 8676.93 8749.19 3969.76 4237.10 -68.48 3971.91 24.09 19.36 48.67 5968125.66 638386.18 N 70.32066196 W 148.87804492 BP _MWD+IFR+MS 10283.88 27.68 295.68 8706.45 8778.71 3957.48 4250.26 -64.09 3959.54 28.22 21.92 44.00 5968129.83 638373.73 N 70.32067398 W 148.87814517 BP _MWD+IFR+MS 10314.87 35.35 301.68 8732.85 8805.11 3943.50 4266.44 -56.25 3945.40 26.71 24.75 19.36 5968137.41 638359.45 N 70.32069542 W 148.87825976 BP _MWD+IFR+MS 10344.83 43.19 297.55 8756.03 8828.29 3927.20 4285.38 -46.94 3928.91 27.57 26.17 -13.79 5968146.43 638342.80 N 70.32072088 W 148.87839343 BP _MWD+IFR+MS 10364.58 46.17 297.08 8770.08 8842.34 3914.99 4299.27 -40.57 3916.57 15.18 15.09 -2.38 5968152.57 638330.35 N 70.32073830 W 148.87849342 BP _MWD+IFR+MS 10377.16 48.69 292.74 8778.59 8850.85 3906.66 4308.53 -36.68 3908.17 32.35 20.03 -34.50 5968156.32 638321.88 N 70.32074895 W 148.87856150 BP _MWD+IFR+MS 10408.72 58.23 290.47 8797.36 8869.62 3883.30 4333.85 -27.38 3884.61 30.77 30.23 -7.19 5968165.19 638298.16 N 70.32077438 W 148.87875242 BP _MWD+IFR+MS 10441.06 60.99 289.27 8813.72 8885.98 3857.26 4361.75 -17.90 3858.38 9.11 8.53 -3.71 5968174.19 638271.76 N 70.32080030 W 148.87896503 BP _MWD+IFR+MS 10471.52 63.35 287.82 8827.94 8900.20 3831.90 4388.68 -9.34 3832.84 8.82 7.75 -4.76 5968182.30 638246.08 N 70.32082373 W 148.87917200 BP _MWD+IFR+MS SurveyEditor Ver 3.1 RT-SP3.03-HF4.00 Bld( do31 rt-546 ) N-07IN-07\N-07 AIN-07 A Generated 8/4/2004 11:45 AM Page 3 of 4 Comments Survey Tool Model 10504.79 64.91 288.19 8842.45 8914.71 3803.62 4418.62 -0.09 3804.37 4.79 4.69 1.11 5968191.04 638217.45 N 70.32084905 W 148.87940274 BP _MWD+IFR+MS 10538.24 64.37 288.31 8856.78 8929.04 3775.10 4448.84 9.38 3775.67 1.65 -1.61 0.36 5968199.99 638188.58 N 70.32087495 W 148.87963540 BP _MWD+IFR+MS 10568.31 65.50 287.51 8869.52 8941.78 3749.36 4476.08 17.75 3749.75 4.46 3.76 -2.66 5968207.90 638162.52 N 70.32089787 W 148.87984546 BP _MWD+IFR+MS 10603.17 65.25 288.79 8884.04 8956.30 3719.45 4507.77 27.62 3719.64 3.41 -0.72 3.67 5968217.22 638132.24 N 70.32092488 W 148.88008952 BP _MWD+IFR+MS 10634.06 60.88 289.00 8898.03 8970.29 3693.58 4535.30 36.54 3693.59 14.16 -14.15 0.68 5968225.67 638106.04 N 70.32094927 W 148.88030065 BP _MWD+IFR+MS 10664.21 56.98 289.11 8913.59 8985.85 3669.35 4561.12 44.97 3669.18 12.94 -12.94 0.36 5968233.66 638081 .49 N 70.32097233 W 148.88049845 BP _MWD+IFR+MS 10695.63 52.82 289.61 8931.65 9003.91 3645.28 4586.82 53.49 3644.93 13.30 -13.24 1.59 5968241.74 638057.09 N 70.32099563 W 148.88069498 BP _MWD+IFR+MS 10726.42 49.19 289.85 8951.03 9023.29 3622.92 4610.75 61.56 3622.41 11.81 -11.79 0.78 5968249.41 638034.43 N 70.32101772 W 148.88087752 BP _MWD+IFR+MS 10759.68 44.70 289.69 8973.73 9045.99 3600.22 4635.05 69.78 3599.55 13.50 -13.50 -0.48 5968257.22 638011.43 N 70.32104020 W 148.88106283 BP _MWD+IFR+MS Last MWD+IFR+MS 10776.98 43.42 288.17 8986.16 9058.42 3588.92 4647.08 73.69 3588.17 9.59 -7.40 -8.79 5968260.92 637999.98 N 70.32105089 W 148.88115506 BP _MWD+IFR+M5 TD ( Projected) 10832.00 43.42 288.17 9026.12 9098.38 3553.23 4684.89 85.48 3552.24 0.00 0.00 0.00 5968272.07 637963.85 N 70.32108315 W 148.88144628 BP _BLIND Survey Type: Definitive Survey NOTES: CB GYRO MS - ( Camera-based gyro multlshot -- Traditional optically referenced gyro surveys run on wlrellne - Including "level rotor" gyros and Speny-Sun SU3. Replaces ex-BP "PGMS" model.) MWD + IFR + MS - ( In-field referenced MWD with mult-statlon analysis and correction applied In post-processing.) e Leaal Description: Suñace: 2218 F5L 4709 FEL 58 T11N R13E UM BHL: 2303 FSL 1157 FEL 58 T11N R13E UM Northing /VI fflUSI 5968123.00 5968272.07 Eastlng IX) fflUSI 634414.00 637963.85 e SurveyEditor Ver 3.1 RT-SP3.03-HF4.00 Bld( d031 rt-546 ) N-07IN-07IN-07 AIN-07 A Generated 8/4/2004 11 :45 AM Page 4 of 4 f ' J N-07A miD::: 3.125" @9811 /2." XN NIPPLE 4-1/2"TBG, 12.6#, 13Cr, ID::: CI3VIENT 7" LNR, 29#, N-80, .0371 bpf, ID :: . . Schlumberger Drilling & Measurements MWD/lWD log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Robin Deason Well No N-07A Date Dispatched: 16-May-04 Installation/Rig Nabors 7ES Dispatched By: Rose Data No Of Prints No of Floppies Surveys 2 1 ~ I I II Received By: /J~/\..(l ()~J Please sign and return to: 6 ~ Ái'6 '1 Drilling & Measurements LWD Division 2525 Gambell Street, Suite 400 Anchorage, Alaska 99503 nrose1@slb.com Fax: 907·561-8417 LWD Log Delivery V 1.1 , 10-02-03 Schlumberger Private J û ~I -I 0 \ h«(~ ,....pr -..-,. SCHLUMBERGER Survey report Client. ...... ......... ...: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: PBU-WOA Well. . . . . . . . . . . . . . . . . . . . .: N-07A API number. ..............: 50-029-20137-01 Engineer....... .... ......: S. Moy Rig:.. ....... ......... ...: Nabors 7ES STATE:... ... ..... ... .....: Alaska ----- Survey calculation methods------------- Method for positions.. ...: Minimum curvature Method for DLS... ..... ...: Mason & Taylor ----- Depth reference ----------------------- Permanent datum... .......: Mean Sea Level Depth reference.. ... .....: Driller's Pipe Tally GL above permanent.... ...: 43.75 ft KB above permanent.. .....: N/A Top Drive ft DF above permanent. ......: 72.26 ft ----- Vertical section origin---------------- Latitude (+N/S-).. .... ...: 0.00 ft Departure (+E/W-) .... ....: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-) .........: N 70.32085193 ft Departure (+E/W-). .......: W148.91024198 ft Azimuth from rotary table to target: 88.86 degrees [(c)2004 IDEAL ID8_1C_01J 20-Jul-2004 05:00:06 Spud date. . . . . . . . . . . . . . . . : Last survey date. ... .....: Total accepted surveys...: MD of first survey.. .....: MD of last survey........: Page 1 of 2 17-Jul-04 20-Jul-04 30 9910.85 ft 10832.00 ft . ----- Geomagnetic data ---------------------- Magnetic model. .... ......: BGGM version 2003 Magnetic date.. .... ......: 16-Jul-2004 Magnetic field strength..: 1151.76 HCNT Magnetic dec (+E/W-).....: 25.09 degrees Magnetic dip... ..........: 80.85 degrees ----- MWD survey Reference Reference G... ...... .....: Reference H.......... ....: Reference Dip............: Tolerance of G. ..........: Tolerance of H....... ....: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1151.76 HCNT 80.85 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees . ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.09 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.09 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction ;20C(-l(j} " .- ..... SCHLUMBERGER Survey Report 20-Jul-2004 05:00:06 Page 2 of 2 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seg Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 9910.85 29.75 109.00 0.00 8431. 24 3910.83 -49.48 3912.59 3912.90 90.72 0.00 TIP None 2 10005.00 30.93 109.94 94.15 8512.50 3955.34 -65.34 3957.42 3957.96 90.95 1. 35 Top of Window 3 10017.00 30.99 107.14 12.00 8522.79 3961.15 -67.30 3963.28 3963.85 90.97 12.01 Bottom of Window 4 10027.31 28.75 107.14 10.31 8531.73 3966.03 -68.81 3968.18 3968.78 90.99 21. 73 MWD IFR MS - 5 10058.88 19.84 104.40 31. 57 8560.47 3978.42 -72.39 3980.65 3981.31 91.04 28.44 MWD IFR MS 6 10090.89 10.62 96.14 32.01 8591.33 3986.60 -74.06 3988.86 3989.55 91.06 29.52 MWD IFR MS . - 7 10122.01 2.96 32.95 31. 12 8622.23 3989.90 -73.69 3992.16 3992.84 91.06 31.01 MWD IFR MS - 8 10154.14 5.94 331.42 32.13 8654.28 3989.60 -71.53 3991.82 3992.46 91. 03 16.25 MWD IFR MS - 9 10185.20 9.67 281.81 31.06 8685.08 3986.32 -69.59 3988.49 3989.10 91.00 23.69 MWD IFR MS - 10 10219.26 14.34 265.74 34.06 8718.39 3979.31 -69.31 3981.48 3982.08 91. 00 16.74 MWD IFR MS 11 10251.54 20.59 281.45 32.28 8749.18 3969.76 -68.48 3971.91 3972.50 90.99 24.09 MWD IFR MS - 12 10283.88 27.68 295.68 32.34 8778.70 3957.49 -64.09 3959.54 3960.06 90.93 28.22 MWD IFR MS - 13 10314.87 35.35 301.68 30.99 8805.11 3943.50 -56.25 3945.40 3945.80 90.82 26.71 MWD IFR MS - 14 10344.83 43.19 297.55 29.96 8828.29 3927.20 -46.94 3928.91 3929.19 90.68 27.57 MWD IFR MS - 15 10364.58 46.17 297.08 19.75 8842.33 3914.99 -40.57 3916.57 3916.78 90.59 15.18 MWD IFR MS 16 10377.16 48.69 292.74 12.58 8850.84 3906.67 -36.67 3908.17 3908.34 90.54 32.35 MWD IFR MS - 17 10408.72 58.23 290.47 31.56 8869.61 3883.30 -27.38 3884.61 3884.71 90.40 30.77 MWD IFR MS - 18 10441.06 60.99 289.27 32.34 8885.97 3857.26 -17.90 3858.38 3858.42 90.27 9.11 MWD IFR MS - 19 10471. 52 63.35 287.82 30.46 8900.19 3831.90 -9.34 3832.84 3832.85 90.14 8.82 MWD IFR MS - 20 10504.79 64.91 288.19 33.27 8914.71 3803.62 -0.09 3804.37 3804.37 90.00 4.79 MWD IFR MS 21 10538.24 64.37 288.31 33.45 8929.04 3775.11 9.38 3775.67 3775.68 89.86 1. 65 MWD IFR MS . - 22 10568.31 65.50 287.51 30.07 8941. 77 3749.36 17.75 3749.75 3749.79 89.73 4.46 MWD IFR MS - 23 10603.17 65.25 288.79 34.86 8956.30 3719.45 27.63 3719.64 3719.74 89.57 3.41 MWD IFR MS - 24 10634.06 60.88 289.00 30.89 8970.29 3693.58 36.54 3693.59 3693.77 89.43 14.16 MWD IFR MS - 25 10664.21 56.98 289.11 30.15 8985.85 3669.35 44.97 3669.18 3669.46 89.30 12.94 MWD IFR MS 26 10695.63 52.82 289.61 31.42 9003.91 3645.28 53.49 3644.94 3645.33 89.16 13 .30 MWD IFR MS - 27 10726.42 49.19 289.85 30.79 9023.28 3622.92 61. 56 3622.41 3622.94 89.03 11.81 MWD IFR MS - 28 10759.68 44.70 289.69 33.26 9045.98 3600.23 69.78 3599.55 3600.23 88.89 13 .50 MWD IFR MS - 29 10776.98 43.42 288.17 17.30 9058.41 3588.93 73.69 3588.17 3588.93 88.82 9.59 MWD IFR MS 30 10832.00 43.42 288.17 55.02 9098.38 3553.24 85.48 3552.24 3553.27 88.62 0.00 Projected to TD [(C)2~Û4 IDEAL ID8_1C_Ol] . . . . @\@rv LiL\ QD Lf ù FRANK H. MURKOWSK', GOVERNOR AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay N-07 A BP Exploration (Alaska) Inc. Permit No: 204-105 Surface Location: 3061' SNL, 4709' WEL, SEC. 08, Tl1N, R13E, UM Bottomhole Location: 2990' SNL, 1127' WEL, SEC. 08, T11N, R13E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you ftom obtaining additional permits or approvals required by law trom other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 65 -3 (pager). BY ORDER OF THE COMMISSION DA TED this~ day of June, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. W C; I\- ¿, I ( 0 /Zß() + 1a. Type of work DDrill III Redrill 1b. Current Well Class D Exploratory III Development Oil D Multiple Zone D Re-Entry D Stratigraphic Test D Service D Development Gas D Single Zone 2. Operator Name: 5. Bond: a Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 PBU N-07 A /' 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 10797 TVD 9064 Prudhoe Bay Field I Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool / Surface: ADL 028282 3061' SNL, 4709' WEL. SEC. 08, T11N. R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: .,,/ Top of Productive Horizon: 3102' SNL, 809' WEL, SEC. 08, T11N, R13E, UM June 18, 2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2990' SNL, 1127' WEL, SEC. 08, T11 N. R13E, UM 2560 23,600' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Plan 15. Distance to Nearest Well Within Pool Surface: x-634414 y- 5968123 Zone- ASP4 (Height above GL): 70.34' feet N-20A is 665' away at 10300' 16. Deviated Wells: 17. Maximum Anticipated Pressures in psig (see 20 MC 25.0)5) Kickoff Depth 10003 ft Maximum Hole Angle 68 0 Downhole: 3160 psig Surface: 2280 psig 18. Ǫ~'[lgBrogràrri Sétting[)éþtbii······ii ~t!tyQfC~!'1eD~i. Sizè Top <.>Bottom .tor sacks) Hole Casina Weiaht Grade Couolina Lenath MD TVD MD TVD lincludina staae data) 6" 4-1/2" 12.6# L-80 IBT-M 944' 9853' 8381' 10797' 9064' 122 sx Class 'G' 19. PRESENT WELL CONDITIQN. SUMMARY(TO~CI:>rtI!)IØt~çJJor RedriU ANDR~-ep~rYÖpe"ªtio[l$) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): I Effective Depth TVD (ft):1 Junk (measured): 10645 9082 None 10633 9071 10604 i !;.!#f!Wu:Ji .ii Sižê ii Pi Pi vi' ·'·iiI'VlD i ·..····i/i IVIµ/i. C+~, ,,,+0 ....,,1 Conductnr 100' 20" 122 sx Permafrost 100' 100' Surf;:¡c:e 2618' 13-3/8" 3786 sx Permafrost II 2618' 2618' Inter 9635' 10-3/4" x 9-5/8" 1270 sx Howco Liaht, 200 sx Class 'G' 9635' 8193' Production Liner 1704' 7" 460 sx Class 'G' 8938' - 10642' 7598' - 9079' Perforation Depth MD (ft): 10445' - 10584' \perfOration Depth TVD (ft): 8901' - 9026' 20. Attachments a Filing Fee, $100 o BOP Sketch a Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report a Drilling Fluid Program a 20 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ken Allen, 564-4366 Printed Name Bill Isaacson Title Senior Drilling Engineer Sianature 1 Lit L (. / li/ O'i Prepared By Name/Number: ~. Phone 564-5521 Date Terrie Hubble, 564-4628 iF / ii·C iii ii ·.CL ..............iiii! i/p·X X.·i..'/i· Lii /./i. Vi ........... ii' Permit To Drill I API Number: Permit APprovar/;?/¡<ht/1 ~ee cover letter for Number: 'l.v4 -I OS 50-029-20137-01-00 Date: f1 other requirements Conditions of Approval: Samples Required D Yes ~No Mud Log Required' I DYes .ÀfNo Hydrogen Sulfide Measures ~Yes D No Directional Survey Required ¡gYes DNo Othe, T<¿~~ 3500 (Ht' p e1/ c., Ô. Sl&. C;CD , Anomved BvoI /'"Y' ~ BY ORDER OF b¡'ÍsJðl./ "~t"t'" A' THE COMMISSION Date Form 10-401 ~sed 12ì~03 UK IlJ II\JJ-\ L ~bmit IrfDuplilate . STATE OF ALASKA . ALAS~ OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 // '" · . IWell Name: IN-07A Drill and Complete Plan Summary I Type of Well (service I producer I injector): I High Angle Sidetrack Producer Surface Location: X = 634,414 Y = 5,968, 123 //~ As built 3061' FNL 571' FWL Sec. 8, T11 N, R13E Umiat Target Location: X = 638,314 Y = 5,968,153 TVDss 8 801' Ivishak Zone 2 3102' FNL 809' FEL Sec. 8, T11 N, R13E Umiat "7 Bottom Hole Location: X = 637,994 Y = 5,968,259 TVDss ~92' 2990'FNL 1127' FEL Sec. 8, T11 N, R13E Umiat I AFE Number: I PBD4P2170 I I Estimated Start Date: I 06/18/04 ~ 10,797' I I TVD: I 9,064' I I Rig: I Nabors 7ES / I Operating days to complete: 125.3 ~I 41.84' I I KB: 128.5' I I KBE: 170.34' I I Well Design (conventional, slim hole, etc.)~ì Single String, High Angle Sidetrack I Objective: I Ivishak Zone 2B/2C Formation Markers (SLB wp12) Formation Tops MD TVD TVDss Comments TSAG 10,000' 8,507' 8,437' Hydrocarbon bearing 6.9 ppg EMW KOP 10,003' 8,510' 8,440' Hydrocarbon bearing 6.9 ppg EMW TSHU 10,039' 8,542' 8,472' Hydrocarbon bearing 6.9 ppg EMW TSADfTZ4B 10,126' 8,625' 8,555' Hydrocarbon bearina 6.9 ppa EMW TCGLfTZ3 10,309' 8,800' 8,730' Hydrocarbon bearing 6.9 ppg EMW BCGLfTZ2C 10,406' 8,871' 8,801' Hydrocarbon bearing 6.9 ppg EMW PGOC 10,413' 8,875' 8,805' POWC 10,594' 8,950' 8,880' 25N 10,619' 8,960' 8,890' MHO/HOT 10,744' 9,027' 8,957' 22N 10,747' 9,029' 8,959' TD 10,797' 9,064' 8,993' TD CRITERIA: TD WELL 200' MD BELOW owe. ¡ ( ~,ç 5' Directional - Sperry wp12 KOP: 10,003' MD Maximum Hole An Ie: _680 in 6" production section. N-07 A Permit to Drill Page 1 . . Close Approach Wells: N-20A Fails BP Major risk scan, but passes with a risk base rule of 1 :200. The closest point to well N-20A is 665' center to center distance from N-07 A wp12. This occurs at 10,300' MD in N-07 A and at 11,900' MD in N-20A. Closest Well: The closest well is N-20A which is listed above. Survey Program: MWD Standard. Nearest Property Line: 23,600' Casin Hole Size WtlFt Grade Conn Length Top Btm MDITVD MDITVD Tubin 4-1 /2" 12.6# 13-Cr V AM To 9,853' GL 9,853'/8,381 ' 6" 4-1 /2" 12.6# L-80 IBT-M 944' 9,853'/8,381 ' 10,797'/9064' YP 22-30 Lo 6" Production: Drilling: Open Hole: Cased Hole: Sample Catchers - over entire interval, samples described Dir/GRlRes - Real time None None None 26 bbls, 146 ft ,12 sacks Class G @ 15.8 , 1 .20 ft3/sack . 4.5" 12.6#, L-80 Production Liner , 1 .20 ft3/sack Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. N-07 A Permit to Drill Page 2 . . Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval Maximum antici ated BHP Maximum surface ressure Kick tolerance Planned BOP test pressure Diesel Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Sidetrack and Complete Procedure Summar'l Pre-Riq Operations 1. Test the 9 5/8" pack-off, cycle tubing hanger and 95/8" hanger LDS. 2. Pull XX Plug from tailpipe set in Parker X Nipple @ 10163'. 3. P&A the liner straddle section with 19.1 bbls of 15.8 ppg cement. RU & RIH with coil tubing. Lay cement from the top of the fish at 10,604' to 10,150'. The volume to fill the 7" liner and tubing straddle section is 14.1 bbls. An additional 5 bbls of cement will be squeezed into the perfs. Dress off TOC at 10,150' (14.1 bbls actual calculated cement volume left in liner and straddle). 4. Combo-Pressure test the tubing, lA, and OA to 1000 psi. 5. Drift the tubing and tag top of cement. Chemical cut the 3%" tubing in the center of the joint immediately below the crossover from 4 W' tubing (cut at ±1 0095'). 6. Circulate the well to seawater. Freeze protect the IA and tubing with diesel to 2000'. 7. Make a second chemical cut with a 3.25" cutter 2 joints below the 4 %" BVN at ±2100' MD. 8. Bleed all pressures. Set BPV. Secure well. 9. Remove the well house and level the pad. RiQ Operations: 1. MIRU Nabors 2ES. Bleed tubing and annuli pressures as required. 2. Pull BPV. Circulate out freeze protection and d~place well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. / 4. Pull 4%" tubing from above pre-rig cut. The tubing has a reduced 10 to 3.34" at Í100' -120' MD. If the thermal casing is collapsed on the tubing here and the tubing will not pull through: o RU Schlumberger, chemical cut the tubing 10' below the top of the forth joint from surface (125' MD) just below the collapsed section of tubing. Ensure seawater in the well is at least 50-degrees so that the chemical cutter will function properly. o Lay down the upper 125' of 4 %" tubing from collapsed section. · Make another chemical cut in the middle of the third joint from surface at 90' MD (10' above the collapsed section) if jarring is unsuccessful. · Pull and lay down top 90' of tubing and hanger. · Attempt to jar free the 35' damaged section of tubing. N-07 A Permit to Drill Page 3 . . o ND BOPs and tubing spool. Weld the slips to the 9 5/8" casing and NU / test BOPs. o RU Spear, pull 9 5/8" tieback from the PBR at 2045'. · Burn over 35' section with 6 3/8" x 5 1j.¡" burn shoe if 9 5/8" tieback and thermal casing will not pull free. · Recover section of tubing and outside cut ±40' deeper to allow multi-string cut of 10 JA" section below the damaged area. Recover thermal casing. 5. Pull 1 0 JA" casing from the PBR. 6. Circulate Arctic Pack from the 13 3/8" x 9 5/8" annulus with diesel followed by seawat~J. 7. Lay down three joints of thermal casing and 1900' of 10 JA" and 9 5/8" casing. /' 8. Fish remaining tubing. 9. RIH with a 13 3/8" casing scraper and BOT polish mill. Polish the TBR at 2045' and circulate out residual Arctic Pack. 10. Test the casing to 3000 psi. Pick up 133/8" RTTS if casing test fails. 11. RIH with tapered mill and dress off the 7" tubing stub at 8918'. Circulate the well to seawater. 12. RU wireline. Run gauge ring/junk basket to top tubing at 10,100'. 13. Set EZSV at 10,025' (20' below top Sag R by gamma ray). Set a second EZSV in the 7" tubing ~tub at 90})0' MD. 14. RIH w/ 7" x 9 5/8" Baker JMZXP weight-set pac n 7" 26# BTC-m tieback string. Locate into cut tubing stub. 15. Log 7" liner top / tieback to ensure proper po . loni . RD wireline. 16. Freeze protect and cement 7" tieback with 00 nnular feet of cement. Set JMZXP. 17. ND BOP and set 7" slips. Rough-cut 7" c . and set back BOP¥ 18. Install 7" packoff and tubing spool. NU, TestBOPs.'/ / 19. RIH with 6" bit and drillout 7" float equipment and upper EZSV. Test casing to 3500 psi. 20. RIH to lower EZSV and change well over to 8.5 ppg milling fluid. 21. RIH with 7" whipstock and milling assembly to EZSV. Orient and set the whipstock. 22. Mill window in 7" casing at ±1 0,000' MD plus 20' from mid window. Perform FIT to 10.0 ppg. 23. Drill the 6" production section as per directional plan to an estimated TD of 10,800' MD. 24. Run & cement a 4 W', 12.6# L-80 production liner. Displace well to clean seawater above liner top. 25. POH LD DP. 26. Run 4-1/2", 12.6# 13Cr-80 completion tying into the 4-1/2" liner top. / 27. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. .. 28. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 29. Freeze protect the well to -2200' and secure the well. 30. Rig down and move off. /. / /~ Post-Ria Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Perforate ±50', wireline-conveyed, depths to be determined. 4. Install gas lift valves. N-07A Drilling Program Job 1: MIRU Hazards and Contingencies ~ One well will require well house removal for the rig move onto N-07 A. The closest neighboring wells are spaced as follows: N-26 at -30' to the North and N-23A at -65' to the South. Care should be taken while moving onto the well. Spotters will be used at all times. ~ Note tubing, inner annulus and outer annular pressures (trapped gas). Bleed-off any pressure as required and monitor to verify well is dead prior to MIRU. N-07 A Permit to Drill Page 4 . . ~ N-pat!..}§JJesignated as an H2S site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Well Name H2S Readin N-26 55 m N-23Ai 30 m N-20A 10 m N-04A 30 m N-15 220 m m startin 4/15/2000 Date 5/1/2004 9/4/1999 4/25/2004 12/18/2000 10/4/1995 ;¡.. Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud. Reference RP .:. "Dril/ing/Workover Close Proximity Surface and Subsurface Wells" SOP. .:. "Hydrogen Sulfide" SOP. .:. "ADW Rig Move" RP. Job 2: De-complete well Hazards and Contingencies ~ The perforations in N-07 have been isolated with a cement plug set during pre-rig operations. The well also passed a CMIT-T x IA x OA to 1600 psi. Monitor well for any signs of pressure or flows. ~ Maintain kill weight fluid in the hole at all times. ~ Note and record required PU weight to pull tubing at cut point. First cut is -2100', but the tubing may be pinched in with 9-5/8" at -100', ~ NORM test all retrieved well head and completion equipment. ~ Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP Job 3: ThermoCASE, 10-3/4 and 9-S/8"casina pull Hazards and Contingencies ~ The perforations in N-07 have been isolated with a cement plug set during pre-rig operations. The well also passed a CMIT-T x IA x OA to 1600 psi. Monitor well for any signs of pressure or flows. ~ If casing cutting or burn over is required the following should be followed: . Once casing cutting is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. ~ Maintain kill weight fluid in the hole at all times. ~ Note and record required PU weight to pull casing from PBR at 2045'. ~ NORM test all retrieved well head and completion equipment. N-07A Permit to Drill Page 5 . . Reference RP .:. "Hydrogen Sulfide" SOP. .:. "De-completions" RP Job 4: Finish De-complete / Pull remainina 4-1/2" Tubina Hazards and Contingencies '" Maintain kill weight fluid in the hole at all times. Job 5: Run 7" Scab Tie-Back to surface Hazards and Contingencies '" Maintain kill weight fluid in the hole at all times. '" Ensure the JMZXP packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. '" To minimize fire hazard, perform standard precautionary measures, obtain a Hot Work Permit, and use a hydraulic cutter to cut the 7" casing tieback at surface after setting the slips. Job 6: Set whipstock & mill window in 7" liner Hazards and Contingencies '" Maintain kill weight fluid in the hole at all times. '" Once milling is complete, circulate a minimum of 1-1/2 bottoms up and pump a "Super Sweep" pill to remove metal debris created from the milling process. Ditch magnets should be used throughout job. '" Once the milling BHA is out of the hole the entire stack and flow lines should be flushed to remove metal debris that may have settled out in these areas. Reference RP .:. "Hydrogen Sulfide" SOP. .:. "Whipstock SidetracK' RP. Job 7: Drill 6" Production Hole Hazards and Contingencies '" There are no fault crossings in the production section. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. The nearby wells that have had LC events were associated with faults. '" Differential sticking is a concern. The 8.5ppg mud will be -730 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while in open hole (making connections, surveying, etc). '" There is one close approach issue in the production section. N-07 A Permit to Drill Page 6 e . . N-20A Fails BP Major risk scan, but passes with a risk base rule of 1 :200. The closest point to well N-20A is 665' center to center distance from N-07A wp12. This occurs at 10,300' MD in N-07A and at 11,900' MD in N-20A. þ> KICK TOLERANCE: In the worst-case scenario of 7.5 ppg pore pressure in the Ivishak, re gradient of 10.0 ppg at the 7" casing window, and 8.5 ppg mud in the hole, the kick tolerance i nfinit Reference RP .:. "Leak-off and Formation Integrity Tests" SOP .:. "Prudhoe Bay Directional Guidelines" RP .:. "Lubricants for Torque and Drag Management' RP Job 8: Install 4-1/2" Solid Production Liner Hazards and Contingencies þ> Differential sticking is a concern. The 8.5ppg mud will be -730 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. þ> Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. þ> Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate liner / window. ~ Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. Reference RPs .:. "Production Interval Cementing" RP. .:. "Running and Cementing a Liner ConventionallY' RP. .:. Schlumberger Cement Program. Job 9: Run Completion Hazards and Contingencies þ> Diesel will be used to freeze protect the well to -2200'. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RP .:. "Completion Design and Running" RP .:. "Casing and Tubing connections" RP Job 10: ND/NUlRelease Ria Hazards and Contingencies þ> The closest neighboring wells are spaced as follows: N-26 at -30' to the North and N-23A at -65' to the South. Care should be taken while moving off the well. Spotters will be used at all times. N-07 A Permit to Drill Page 7 - . Reference RP .:. "ADW Rig Move" RP. .:. "Freeze Protecting an Inner Annulus" RP. N-07 A Permit to Drill Page 8 -- . N-07A Well Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE Production Hole Section: · There are no fault crossings in the production section. Lost circulation is not anticipated, but has been encountered on the parent well bore N-07. Follow the lost circulation decision tree should LC become problematic. · There is one close approach issue in the production section. o N-20A Fails BP Major risk scan, but passes with a risk base rule of 1 :200. The closest point to well N-20A is 665' center to center distance from N-07A wp12. This occurs at 10,300' MD in N-07A and at 11,900' MD in N-20A. · Kick tolerance is Infinite with a 10.0 ppg FIT. · Differential sticking is a concern. The 8.5ppg mud will be -730 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while in open hole (making connections, surveying, etc). HYDROGEN SULFIDE - H2S / y N-pad is designated as an H25 site. Standard Operating Procedures for H2S precau1íõñs should be followed at all times. Recent H2S data from the pad is as follows: Well Name H2S Readin Date N-26 55 m 5/1/2004 N-23Ai 30 m 9/4/1999 N-20A 10m 4/25/2004 N-04A 30 m 12/18/2000 N-15 220 ppm 10/4/1995 #1 Closest SHL with H2S Readin #2 Closest SHL with H2S Readin #1 Closest BHL with H2S Readin #2 Closest BHL with H2S Readin Max Recorded H2S Reading on the Pad N-15 below 50 4/15/2000 CONSULT THE N-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION N-07A Permit to Drill Page 9 TREE'= 4"FMC e rNOTES: I WELLHEAD - MCBlOY N-07 ACTUATOR = BAKER KB. ELBI = 61.40' BF. ELBI = 41.84' Y -(J 146' H 11-3/4" X 9-5/8" THERMOCASE II I KOP= 3100' Max Angle = 57 @ 5400' l--1 1967' 1-110-3/4" X 9-5/8" XO I Datum MD = 10401' t- _n_. _ ........, n_.,_'__ 1-14-1/2" OTIS DBE SSSV NIP, ID = 3.813" I DatumlVD= 8800' SS Ý ( . I 1986' ";':' 110-3/4" CSG, 55.5#, N-80, ID = 9.953" I 1967' 2045' -1-19-518" PBR I 113-3/8" CSG, 72#, N-80, ID = 12.347" I 2617' -U ~ GAS LIFT MANDRELS ST MD lVD DBI TYÆ VLV LATCH PORT DATE 5 3005 2941 8 CAMCO RK Minimum 10 = 2.75" @ 10163' 4 6691 5758 45 CAMCO RK L 3 8800 7427 37 CAMCO RK 3-1/2" PARKER X NIPPLE 2 10120 8550 29 MCMURRAY BK 1 10146 8575 29 MCMURRAY BK III IJ 8918' 1-17" X 26" SEAL ASSY STUB I TOPOF 7" LNR I 8978' I ~ ¡.¡.¡ I 9-5/8" CSG, 47#, L-80, ID = 8.681" I 9635' I ~ 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 10078' I 10078' .1-+-1/2" x 3-1/2" XO I I - I TOP OF 3-1/2" 9.3#, L-80 I 10078' r- ~. 10163'1-13-1/2" PKRX NIP, ID = 2.75" I I ¿ PERFORA TION SUMMARY 10188' 1-17" HB PKR WI PBR I :8 .- REF LOG: SWS-BHCS ON 07/18/74 I"-" ANGLEAT TOP PERF: 26 @ 10532' Note: Refer to Production DB for historical perf data II SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 1 0234 - 1 0239 S 07/16/86 4" 4 10380 - 10400 S 07/16/86 10409' 1-17" MARKER JOINT I 4" 4 10415 - 10440 S 07/16/86 II 2-1/8" 6 1 0445 - 1 0465 0 05/20/02 4" 4 10454 - 10474 S 07/16/86 [][] 4" 4 10494 - 10532 S 07/16/86 2-1/8" 6 10500 - 10511 0 04/19/02 2-1/2" 6 10511 - 10520 0 04/20/02 :8 ,. 10467' 1-i7" X 3-1/2" 3H BOT PKR I 2-1/8" 4 10532 - 10550 0 07/16/86 I2S -, 2-1/8" 4 10550 - 10580 0 07/02/00 I · l-þ-1/2" PKR X NIP, ID = 2.75" I 2-1/8" 6 1 0550 - 1 0584 0 05/13/00 · I 10478' 2-1/8" 6 1 0550 - 1 0600 S 05/06/92 . · 10485' -þ-1/2" PKR X NIP, ID = 2.75" I · , /3-112" TBG, 9.3#, N-80, .0087 bpf. ID = 2.992" I 10486' r 10486' 1-13-1/2" WLEG, TT I 1) . I 10494' H ELMD TT LOGGED 07/15/00 I 10604' 1-1 FISH - 2 SPLIT RINGS FROM OTIS BV I , -. I PBTD I 10633' 'yyyyyyy IT' LNR, 29#, N-80, .0371 bpf, ID = 6.184" I 10642' DATE RBI BY COMMENTS DATE RBI BY COMMENTS PRUDHOE BA Y UNIT 01/24/77 ORIGINAL COM PLEfION WELL: N-07 , 03/21/89 RWO PERMrr No: 1740230 10/06/01 RNlTP CORRECTIONS API No: 50-029-20137-00 4/19-20/0" CWS/KK ADPERFS SEC 8, T11 N, R13E, 2219' FSL & 571' FWL 05/28/02 JLJ/tlh ADPERFS 08/16/03 CMO/TLP KB ELBI A TION CORRECTION BP Exploration (Alaska) T~= WELLHEAD = ~CTUA TOR = KB. ELEV = BF. REV = KOP= Max Angle = Datum MD = Datum 1VD = 4" FMC MCEVOY BAKER 61 .40' 41.84' 3100' 57 @ 5400' 10401' SSOO' SS e 110-3/4" CSG, 55.5#, N-SO, ID = 9.953" I 1 13-3/S" CSG, 72#, N-80, ID = 12.347" I Minimum ID = 2.75" @ 10163' 3-1/2" PARKER X NIPPLE I TOP OF 7" LNR 19-5/8" CSG, 47#, L-SO, ID = 8.6S1" 14-1/2" TBG, 12.6#, L-SO, .0152 bpf, ID = 3.95S" I TOP OF 3-1/2" 9.3#, L-SO PERFORA TION SUMMARY REF LOG: SWS-BHCS ON 07/1S/74 ANGLEAT TOP PERF: 26 @ 10532' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2-7/S" 4 10234 - 10239 S 07/16/S6 4" 4 103S0 - 10400 S 07/16/86 4" 4 10415 - 10440 S 07/16/86 2-1/S" 6 10445 - 10465 0 05/20102 4" 4 10454 - 10474 S 07/16/86 4" 4 10494 - 10532 S 07/16/86 2-1/S" 6 10500 - 10511 0 04/19/02 2-1/2" 6 10511 - 10520 0 04/20102 2-1/S" 4 10532 - 10550 0 07/16/S6 2-1/8" 4 10550 - 105S0 0 07/02/00 2-1/8" 6 10550 - 10584 0 05/13/00 2-1/8" 6 10550 - 10600 S 05/06/92 I 3-1/2" TBG, 9.3#, N-SO, .0087 bpf, ID = 2.992" 1 10486' I PBTD I 10633' I 7" LNR, 29#, N-SO, .0371 bpf, ID = 6.1S4" I DATE 01/24/77 03/21/89 10/06/01 4119-20/0 OS/2S/02 OS/16/03 10642' REV BY COMMENTS ORIGINAL COM PLETION RWO RN/TP CORRECTJONS CWS/KK ADPERFS JLJ/tlh ADPERFS CMOITLP KB REV A TJON CORRECTJON N-07/ Pre-Rig ~NOTES: LJ!!!I\ \4P , -, ST MD 1VD 5 3005 2941 4 6691 575S 3 8800 7427 2 10120 8550 1 10146 8575 8918' DATE REV BY COMMENTS 11-3/4" X 9-5/S" THERMOCASE II GAS LIFT MANDRELS DEV TYÆ VLV LATCH PORT DATE S CAMCO RK 45 CAMCO RK 37 CAMCO RK 29 MCMURRA Y BK 29 MCMURRAY BK - 7" X 26" SEAL ASSY STUB I -14-1/2" X 3-112" XO I -lCut 3-1/2" Tubing I 10409' - 7" MARKER JOINT 10467' - 7" X 3-1/2" 3H BOT A<R I 10478' - 3-1/2"A<RXNIP,ID=2.75" I 10485' --f3-1/2"A<RXNIP,ID=2.75" 10486' -13-1/2" WLEG, TT I 10494' H ELMDTTLOGGED07/15/00 10604' -1 FISH - 2 SPLIT RINGS FROM OTIS BV PRUDHOE BA Y UNIT WELL: N-07 PERMIT No: 1740230 API No: 50-029-20137-00 SEC S, T11 N, R13E, 2219' FSL & 571' FWL BP Exploration (Alaska) 4-1/2" TBG, 12.6#, 1 ID = PERFORA TION SUMMARY REF LOG: SWS-8HCS ON 07/18/74 ANGLE AT TOP ÆRF: Note: Refer to Production DB for SIZE INTERV A 4" 10234 - 10600 SEe 8, BP ò N-07 A (P3b) Proposal Schlumberger RepOrt Date: Client: Field: structure 1 Slot: Well: Borehole: UWUAPI#: Survey Name 1 Date: Tort 1 AHD 1 DDI 1 ERD ratio: Grid Coordinate System: Location LatlLong: Location Grid NJE YIX: Grid Convergence Angle: Grid Scale Factor: June 3, 2004 BP Exploration (Alaska) Prudhoe Bay Unit - WOA N-PAD 1 N-07 ~¡~: N-07A Approved 500292013701 N-07A (P12) 1 June 2, 20 ~ 295.144· 14664.36 ft 1 6.215 1 0.515 NAD27 Alaska State Planes, Zone 04, US Feet N 70.32085193, W 148.91024198 N 5968123.000 ftUS, E 634414.000 ftUS +1,02612276· 0.99992052 06/0 _/04 Survey I DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Base Flange Elevation: Magnetic Declination: Total Field strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North·> True North: Local Coordinates Referenced To: Minimum Curvature I Lubinski 88.860· N 0,000 ft, E 0.000 ft Rotary T abie 70.34ft relative to MSL 41.84 ft relative to MSL 25.120· 57584.953 nT 80.854· June 20, 2004 BGGM 2003 True North +25.120· Well Head . Comments Latitude Longitude Tie-In Survey N 70.32071396 W 148.87852568 Top Sag River N 70.32067238 W 148.87817716 Top Whipstock N 70.32067071 W 148.87816348 KOP Crv 21.35/100 10012.80 31.05 107.62 8448.57 8518.91 3960.04 4183.09 -66.95 3962.16 12.00 -178.40G 1.25 -23.18 5968127.02 638376.40 N 70.32066617 W 148.87812399 Top Shublik 10039.39 25.37 107.25 8472.00 8542.34 3971.95 4195.65 -70.72 3974.14 21.35 -178.07G -21.34 -1.39 5968123.46 638388.45 N 70.32065586 W 148.87802682 10100.00 12,45 105.25 8529.21 8599.55 3990.62 4215.25 -76.31 3992.93 21.35 -176.16G -21.33 -3.31 5968118.21 638407.33 N 70.32064055 W 148.87787459 TSAD 10126.17 6.88 102.13 8555.00 8625.34 3994.85 4219.64 -77.38 3997.18 21.35 -173.09G -21.26 -11.90 5968117.21 638411.60 N 70.32063762 W 148.87784009 10200.00 8.97 294.24 8628.58 8698.92 3993.96 4224.99 -75.94 3996.26 21.35 -5.31G 2.82 -227.40 5968118.64 638410.65 N 70.32064156 W 148.87784759 10300.00 30.29 290.41 8722.23 8792.57 3963.10 4258.38 -63.81 3965.16 21.35 -1.64G 21.32 -3.83 5968130.21 638379.34 N 70.32067475 W 148.87809966 Top Zone 3 10309.09 32.23 290.31 8730.00 8800.34 3958.71 4263.10 -62.17 3960.73 21.35 -1.55G 21.34 -1.14 5968131.77 638374.89 N 70.32067924 W 148.87813551 10400.00 51.63 289.65 8797.31 8867.65 3902.29 4323.56 -41.57 3903.89 21.35 -1.05G 21.34 -0.72 5968151.35 638317.69 N 70.32073558 W 148.87859620 Top Zone 2 10406.03 52.92 289,62 8801.00 8871.34 3897.83 4328.33 -39.97 3899.39 21.35 -1.04G 21.35 -0.49 5968152.87 638313.17 N 70.32073997 W 148.8.3 PGOC 10412.78 54.36 289.59 8805.00 8875.34 3892.75 4333.76 -38.14 3894.28 21.35 -1.02G 21.35 -0.47 5968154.60 638308.02 N 70.32074496 W 148.8 2 End Crv 10475.48 67.75 289.33 8835.28 8905.62 3841.50 4388.51 -19.91 3842.65 21.35 O.OOG 21.35 -0.41 5968171.90 638256.08 N 70.32079484 W 148.87909249 PO we 10593.58 67.75 289.33 8880.00 8950.34 3739.10 4497.81 16.27 3739.52 0,00 O.OOG 0.00 0.00 5968206.23 638152.32 N 70.32089384 W 148.87992841 Target! Orp 12/100 10596.22 67.75 289.33 8881.00 8951.34 3736.81 4500.26 17.08 3737.21 0.00 180.00G 0.00 0,00 5968207.00 638150.00 N 70.32089605 W 148.87994710 10600.00 67.29 289.33 8882.44 8952.78 3733.54 4503.75 18.24 3733.92 12.00 180.00G -12.00 0.00 5968208.10 638146.69 N 70.32089921 W 148.87997380 25N 10618.70 65.05 289.33 8890.00 8960.34 3717.51 4520.86 23.90 3717.77 12.00 180.00G -12.00 0.00 5968213.47 638130.45 N 70.32091471 W 148.88010464 10700.00 55.29 289.33 8930.39 9000.73 3651.52 4591.30 47.22 3651.30 12.00 180.00G -12.00 0.00 5968235.59 638063.58 N 70.32097851 W 148.88064336 MHOIHOT 10743.89 50.03 289.33 8957.00 9027,34 3618.84 4626.18 58.77 3618.39 12.00 180.00G -12.00 0.00 5968246.55 638030.46 N 70.32101010 W 148.88091015 22N 10746.99 49.66 289.33 8959.00 9029.34 3616.62 4628.55 59.56 3616.15 12.00 180.00G -12.00 0.00 5968247.30 638028.21 N 70.32101225 W 148.88092828 TO /4-1/2" Lnr 10796.22 '-- 43.75 289.33 8992.75 9063.09 3583.07 4664.36 71.41 3582.36 12.00 O.OOG -12.00 0.00 5968258.54 637994.21 N 70.32104468 W 148.88120217 Leaa' DescriDtion: Northina IVI fftUS] Eastina IXI fftUS] Surface: 2218 FSL4709 FEL 58 T11N R13E UM 5968123.00 634414,00 Target : 2234 FSL 972 FEL 58 T11N R13E UM 5968207.00 638150.00 BHL: 2289 FSL 1127 FEL 58 T11N R13E UM 5968258.54 637994.21 WellOesign Ver 3.1 RT-SP3.03-HF4.00 Bld( do31 rt-546 ) N-07IN-07IPlan N-07AIN-07A (P12) Generated 6/4/2004 9:48 AM Page 1 of 1 Prudhoe Jur",,20.20G4 5?5B5.0nT N1019i:"W67 W148S436il71 3600 3700 3800 8500 8600 8700 II (!) ro u (f) a > I- 8800 8900 9000 3600 3700 N-P AD TVORd SJYyOatG 3900 4000 4100 4200 4100 OE/,W 4200 4300 8500 8600 8700 8800 8900 9000 4300 Mdgnelk;P¡¡ra"''''18fS Modal 8GGM 2003 Dip IvwgO..c f';!5.120' TVD RDf: R01ary r"We {l034 It aoov<,; MSL) 1\1-07 A 3525 3600 3675 3750 3825 3900 3975 150 150 ^ ^ ^ 75 75 z ¢? i:ñ ~ g II ( ) ro 0 0 <.) (f) (f) V V V ·75 ·75 -07 3600 . . Oilfield Services, Alaska Schlumberger Drilling & Measurements Schlumbepgep 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8367 Friday, June 04, 2004 Ken Allen Prudhoe Bay N-07 A (P12) BP Exploration Alaska Nabors 7ES Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analvsis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two thousand feet with an increment of one hundred feet for everyone thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survey ProQram: Instrument Type CB - GYRO - MS MWD + IFR + AK Start Depth 107.18'md 9908.94'md End Depth 9,908.94'md 10,796.22'md Close Approach Analvsis results: Under method (2), Note: Wells N-20 violates the conventional major risk anti-collision rules. This well needs to be assessed under the BP Tolerable Collision Risk Worksheet, and should be shut in, or determined if it is P&A'd. Please refer to the anti-collision sheet on the next pages for detailed separation information. N-20 passes the risk based rule of 1 :200. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach DrillinQ Aids to be provided: None needed, sidetrack has no other tolerance lines within 300' of it. Checked by: Scott Delapp 06/04/04 Company: Field: Reference Site: Reference Well: Reference Wellpath: BP Amoco Prudhoe Bay PB N Pad N-07 Plan N-07 A . Schlumberger Anticollision Report . NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 10002.80 to 10796.22 ft Maximum Radius: 10000.00 ft Date: 6/3/2004 Time: 14:11:02 Co-ordinate(NE) Reference: Vertical (fVD) Reference: Welt: N-07, True N-07A Plan 70.3 Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 61212004 Validated: No Version: 7 Planned From To Survey Toolcode ft ft 107.18 9908.94 1 : Camera based gyro multisho (108.94-10æB:œ:tr1~O-MS 9908.94 10796.22 Planned: Plan #12 V1 MWD Casing Points MD TVD Diameter Hole Size ft ft in in 2625.94 2625.62 13.375 17.500 8131.20 6938.48 9.625 12.250 10002.80 8510.34 7.000 8.500 10796.21 9063.08 4.500 6.000 Name 13 3/8" 95/8" 7" 4 1/2" Summary <--'-..~--__---- Offset Well path -......-- -> Site Well Well path PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad PB N Pad N-01 N-01 N-02 N-03 N-04A N-04 N-05 N-06 N-07 N-08A N-08 N-09 N-10 N-10 N-11A N-11 B N-11BPB1 N-11BPB2 N-11 B N-11 N-12 N-13 N-14A N-14 N-15 N-16 N-17 N-18 N-19 N-20A N-20 N-21A N-21 N-22A N-22 N-23A N-23 N-24 N-25 N-26 N-01 V1 Plan N-01A VO Plan: N- N-02 V1 N-03 V1 N-04A V1 N-04 V1 N-05 V1 N-06 V1 N-07 V1 N-08A V2 N-08 V6 N-09 V1 N-10 V1 N-10A V1 N-11A V1 N-11BV4 N-11BPB1 V3 N-11BPB2V3 Plan N-11 C V3 Plan: N- N-11 V1 N-12 V1 N-13 V1 N-14A V3 N-14 V1 N-15 V1 N-16 V1 N-17 V1 N-18 V1 N-19 V1 N-20A V2 N-20 V1 N-21A V2 N-21 V2 Plan: Undefine N-22A V7 N-22 V1 N-23A V2 N-23 V1 N-24 V1 N-25 V1 N-26 V1 Tool Name Camera based gyro multishot MWD - Standard Reference MD ft Ctr-Ctr No-Go Distance Area ft ft Allowable Deviation ft Offset MD ft 10775.00 9300.00 4596.84 999.08 3597.76 10796.21 8900.00 1957.19 767.75 1189.43 10008.94 10000.00 0.04 808.58 -808.54 10717.55 9600.00 2766.901012.81 1754.09 10365.28 11650.00 702.15 944.21 -242.06 10007.66 9999.98 1591.06 725.09 865.97 10008.52 10000.00 1578.34 724.08 854.25 10188.59 11803.00 4268.35 1072.60 3195.75 10002.80 9750.00 4463.151179.83 3283.31 10775.00 8950.00 4991.54 640.03 4351.52 warn~ Out of range Out of range Pass: Major Risk Out of range Pass: Major Risk Out of range Out of range Out of range FAIL: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range FAIL: Major Risk Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Out of range Pass: Major Risk Out of range Out of range . Schlumberger Anticollision Report . Company; BP Amoco Date: 6/3/2004 Time: 14:11 :56 Page; Field: Pf'UdhOe~ay Reference Site: PB N .pad Co-ordiÎlat~(NF;)Reference; Well: N-07,Tl1Jé North Reference Well: N-07 Vertical (fVD)Reference: N-07A Plan 70.3 Reference Wellpath: Plan N-07A Db: Sybase . NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 10002.80 to 10796.22 ft Scan Method: Trav Cylinder North Maximum Radius: 10000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 6/2/2004 Validated: No Version: 7 Planned From To Survey Toolcode Tool Name ft ft 107.18 9908.94 1 : Camera based gyro multisho (108.94-10œ.,IMr1~O-MS Camera based gyro multi shot 9908.94 10796.22 Planned: Plan #12 V1 MWD MWD - Standard Casing Points MD TVD Diameter Hole Size Name ft ft in in 2625.94 2625.62 13.375 17 .500 13 3/8" 8131.20 6938.48 9.625 12.250 95/8" 10002.80 8510.34 7.000 8.500 7" 10796.21 9063.08 4.500 6.000 4 1/2" Summary <---_____--- Offset Wellpath -------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning . ft . ft ft ft ft PB N Pad N-20A N-20A V2 10300.00 11900.00 664.53 0.00 664.53 Pass: Minor 1/200 294 ·200 ·100 100 . ··200 294 Field: Prudhoe Bay Site: PB N Pad Well: N-07 Wellpath: Plan N-07A 100 . 27 101 102 ~102.. 102/ 102 ./ ~03 . 100·' ~~--_/-. .----- "·200'·' 180 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [100ft/in] TERRIE L HUBBLE BP EXPLORATION AK INC "Mastercard Check" PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 First National Bank Alaska Anchorage, AK 99501 MEMO }J., 07 IT . 89-6/1252 113 .: ¡. 25 20001;0.: £i £i ¡. 1."' I; 2 27"' ¡. 55 I;u- 0..1 . $ DOLLARS ~~.bf~ . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME f'8u IU -o7A PTD# 201.1'" IDS >< Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new weUboresegment of LATERAL existing wen . Permit No, API No. . (If API number Production. should continue to be reported as last two (2) digits a function 'of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(1), an (PH) records, data and logs acquired for the pUot bole must be dearJy differentia1edin both name (name on permit plus PH) .' and API Dumber (50 - 70/80) from records, data and Jogs acquired for we)) (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION compJiance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to tbe spacing .exception that may occur. DRY DITCH An dry ditcb sampJe sets submitted to the SAMPLE Commission must be in no greater than 30' sampJe intervaJs from beJow tbe permafrost or from wbere sampJes are first caught and ] 0' sampJe iIÌter:vals througb target zones. . . D D Well bore seg Annular Disposal PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT N-07A _ Program DEV ALASKA) INC Initial ClassfType DEV 11~ GeoArea ~~ Unit 11650 On/Off Shore On Administration P~m)it fee attache_d - - - - - - - - - - - - - ~ - - - - - - - - - - _ _ _ _ _ Y~s_ 2 _Leas~_number _appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - _ Yes - - - - - - - - - - - ~ 3 _U_nique well_n_am~_and OUJ1)b_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s - - - - - - - - - - - - - - - - - -- 4 Well locat~d ina definedppol_ _ _ _ Y~s - - - - - - - - - - - 5 WelUoC<lt~d pr_oper _distance from driJling unitb_oundary_ _ _ _ _ _ _ _ _ _ Yes - - - - - - - - - - 6 Welllocat~d prpperdistance_ from Qtber wells _ _ _ _ _ _ _ _ _ _ _Y~s - - - - - - - - - - - - 7 _Sufficient acreaQ.e_aYail<lble indrillioQ. l,JnjL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s - - - - - - - - - 8 Itd~viated, js_ weJlbore plaUncJuded _ _ _ _ _ _ - - - - - - - Yes - - - - - - - - - - - - - - - - - 9 Operator only affected party _ - - - - -- _ _ _ _ _ Y~s - - - - - - - - - - 10 _Operator bas_apprppriate)¿ond inJQrce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s - - - - - - - - - - - - - - - - - - - 11 P~rmit cao be issued wjtbout COMervation Qrder _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - - - - - - - - - - - - Appr Date 12 P~rmit can be issued wjtbout administrati\(e_apprpval _ _ _ _ _ _ _ _ _ _ _ _ Y~s - - - - - - - RPC 6/10/2004 13 Can permit be approved before 15-day wait Yes 14 Well locat~d within area and_strata authorized by_lnjectipo Ord_er # (put 10# h commeots)_ (ForNA - - - - - - - - - - - - - 15 AJI wells_ within Jl4JDile_area_of reyiew jd~otified (Fpr servjc~-,,\(e[l pnly) _ _ _ _ _ _ _ _ _ _ _ _ _ _NA - - - - - - - - - - - - - - - - - -- 16 Pre-produced injector; dur<ltio_nof pre-produc;tipn I~ss than_ 3 months_ (FQrservice well QnJy) NA - - - - - - - - - 17 ACMF finding 9f CQn_siJ>tenc;y_ h_as bee_n issued fpr_ tbis pr_olect NA - - - - - - - - - - - Engineering 18 Conductor string_provided _ _ _ - - - - - - - - - - - - - - - - - - - - NA - - - - - - - - - - - - 19 _Sm:face _casingprQtecìs alLknown USDWs _ _ - - - - - - NA - - - - -- 20 _CMTvoladequateJo circulateonconductpr_& surfcsg _ _ _ _ _ _ _ _ _ NA - - - - - - - - - - - - - - - - - - - 21 _CMT v_ot adequ_ateJo tie-inJQngstring to_surf csg_ _ _ _ _ _ _ _ _ NA - - - - - - - - - - - - - 22 CMTwill coyer_aU knownproduc;tiye bQrizQn_s_ _ _ _ _ _ _ _ _ Y~s - - - - - - - - - - - 23 C_asiog de_sigos adeQuate fpr CJ, B _& permafr.ost _ _ _ _ _ _ _ _ _ _ _ _ Y~s - - - - - - - - - - -- 24 _Adequ<ltetan_kage_or re_serye pit _ _ _ _ _ _ . . . _ . _ _ _ _ _ Yes \ ab9rs_7_ES, _ 25 l(aJe-d(ilt has a_ tOA03 for <lbandon_ment be~o apprQved _ _ _ _ Y~s * - - - - - - - - - - - - - - - - - 26 Adequatewellbor~~eparatjon_propp~ed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ . - - - - - - - - - - - - - - - - -- 27 Jtdjver:terrequiJ~d, dQe$ jt meet regulations_ _ _ _ _ . . . . _ _ _ _ _ NA Sidetrack. _ _ _ - - - - - Appr Date 28 DriUiog flujdprQgram sc;hematic& eC1-uiplistadequat~ _ _ _ _ _ _ _ Y~$ MaxMWR5ppg. . . _ _ _ _ _ . WGA 6/10/2004 29 BOPEs,_d_o Jhey meet regulaJipn _ - - - - - - - - - - Y~s - - - - - - - - - - - - - - - - - 30 _BOPEpress raJiog appropriate; test to_(put psig Ln_commentsL Yes Test to _3500 psi.MSF> 22-80 psi 31 ChokemanjfQld complies w/APt RF>-53 (May 84)_ _ _ - - - - - - - - Y~s - - - - - - -- 32 WQrk will pC;C_U( withputoperatjon _shutdown _ _ _ _ _ . . . . . . . _ _ _ _ Y~s - - - - - - - - - 33 Is presence of H2S gas_ prQb_able _ . . . . . _ _ _ _ _ Y~s \ <10 H2S pad, 34 Mecban[catcpodJ!lon p{ w~lIs within ,ð.OB. yerified (for_s_ervice w~U only) NA Geology 35 P~rmit can be issued w/o_ hydrogen s_ulfide meas_ure$ _ _ . . . _ _ _ No 36 .D_ata_presented on_ pote_ntial pverpres_sur~ _zones_ NA Appr Date 37 S~ismic_analysJs Qf $ballow gas_z_ooes . . _ _ _ _ _ _ NA RPC 6/10/2004 38 S~abedcondjtipo survey (if off-sh_ore} . . . . . _ _ _ _ _ _ . NA 39 _ ContactnamelphoneJQrwe~kly prpgress_reports [exploratpryonly] NA - Geologic Date: Engineering Date Commissioner: Commissioner: þi5 ~fI5j1-
