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206-161
1890 cu ft G, 230 cu ft G, 674 cu ft G By Grace Christianson at 12:34 pm, Jan 19, 2024 Abandoned 12/27/2023 JSB RBDMS JSB 020124 xG DSR-2/13/24 Drilling Manager 01/18/24 Monty M Myers Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.01.18 20:19:22 -09'00' Torin Roschinger (4662) ACTIVITYDATE SUMMARY 10/13/2023 ***WELL S/I UPON ARRIVAL*** MIRU HES PT PCE 300PSI LOW 3000PSI HIGH CORRELATED TO SLB CBL DATED 07MAR07 SET 4.5" NORTHER SOLUTIONS PACKER WHIPSTOCK WITH TOW AT 10,090' AT 90 DEG ROHS RDMO HES ***WELL S/I UPON DEPARTURE*** 11/1/2023 T/I/O = 15/1604/314. Temp = SI. MITIA PASSED to 3257psi. Pumped 4.25 bbls 60/40 @ 3257 psi. First 15 min loss of 57 psi. Second 15 min loss of 18 psi, for a total of 75psi in 30min. FWHP's = 13/500/310 11/3/2023 Coil Unit 9 1.75" Coil Tubing Weather Stand by 11/4/2023 Coil Unit 9 1.75" Coil Tubing Weather Stand by 11/5/2023 Coil Unit 9 1.75" Coil Tubing Weather Stand by 11/6/2023 Coil Unit 9 1.75" Coil Tubing Weather Stand by 11/7/2023 Coil Unit 9 1.75" Coil Tubing Weather Stand by 11/15/2023 Assist Coil w/ heating UR's to 120*F 11/16/2023 CTU #9 1.75" CT Job Objective: Pre CTD, Mill XN MIRU CTU. MU BOT ctc. Fnc Test BOPs. Man Down Drill. MU BOT LH 3.80" milling BHA. RIH. CTP Increasing w/ same rate. Motor issue. FP CT POOH. BD BOT motor locked up. MU new LH Motor. RIH. Tag XN nipple at 9766' ctm and mill through. Dry drift acoss the nipple and tag Whipstock at 10090'. POOH. ***Continued on 11/17/23*** 11/17/2023 CTU #9 1.75" CT Job Objective: Pre CTD, Mill XN Lay in diesel freeze protect from 2500' TVD. Lay down tools. Rig down CTU. ***Job Complete*** 12/17/2023 T/I/O = 0/500/250. Removed Chem Jewelry flange from front of Flow Cross. Installed Target 90. Torqued to spec. Installed CDR Platform. FWP = 0/500/250 Daily Report of Well Operations PBU N-22B CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Alaska NS - CTD DSM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Alaska NS - CTD DSM; Nathan Wheeler; Robert Coyne; Williams, Wade; Thomas Henson Subject:Nabors CDR2-AC PBU N-22B Initial BOPE test 12-27-2023 Date:Wednesday, December 27, 2023 4:23:14 PM Attachments:Nabors CDR2-AC 12-27-2023.xlsx John Perl Sr. Drilling Foreman – Nabors CDR2 Rig (907) 670-3097 Personal Cell (907) 355-5815 H# 4169 Positional Email AlaskaNS-CTD-DSM@hilcorp.com Alternate: Mark Igtanloc Hilcorp Alaska, LLC 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. 3%81% 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmitt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:CDR2AC DATE: 12/27/23 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #2061610 Sundry #323-524 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2920 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 2-3/8"P Trip Tank PP Annular Preventer 1 7 1/16" 5K P Pit Level Indicators PP #1 Rams 1 Blind/Shear P Flow Indicator PP #2 Rams 1 2-3/8" Pipe/Slips P Meth Gas Detector PP #3 Rams 1 3" Pipe/Slips P H2S Gas Detector PP #4 Rams 1 2-3/8" Pipe/Slips P MS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 2-1/16"P Time/Pressure Test Result HCR Valves 2 2-1/16"P System Pressure (psi)3000 P Kill Line Valves 2 2-1/16"FP Pressure After Closure (psi)2200 P Check Valve 0NA200 psi Attained (sec)20 P BOP Misc 2 2.0" Piper P Full Pressure Attained (sec)59 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge: 1037 P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 10 @ 2050 P No. Valves 12 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 5 P #1 Rams 4 P Coiled Tubing Only:#2 Rams 3 P Inside Reel valves 1P #3 Rams 2 P #4 Rams 3 P Test Results #5 Rams NA #6 Rams NA Number of Failures:1 Test Time:4.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/25/23 14:43 Waived By Test Start Date/Time:12/26/2023 20:30 (date) (time)Witness Test Finish Date/Time:12/27/2023 0:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Nabors R2(Remote actuated kill line) Fail, grease, Pass Wheeler / Henson Hilcorp Alaska, LLC Perl / Burnett PBU N-22B Test Pressure (psi): Nathan.Wheeler@nabors.com alaskans-ctd-dsm@hilcorp.com Form 10-424 (Revised 08/2022) 2023-1227_BOP_Nabors_CDR2AC_PBU_N-22B 9 9 9 999 9 9 9 9 9 9 FP R2(Remote actuated kill line) Fail Drilling Manager 09/15/23 Monty M Myers By Grace Christianson at 9:06 am, Sep 18, 2023 323-524 DSR=9/18/22SFD 9/19/2023 10-407 * BOPE test to 3500 psi. * Variance to 20 AAC 25.112(i) Approved for alternate plug placement when up coming CTD sidetrack liner is fully cemented. MGR22SEP23*&: JLC 9/22/2023 09/22/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.09.22 13:03:04 -08'00' RBDMS JSB 092223 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: September 15, 2023 Re: PBU N-22B Sundry Request Sundry approval is requested to set a whipstock and mill the window in N-22B, as part of the pre-rig for drilling and completing of the proposed N-22C CTD lateral. Proposed plan for N-22B Producer: Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line will set a 4-1/2" packer whipstock. E-line or coil will mill the XN-nipple. Coil will mill window pre-rig. If unable to set the whipstock or mill the window, for scheduling reasons, the rig will perform that work. See N-22C PTD request for complete drilling details - 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 and land in Ivishak Zone 4. The lateral will continue in Zone 4 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 Ivishak perforations via the packer whipstock, liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). Pre-Rig Work - (Estimated to start October 2023): 1. Slickline: Dummy WS drift and Caliper a. Drift and Caliper past whipstock setting location 2. Fullbore: MIT a. MIT-IA to 3,000 psi 3. E-line: Set 4-1/2” packer whipstock* a. Top of window at 10,090’ MD (top of whipstock = pinch point) b. Oriented 90° ROHS 4. Service Coil: Mill Window (mill with rig if needed) a. Mill XN nipple at 9,758’ MD to 3.80” b. Mill Window I. MIRU Service Coil Window Milling Surface Kit II. Give AOGCC 24hr notice prior to BOPE test III. Test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,920 psi IV. Mill 3.80” window plus 10’ of rat hole V. Single string window exit out of 4-1/2” liner 5. Valve Shop: Pre-CTD Tree Work as necessary Rig Work: (Estimated to start November 2023): x Reference PBU N-22C PTD submitted in concert with this request for full details. x General work scope of Rig work: 1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 2,920psi a. Give AOGCC 24hr notice prior to BOPE test 2. Mill Window (only if not done pre-rig) 3. Drill Build and Lateral 4. Run and Cement Liner* 5. RPM log and Perforate (only if not done post-rig) 6. Freeze Protect and RDMO 7. Set LTP* (if needed), RPM log and perforate post rig * Approved alternate plug placement per 20 AAC 25.112(i) plugging the existing Ivishak perforations Sundry 323-524 PTD 223-086 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 20 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 an H2S pad. Last H2S reading on N-22B: 22 ppm in 2021. x Max H2S recorded on N pad: 220 ppm on N-15 in 1995. Reservoir Pressure: x The reservoir pressure is expected to be 3789 psi at 8800 TVD. (8.3 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,920 psi. x Reservoir pressure will be controlled with a closed circulating system and choke for backpressure to maintain overbalance to the formation. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 N pad is an H2S pad. NOTE! BHPE ~8.3 PPGE - mgr Coiled Tubing BOPs 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 nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Sundry Application PRUDHOE BAY UNIT N-22B (PTD 206-161; Sundry 323-524) 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 SFD 9/19/2023 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 SFD 9/19/2023 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 Samuel Gebert Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 02/15/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU N-22B (PTD 206-161) RPM 12/30/2020 ANALYSIS RAW DATA Please include current contact information if different from above. PTD: 2061610 E-Set: 34697 Received by the AOGCC 02/16/2021 02/16/2021 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:206-161 6.50-029-21349-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 13155 13068 8956 9714 None None 8343 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 31 - 111 31 - 111 Surface 2654 13-3/8" 30 - 2684 30 - 2684 5380 2670 Intermediate 7212 9-5/8" 28 - 7240 28 - 6349 6870 4760 Liner 7" 7078 - 9908 6223 - 8499 7240 5410 Perforation Depth: Measured depth: 11798 - 13060 feet True vertical depth:8895 - 8956 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6#13Cr80 27 - 9771 27 - 8389 9714 8343Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer Liner 4-1/2" 9766 - 13155 8384 - 8956 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): 1.5 gallons WellLock Final WH pressures: TBG = 1250 psi, IA = 550 psi, OA = 200 psi Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2091637482746 5590550 1742 340 94 204 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Aras Worthington aras.worthington@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907-564-4763 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8956 Sundry Number or N/A if C.O. Exempt: 320-239 No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 OA Squeeze Operations shutdown Change Approved Program 5 OA WellLock Treatment. Pump 1.5 gal WellLock into OA. Sqz to 1250 psi. SI Al and bled IA from 1700 to 750 psi during sqz. Left CNG hose charged w/ 1250 psi AL gas connected to hardline to serve as accumulator. 1/2 gallon of WellLock in hardline (surface vol Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028282, 028283 & 028284 PBU N-22B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:56 am, Jul 31, 2020 Senior ResSenior ResRenior R Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.07.30 17:25:22 - 08'00' Stan Golis DSR-8/3/2020 RBDMS HEW 8/3/2020 SFD 7/31/2020MGR31JUL2020 ACTIVITYDATE SUMMARY 6/14/2020 T/I/O = 220/1740/640. Temp = 154°. Remove OA gate valve (pre Wellock). ALP = 1740, AL online. OA cemented to surface. Bled OAP from 640 psi to 0 psi in 1 min, gas. Monitor for 1 hr no flow test. No flow test passed, inspected side outlets of surface casing. Wellock is mostly covering both side outlets of OA, both do have a flow path for future treatments. Valve shop removed 3" gate valve from working side of OA & blind flange & installed 3" integrals with Viton seals torqued to API specs. SV = C. WV, SSV, MV = O. IA, OA = OTG. 12:00 6/15/2020 Job Scope: OA WellLock Treatment. Pump 1.5 gal WellLock into OA. Sqz to 1250 psi. SI Al and bled IA from 1700 to 750 psi during sqz. Left CNG hose charged w/ 1250 psi AL gas connected to hardline to serve as accumulator. 1/2 gallon of WellLock in hardline (surface volume). Pad Op called in Freeze Protect. Final pressure 1240 psi WHT 75F. Heater in wellhouse Job Complete - DHD will monitor once per shift 6/16/2020 T/I/O = SSV/550/1200. Temp = SI. WHPs (post Wellock). ALP = 0 psi, AL SI & bled off by pad op. Wellock sample not set up. Well head temp = 56°, adjust heater. Discuss leaving door cracked open with pad op to allow more heat to stay in wellhouse. Heater in well house working properly, man door ajar. SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:00 6/16/2020 T/I/O = 60/550/1200. Temp = SI. WHPs (post WellLock). ALP = 1320 psi, SI @ CV. WH temp = 54°, adjusted heater trunk in well house. WellLock sample is not setup. TP decreased 140 psi, OAP decreased 50 psi overnight. SV, WV = C. SSV, MV = O. IA, OA = OTG. 03:15 6/17/2020 T/I/O = 140/550/1200. Temp = SI. WHPs (post WellLock). ALP = 1320 psi, SI @ CV (LOTO). WellLock sample is not setup. WH temp = 107°, adjust heater trunk and partially open WH door. Heater in well house working properly. SV, WV = C. SSV, MV = O. IA, OA = OTG. 02:00 6/17/2020 T/I/O = 140/550/1250. Temp = SI. WHPs (post WellLock). ALP = 1550 psi, SI @ casing valve (LOTO). WellLock sample is not set up. WH temp = 90°, door ajar. Heater in well house working properly. SV, WV = C. SSV, MV = O. IA, OA = OTG. 13:00 6/18/2020 T/I/O = 160/530/1230. Temp = SI. WHPs (post WellLock). ALP = 1630 psi, SI @ CV (LOTO). WellLock sample is not setup. WH temp = 88°, 1 door ajar. Heater in well house working properly. SV, WV = C. SSV, MV = O. IA, OA = OTG. 01:00 6/18/2020 T/I/O = 0/550/1260. Temp = SI. WHPs (Post Wellock). AL SI @ casing valve (1680 psi). The TP decreased 140 psi, IAP remained unchanged and the OAP increased 60 psi overnight. The Wellock sample has not set up. Wellhead temp = 88*. Left the heaters/doors as found. SV, WV = C. SSV, MV = O. IA, OA = OTG. 1045 6/19/2020 T/I/O = 160/530/1220. Temp = SI. WHPs (post WellLock). ALP = 1990 psi, SI @ CV (LOTO). WellLock sample is beginning to setup, consistency of warm honey. WH temp = 70°, 1 door ajar. Heater in well house working properly. SV, WV = C. SSV, MV = O. IA, OA = OTG. 02:00 6/19/2020 T/I/O = 160/520/1240. Temp = SI. WHPs (Post Wellock). AL SI @ casing valve (1990 psi). Wellhead temp = 85*. Wellock sample is beginning to thicken. Left heater/doors as found. SV, WV = C. SSV, MV = O. IA, OA = OTG. 1320. Daily Report of Well Operations PBU N-22B Daily Report of Well Operations PBU N-22B 6/20/2020 T/I/O = 160/520/1240. Temp = SI. WHPs (Post Wellock). AL SI @ casing valve (1900 psi). Wellhead temp = 85*. Wellock sample is tacky to the touch. SV, WV = C. SSV, MV = O. IA, OA = OTG. 1500. 6/20/2020 T/I/O = 160/530/1200. Temp = SI. WHPs (post WellLock). ALP = 1900 psi, SI @ CV. WellLock sample is further setup, consistency of honey. WH temp = 70°. Heater in well house is working properly, 1 door ajar. SV, WV = C. SSV, MV = O. IA, OA = OTG. 01:30 6/21/2020 T/I/O = 160/520/1200. Temp = SI. WHPs (post WellLock). ALP = 1920 psi, SI @ CV. Well Lock sample has consistency of cold honey, still tacky. WH temp = 73°. Heater in well house is working properly, 1 door ajar. SV, WV = C. SSV, MV = O. IA, OA = OTG. 23:45 6/21/2020 T/I/O = 160/520/1240. Temp = SI. WHPs (Post Wellock). AL SI @ casing valve (1880 psi). WH temp = 72*. Sample is tacky to the touch. The TP remained unchanged, IAP decreased 10 psi and the OAP increased 40 psi overnight. SV, WV = C. SSV, MV = O. IA, OA = OTG. 1300. 6/22/2020 T/I/O = 160/520/1180. Temp = SI. WHPs (post WellLock). ALP = 1820 psi, SI @ casing valve. Welllock sample is setting up, able to imprint & will not move when tipped, slightly tacky to the touch. WH temp = 70°. Heater in well house is working properly, 1 door ajar. SV, WV = C. SSV, MV = O. IA, OA = OTG. 15:00 6/23/2020 T/I/O = 160/520/1120. Temp = SI. WHPs (post WellLock). ALP = 1770 psi, SI @ casing valve. Welllock sample is mostly set up, still able to leave an impression when firmly pressed into, slightly tacky to the touch. WH temp = 64°, adjusted heater trunk. Heater in well house is working properly, 1 door ajar. SV, WV = C. SSV, MV = O. IA, OA = OTG. 16:30 6/23/2020 T/I/O = 160/520/1120. Temp = SI. WHPs (post WellLock). ALP = 1770 psi, SI @ CV. Well Lock sample is mostly setup, firm but able to be indented. WH Temp = 54°, adjusted heater trunk. Heater in well house working properly, 1 door ajar. SV, WV = C. SSV, MV = O. IA, OA = OTG. 04:00 6/24/2020 T/I/O = 170/520/1120. Temp = SI. WHPs (post WellLock). ALP = 1770 psi, SI @ CV. Well Lock sample is mostly setup, firm but able to be indented, no longer tacky. WH temp = 88°. Heater in well house is working properly, 1 door ajar. SV, WV = C. SSV, MV = O. IA, OA = OTG. 01:30 6/24/2020 T/I/O = 170/520/60. Temp = SI. WHPs (post Wellock). ALP = 1770 psi, AL SI @ casing valve. Wellock sample mostly set up, when pressed into firmly it indents, no longer tacky to the touch. JIC fitting began leaking between night DHD monitor & day pad op. Tighten all JIC fittings & increase OAP using ALP from 60 psi to 1360 psi. Monitored for 1 hr. No changes during 1 hr monitor. WH temp = 86°. Heater working properly, 1 door ajar. SV, WV = C. SSV, MV = O. IA, OA = OTG. 11:00 6/24/2020 T/I/O = 160/520/1280. Temp = SI. WHPs (post WellLock). ALP = 1780 psi, SI @ CV. Well Lock sample mostly setup, able to indent with firm pressure, no longer tacky. WH temp = 71°. Heater in well house working properly, 1 door ajar. SV, WV = C. SSV, MV = O. IA, OA = OTG. 22:00 Daily Report of Well Operations PBU N-22B 6/25/2020 T/I/O = 170/520/1290. Temp = SI. WHPs (Post Wellock). AL SI @ casing valve (1760 psi). Wellhead temp = 85*. Wellock sample is fully cured. The TP, IAP remained unchanged and the OAP increased 170 psi overnight. SV, WV = C. SSV, MV = O. IA, OA = OTG. 1615. 6/26/2020 T/I/O = 170/520/1320. Temp = SI. WHPs (post Wellock). ALP = 1770 psi, SI @ casing valve. Wellock sample not completley set up still able to indent when pressed. WH temp = 92°. Heater in well house working properly, 1 door ajar. SV, WV = C. SSV, MV = O. IA, OA = OTG. 14:30 6/27/2020 T/I/O=SSV/500/0. Post well lock. RD O/A working side 3" 5000 integral. RU O/A working side 3" Cameron valve. torqued to API spec. RD O/A Companion side 3" 5000 integral. RU O/A Companion side 3" 5000 blind flange with Alimite fitting. Torqued to API spec. Job Complete. See log. Final WHP's SSV/500/0. 7/14/2020 T/I/O = 1400/1940/380. Temp = SI. Assist Ops w/ POP (post Wellock). AL online. OA cemented to surface. Monitor OAP and bleed as needed. Cont on WSR 7/15/20 7/15/2020 Cont from WSR 7/14/20. Assist Ops w/ POP (post Wellock). AL online. OA cemented to surface. Monitor OAP and bleed as needed. Well temp stablized @ 161°, Bled OAP from 390 psi to 40 psi in 3 minutes (all gas). Continue monitoring for an additional 2 hours. OAP increased 20 psi. Released by Ops. Final WHPs = 200/1730/60. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:00 7/16/2020 T/I/O = 210/1760/80. Temp = 165°. WHPs (post WellLock). AL online @ 1760 psi. OA cemented to surface. TP unchanged, IAP increased 30, OAP increased 10 psi in 10 hours. SV = C. WV, SSV, MV = O. IA, OA = OTG. 11:30 7/16/2020 T/I/O = 210/1730/70. Temp = 152°. WHPs (post Wellock). AL online. SV = C. WV, SSV, MV = O. IA, OA = OTG. 01:30 7/17/2020 T/I/O = 190/1690/60. Temp = 155°. WHPs (post Wellock). AL online. TP decreased 20 psi, IAP decreased 70 psi, OAP decreased 20 psi in 16 hrs. SV = C. WV, SSV, MV = O. IA, OA = OTG. 03:30 7/17/2020 T/I/O = 190/1680/80. Temp = 168°. WHPs (post WellLock). AL online @ 1680 psi. OA cemented to surface. TP unchanged, IAP decreased 10 psi, OAP increased 20 psi in 11 hours. SV = C. WV, SSV, MV = O. IA, OA = OTG. 14:30 7/18/2020 T/I/O = 210/1690/70. Temp = 168°. WHPs (post WellLock). AL online @ 1690 psi. OA cemented to surface. TP unchanged, IAP decreased 20 psi, OAP unchanged in 14.5 hours. SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:30 7/18/2020 T/I/O = 210/1670/70. Temp = 167°. WHPs (post Wellock). AL online. TP increased 20 psi, IAP & OAP decreased 10 psi, temp decreased 1° in 10 hrs 30 min. SV = C. WV, SSV, MV = O. IA, OA = OTG. 01:00 7/19/2020 T/I/O = 190/1710/70. Temp = 166°. WHPs (post Wellock). AL online. TP decreased 20 psi, IAP increased 20 psi, OAP unchanged in 9 hrs 30 min. SV = C. WV, SSV, MV = O. IA, OA = OTG. 01:00 7/19/2020 T/I/O = 200/1700/70. Temp = 168°. WHPs (post Well Lock). AL online @ 1700 psi. OA cemented to surface. TP increased 10 psi, IAP decreased 10 psi, OAP unchanged in 15 hours. SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:00 Daily Report of Well Operations PBU N-22B 7/20/2020 T/I/O = 200/1700/70. Temp = 167°. WHPs (post Wellock). AL online. WHPs unchanged, temp decreased 1° in 11 hrs. SV = C. WV, SSV, MV = O. IA, OA = OTG. 03:00 7/21/2020 T/I/O = 190/1650/70. Temp = 165°. WHPs (post Well Lock). AL online @ 1650 psi. OA cemented to surface. TP & IAP unchanged, OAP decreased 10 psi in 15 hours. SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:30 7/21/2020 T/I/O = 190/1650/80. Temp = 169°. WHPs (post Wellock). AL online. TP decreased 10 psi, IAP decreased 50 psi, OAP increased 10 psi, temp increased 2° overnight. SV = C. WV, SSV, MV = O. IA, OA = OTG. 01:30 7/22/2020 T/I/O = 210/1700/80. Temp = 170°. WHPs (post Well Lock). AL online @ 1700 psi. OA cemented to surface. TP increased 20 psi, IAP increased 50 psi, OAP unchanged in 7 hours. SV = C. WV, SSV, MV = O. IA, OA = OTG. 08:45 7/22/2020 T/I/O = 190/1650/80. Temp = 169°. WHPs (post Wellock). TP & IAP unchanged, OAP increased 10 psi, temp increased 4° in 9 hrs. SV = C. WV, SSV, MV = O. IA, OA = OTG. 01:30 7/23/2020 T/I/O = 210/1710/80. Temp = 171°. WHPs (post Wellock). AL online. IAP increased 10 psi, OAP unchanged, temp increased 1° in 19 hrs. SV = C. WV, SSV, MV = O. IA, OA = OTG. 03:30 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:206-161 6.API Number:50-029-21349-02-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Field/Pools:9. Well Name and Number: ADL 028282, 028283 & 028284 Property Designation (Lease Number):10. 8. PBU N-22B 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown OA Squeeze Op Shutdown GAS GSTOR WAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5Stratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 13155 Effective Depth MD: 13Cr80 11. June 15, 2020 Commission Representative: 15. Suspended Contact Name: Worthington, Aras J Contact Email:Aras.Worthington@bp.com Authorized Name: Worthington, Aras J Authorized Title:Interventions & Integrity Engineer Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8956 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9714 / 8343 No SSSV Installed Date: Liner 3389 4-1/2"9766 - 13155 8384 - 8956 8430 7500 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 30 - 2684 30 - 2684 14. Estimated Date for Commencing Operations: BOP Sketch 31 - 111 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S-3 Perm Packer 11798 - 13060 8895 - 8956 4-1/2" 12.6#27 - 9771 Liner 13068 8956 None None 31 - 111 13-3/8" 9-5/8" Contact Phone:+1 907 564 4102 Date: 4760 80 20" x 30"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2655 5380 Intermediate 7212 28 - 7240 28 - 6350 2830 7" 7078 - 9908 6223 - 8499 7240 5410 Address:P.O. Box 196612 Anchorage, AK 99519-6612 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:33 am, Jun 03, 2020 320-239 Aras Worthington Digitally signed by Aras Worthington Date: 2020.06.03 08:16:33 -08'00' DSR-6/3/2020 X DLB 6/3/2020 10-404 MGR04JUN20 Yes Required? Comm 6/10/2020 dts 6/9/2020 JLC 6/10/2020 RBDMS HEW 6/12/2020 Well: N-22 122 OA WellLock Squeeze Well Interventions Engineer: Aras Worthington (907) 564-4102/(907) 440-7692 Pad Engineer: Bernhard Stechauner (907) 564-4594 Expected Start Date: -XQH 15, 2020 History 122B is a natural flowing producer. During a rotary sidetrack in 2007 the 9-5/8” Production Casing was cut, pulled, re-ran with a cementer, and the OA was cemented to surface. The well had been a steady producer but had experienced some intermittent OA repressurization when shut-in or returned to production. A Well Lock OA squeeze was successfully performed in March of 2019 bringing the well back to Operable status. The OA repressurization rate has increased recently, making it difficult to manage by periodic bleeds. A TIFL passed on 10/27/2018. An MITIA passed to 3000 psi passed on 9/19/2008. The IC packoffs were tested and passed to 3500 psi on 11/12/2018. Current Status The well is currently classified as Under Evaluation by BP and remains online. Objective Re-squeeze the cemented OA with WellLock to mitigate the repressurization. Procedure Special Projects 1. Prep OA, Squeeze WellLock into OA to 2,500 psi. DHD 1. Monitor WHPs after Operations POPs well 2 in'Ir.koL:I V r_ L) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MAY 2 i gnia 1. Operations Performed Size: MD: TVD: Burst: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operation yt ttl �❑ Plugs Suspend ❑ Perforate ❑ Other Stimulate ❑ After Casing ❑ V Change ANNp''prroved Prograamm ❑ 8956 Plug for Reddll ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: OA WeIlLock Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work feet 5. Permit to Dtlll Number 206-161 3. Address: P.O. Box 196612 Anchorage, Development 0 Exploratory ❑ 8956 feet Packer AK 99519-6812 Stretigrephic ❑ Service El 1 6. API Number: 50-029-21349-02-00 7. Property Designation (Lease Number): ADL 028282, 028283 8 028284 8. Well Name and Number: PBU N -22B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: 9767-13155 8385 - 8956 8430 7500 Perforation Depth: PRUDHOE BAY. PRUDHOE OIL 11798 - 13060 feet 11. Present Well Condition Summary: Length: Size: MD: TVD: Burst: Collapse: Total Depth: measured 13155 feet Plugs measured None feet true vertical 8956 feet Junk measured None feet Effective Depth: measured 13068 feet Packer measured 9714 feet true vertical 8956 feet Packer true vertical 8343 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 31 - 111 31-111 Surface 2655 13-3/8" 30-2684 30-2684 5380 2670 Intermediate 7212 9-5/8" 28-7240 28-6350 6870 4760 Liner 2830 7" 7078-9908 6223-8499 7240 5410 Liner 3389 4-1/2" 9767-13155 8385 - 8956 8430 7500 Perforation Depth: Measured depth: 11798 - 13060 feet True vertical depth: 8895-8956 feet Tubing (size, grace, measured and true vertical depth) 4-1/2" 12.6#, 13Cr80 27-9771 27-8389 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 9714 8343 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: TOC @ 63" (13 gal void) Filled void with 20 gal WeIlLock. Displaced 5 gal FW Mix and pour 20 gal WeIlLock. OA full and water displaced. Install 2" 1502 caps on integrals plus 4' 2" 1502 pup joint on pump -in side to serve as a reservoir for excess WeIlLock. Sqz to 2500 psi w/ additional 2.5 gal. Continue to bump up to 2500 psi to maintain sqz pressure for 12 hrs.. Mixed 28 gal WeIlLock. Filled void w/ 20 gallons, 3 gallons sqz'd away, additional 5 gallons used to displace contaminants migrating to surface. Monitor and maintain wellhead temp 60 - 90f for 14 days until sample is set up. Intervals treated (measured): Surface to 63" Treatment descriptions including volumes used and final pressure: 48 Gallons WeIlLock Final Pressures: OA = 0 psi, IA = 50 psi, TBG = 0 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 645 13901 3480 2004 1061 Subsequent to operation: Shut In 50 0 14.Attachments: (regmred mr 20 nnc 25 070 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigrephic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318419 Authorized Name: Obrigewitch, Beau Contact Name: Obrigewitch, Beau Authorized Title: Well Image Engineer A 11 Contact Email: BEAU.OBRIGEWITCH0bp.com Authorized Signature: �j,(,1 IVA All_ Date:-"ih ( Q h Contact Phone: +1 907 564 4854 Form 10-404 Revised 06/2017 ���^/� K, �N t/ RQDMSLN' MAV 2 3 2019 Submit Original Only Daily Report of Well Operations PBU N -22B ACTIVITYDATF SI IMMARV T/I/O = 1580/530/440. Temp = SI. Bleed IA & OA to 0 psi. OA cemented to surface. ALP = 1330 psi, SI @ CV & lateral valve. IA FL @ 6376' (Sta 3, SO -341 bbls). Bled OAP to OT from 440 psi to 0 psi in 1 minute. Bleed IAP to OT from 530 psi to 0 psi in 5.5 hrs. Monitor for 30 minutes. IAP unchanged, OAP increased 20 psi during monitor. Final WHPs = 1580/0/20. 3/12/2019 SV, WV, SSV = C. MV = 0. IA,OA = OTG. 17:00 T/1/0 = 1650/0/0. CONTINUED FROM 3/12/2019. R/D 3" O/A Valve. R/U 3" Intergal. Torgued flanged to 413ft lbs (L7M NC ). Installed viton gaskets. R/U block valve and hard line componets. 3/13/2019 RDMO "' JOB COMPLETE"' FWHP = 1650/0/0 See Log for Details. TWO = 1580/4/320. Temp = SI. WHPs (Post Bleed). ALP = 1330 psi, SI @ CV and lateral valve. IAP increased 4 psi and OAP increased 300 psi since 3/12/19. 3/14/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 02:00 Job Scope: WeIlLock Sqz OA TIO- SSV/4/270. Inspected OA void yesterday and placed heater in wellhouse. Void clean so did not steam clean. TOC @ 83" (13 gal void) Filled void with 20 gal WeIlLock. Displaced 5 gal FW. Mix and pour 20 gal WeIlLock. OA full and water displaced. Install 2" 1502 caps on integrals plus 4'2" 1502 pup joint on pump -in side to serve as a reservoir for excess WeIlLock. Sqz to 2500 psi w/ additional 2.5 gal. Continue to bump up to 2500 psi to maintain sqz pressure for 12 hrs. Mixed 28 gal WeIlLock. Filled void w/ 20 gallons, 3 gallons sgz'd away, additional 5 gallons used to displace contaminants migrating to surface. Monitor and maintain wellhead temp 60 - 90f 3/16/2019 Continued on WSR dated 3/17/19. T/I/O = SSV/O+/1500. Temp = SI. WHPs (post wellock squeeze). ALP = 1640 psi, SI @ CV. WH Temp = 75°. WHPs unchanged in 6 hrs. WeIlLock sample not set up, consistency of warm honey. 3/17/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00 T/I/O = SSV/10/1360. Temp = SI. WHPs (Post Wellock Squeeze). ALP = 1670 psi. WHT = 68° Sample is consistency of warm honey. Adjust heater hose at heater. 3/18/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 23:00 T/I/O = SSV/10/1380. Temp = SI. WHPs (Post Wellock Squeeze). ALP = 1590 psi. WHT = 76° Sample is consistency of warm honey. Adjust heater hose in wellhouse. 3/19/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 08:20 T/l/O = SSV/10/900. Temp = SI. WHPs (Post Wellock Squeeze). ALP = 1580 psi. SI @ CV. WHT = 980. Sample is consistency of thick honey. Increased OAP to 1400 psi. Adjust heater hose in wellhouse. WHT = 75°. 3/20/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 21:00 T/I/O = SSV/10/860. Temp = SI. WHPs (post wellock). ALP = 1480 psi, SI @ CV. WHT = 57°. Sample is consistency of thick honey. Increased OAP to 1500 psi with AL. Heater working properly, adjusted heater hose in well house. 3/21/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 20:30 T/I/O = SSW10/1120. Temp = SI. WHPs (post wellock). ALP = 1480 psi, SI @ CV. WHT = 40°. ALI samples are the consistency of thick honey. Heater working properly, adjusted heater hose in well house to attempt to get WHT up. 3/22/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 10:00 T/I/O = SSV/20/1120. Temp = SI. WHPs (post wellock). ALP = 1480 psi, SI @ CV. WHT = 70°. All samples are the consistency of peanut butter. Heater working properly. 3/23/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 23:00 T/I/O = SSV/20/1060. Temp = SI. WHPs (post Wellock). ALP = 1480 psi, SI @ CV. WHT = 560. All samples are the consistency of peanut butter. Adjusted heater slightly. 3/24/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 09:00 T/I/O = SSV/20/1030. Temp = SI. WHPs (post Wellock). ALP = 1800 psi, AL SI @ casing valve. WHT = 700. All samples are the consistancy of peanut butter. Heater working properly. WHPs unchanged in 13 hrs. 3/25/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 22:00 Daily Report of Well Operations PBU N-22B T/I/O = SSV/20/970. Temp = SI. WHPs (post Wellock). ALP = 1720 psi, SI @ casing valve. WHT = 68*. All samples are firm to the touch but can be imprinted with fingernail. Heater is working properly. Temp decreased 2*, OAP decreased 60 psi in 17 hrs. 3/26/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 16:40. T/I/O = SSV/20/950. Temp = SI. WHPs (post Wellock). ALP = 1720 psi, SI @ casing valve. WHT = 76°. All samples are unchanged from last monitor. Heater is working properly. Temp decreased 2°, OAP decreased 20 psi in 15 hrs. 3/27/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:00. T/I/O = SSV/20/940. Temp = SI. WHPs (post Wellock). ALP = 1720 psi, SI @ CV. WHT = 80*. All samples are semi firm with the consistency of carmel. IAP unchanged, OAP decreased 10 psi overnight. 3/28/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:00 TWO = SSV/20/930. Temp = Sl. WHPs (post Wellock). ALP = 1820 psi, SI @ casing valve. WHT = 80*. All samples are firm but imprintable. Heater is working properly. Temp increased 4°, OAP increased 10 psi in 15 hrs. 3/29/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 16:00. T/I/O = SSV/20/890. Temp = SI. WHPs (post wellock). ALP = 1840 psi, AL SI @ casing valve. WHT = 90°. All samples are firm. Moved heater trunk away from wellhead. Heater is working properly. Temp increased 100 and OAP decreased 30 psi overnight. 3/30/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 21:00 T/I/O = SSV/30/880. Temp = SI. WHPs (post wellock). ALP = 1840 psi, AL SI @ casing valve. WHT = 55°. All samples are solid. Adjusted heater trunk. Heater is working properly. Temp decreased 350 and OAP decreased 10 psi overnight. 3/31/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 1535 hrs. TWO = SSV/30/860. Temp = SI. WHPs (post wellock). ALP = 1840 psi, SI @ CV. All samples are set up. IAP increased 10 psi, OAP decreased 30 psi from 3/30/19. 4/1/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 10:00 T/I/O = SSV/30/860. Temp = SI. WHPs (post wellock). ALP = 1660 psi, SI @ CV. All wellock samples are set up. SC temp = 80° and heater is working properly. WHPs unchanged overnight. 4/2/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 16:10 T/I/O = SSV/30/840. Temp = SI. WHPs (post wellock). ALP = 1560 psi, AL SI @ casing valve. WHT = 65°. All samples are set up. Heater is working properly. OAP increased 20 psi in 14 hours. 4/3/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 17:00 T/1/O=SSV/30/800. Post well lock. RD intrgals and block valves. RU 3" OA valve on working side and tapped blind flange with alemite fitting on companion side, torque to API specs. 413 4/7/2019 FT/LBS **'JOB COMPLETE***. See log for details. Final WHPs=SSV/30/0 T/I/0 = SSV/30/0+. Temp = Sl. WHPs (post wellock). ALP = 1730 psi, AL SI @ CV & LV. No heater. WHPs unchanged overnight. 4/8/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 22:15 T/l/O = 200/1570/0+. Temp = 160°. WHPs (post wellock). ALP = 1570 psi and is online. 4/29/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 20:45. T/I/O = 200/1570/0+, Temp = 154*. WHPs (Post Wellock). ALP = 1570 psi, open @ CV. Wellhead temp at OA = 80*. WHPs unchanged overnight. 4/30/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 20:40 T/I/O = 420/1670/0+. Temp = 152°. WHPs (Post Wellock). ALP = 1670 psi, open @ CV. Wellhead temp = 72°. TP increased 220 psi, IAP increased 100 psi since 4/30/19. 5/3/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 02:00 T/I/O = 420/1650/10. Temp = 155*. WHPs (post wellock). ALP = 1650 psi, AL open @ casing valve. TP unchanged, IAP decreased 20 psi and OAP increased to 10 psi overnight. 5/4/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 14:30 IT/I/O = 420/1640/10. Temp = 154°. WHPs (post wellock). ALP = 1640 psi, AL open @ casing valve. TP unchanged, IAP decreased 10 psi and OAP unchanged overnight. 5/5/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 14:00 Daily Report of Well Operations PBU N -22B TWO = 420/1630/10. Temp = 1520. WHPs (post wellock). AL online. TP unchanged, IAP decreased 10 psi and OAP unchanged since last monitor on 05-05-19. 5/7/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 13:30 T/I/O = 420/1630/10. Temp = 152°. WHPs (post wellock). AL online. No change in pressures from previous day. 5/8/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 15:45 T/I/O = 420/1630/10. Temp = 152°. WHPs (post wellock). AL online. No change in pressures since last check on 05/08/19. 5/1012019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 16:45 T/I/O = 410/1620/10. Temp = 151'. WHP's. (Post wellock). ALP = 16520 psi & open to well. TP decreased 10 psi, IAP decreased 10 psi, no change in OAP overnight. 5/11/2019 SV = C. WV, MV, SSV = 0. IA, OA = OTG. 13:51 T/I/O = 420/1640/10. Temp = 1520. WHPs (post wellock). AL online. TP and OAP unchanged, IAP increased 10 psi since last check on 05/10/19. 5/12/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 10:30 T/I/O = 410/1620110. Temp = 152'. WHP's. (Post Wellock). TP decreased 10 psi, IAP decreased 20 psi, No change in OAP overnight. 5/13/2019 SV = C. WV, MV, SSV = 0. IA, OA = OTG. 10:35 T/I/O = 410/1620/10. Temp = 152°. WHP's. (Post Wellock). AL online. No change in TP, IAP or OAP since 5/13/19. SV = C. WV, MV, SSV = 0. IA, OA = OTG. 14:45 5/15/2019 TWO = 410/1620/20. Temp = 152°. WHPs (Post Wellock). AL online. TP and IAP unchanged, OAP increased 10 psi since 5/15/19. 5/17/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 15:30 TWO = 410/1620/20. Temp = 152°. WHPs (Post Wellock). AL online. No change inTP, IAP or OAP overnight. SV = C. WV, SSV, MV = 0. IA, OA = OTG. 15:15 5/18/2019 T/l/O = 410/1620/20. Temp = 152°. WHPs (Post Wellock). AL online. WHPs unchanged overnight. 5/19/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 10:55 TREE= VVEI-rAD= MCEVOY ACTUATOR= BAKER OKB. R = 80.3' REF ELEV = 72.58' BF. BLV = 4424' ORIG KOP= 3100' Max Angle = 102" @ 10809' Datum MAD= 10406' Datum TVD= 8800'SS 9-58' CSG, 478, L-80, D = 8.681• I 1814' 13-3/8• C6G, 728, 4-80, D = 12.34r 2693' Minimum ID = 3.725" @ 9758' 4-112" XN NIPPLE 9-518' CSG, 478, L-80, D = 8.681' 1 4-1/2" TBG, 126#, 13CR80, VAMTOP,.0152bpf, D=3.958" TOP OF 4-1/2' LNi 7• LW 4-1/2' LNR N2 2 B SACHROAtE T &N� L ANGLE> 70" 10503'. -5/8• HES ES CEM34TT8i 1/2 FIESX NP, D=3.81: GAS LFTMANIRR S ST PERPORATDN StlM,Y1RY TVD REF LOG: EVVPJROP/ALDYCTN ON 3/7/07 TYPE ANGLE AT TOP PERF: 88' @ 11798' Note: Refer to PraducWn DB for Nstorical perf data SIZE SIA= INTERVAL Opn/Sgz DATE 2' 6 11798-11818 O 08/28/18 2-12" 6 12075 - 12085 O 10/01/17 2-12" 6 1208.5-12095 O 09/30/17 2-78" 4 12250-12430 O 03/07/07 2-718' 4 12840- 13060 O 03/07/07 4-1/2' LNR N2 2 B SACHROAtE T &N� L ANGLE> 70" 10503'. -5/8• HES ES CEM34TT8i 1/2 FIESX NP, D=3.81: GAS LFTMANIRR S ST MD TVD DEV TYPE VLV LATCH PORT DOTE 4 3412 3401 17 MMS DOMEJ RK 16 0920106 3 6378 56M 42 M MG SO RK 20 09120/08 2 8209 7126 38 KBG2 DW BK 0 09/20108 1 9624 8271 36 KBG2 IOW BK 0 09/20/08 7078' 9-S/8" x r BKR C2 ZXP LT PKR, D = 6.26' w /11.6' 7EBACK & FMC LNR HGR 9-58' MLLOUT WFMW 7240'-7257' 9693' 1--14-1/2 FES X NP, D= 17- x 4-1/2• BKR S-3 PKR D= 3.875. 1 14-1/2l£SXNP. D=3.813 1 9� 766• "7-x SBKRZXPLTPF0;D=4-41' w /11.4' T8$ACK & MAC LNR HGR 8771' 4-1/2 VVLEG, D= 3.958• 9ND NOT LOGG® DATE REV BY COM ENM DATE REV BY COMMENTS 03/28186 INTIAL COMPLETION 08/29/18 JUJMD ADPERFS (0&28/18) 04/25/88 SIDETRACK(M422A) 09/17/18 DD(JMD ADDED FEF &BFELFVS 03/10/07 WES SIDETRACK (N22B) 09/18/18 MJMD CORRECT® FEW DEMIS 08/20/12 PP/PJC PERF REF LOG PFO 09/04/12 SET/JMD DRAVWG CDRREaDoNS 10/12/17 WWAVADPERFS PRLUIOEBAY t1NT WB -L 14-22B DANT No: 2061610 APINo: 50.029-21349-02 Ti IK R13F-706' FSL & 531' FWL BP 6tploration (Alaska) RECEIVED • inks DEC 14 2017 • BAKER PRINT DISTRIBUTION LIST HUGHES G�,/ Please sign and return one copy of this transmittal form to: COMPANY BP orationExplAlaska Inc. BP Exploration(Alaska)Inc. Petrotechnical Data Center,LR2-1 DATA LOGGED WELL NAME N-22B 900 E. Benson Blvd. ‘Z/t4/201Z M K BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D-CO BHI DISTRICT Alaska LOG DATE September 30,2017 AUTHORIZED BY Paul Canizares EMAIL Paul.CanizaresCa)bakerhughes.com TODAYS DATE December 13,2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BO* LOGS LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #OF F'KIN I - #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope. 0 0 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmakcr 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 1 1 0 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 I 1 1 0 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 I 1 1 0 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** I 0 1 I 1 0 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 L***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 1 1 0 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Dodie Stinson SCANNED MAR ,L 3 2013 TOTALS FOR THIS PAGE: 0 5 5 S STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISIII REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 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: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 206-161 3. Address: P.O.Box 196612 Anchorage, Development II Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21349-02-00 7. Property Designation(Lease Number): ADL 0028284 8. Well Name and Number: PBU N-22B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: RECEIVED PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: 2 6 2017 Total Depth: measured 13155 feet Plugs measured feet OCTV v�G� I true vertical 8956 feet Junk measured feet AOGCC CC Effective Depth: measured 13068 feet Packer measured 9714 feet �1�✓aw true vertical 8956 feet Packer true vertical 8343 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 31-111 31-111 Surface 2655 13-3/8"72#L-80 30-2684 30-2684 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: 12075-12085 feet 12085-12095 feet 12250-12430 feet 12840-13060 feet True vertical depth: 8915-8916 feet feet 8916-8917 feet 8929-8944 feet 8968-8956 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 27-9771 27-8389 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): gy � Treatment descriptions including volumes used and final pressure: ��ANNED DEC[ !aQ1 7 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure • Prior to well operation: 524 10429 2457 1993 1067 Subsequent to operation: 395 2173 5807 1935 215 14.Attachments:(required per 20 MC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory 0 Development m Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil RI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: NIA Authorized Name: Bergene,Matthew Contact Name: Bergene,Matthew Authorized Title: �Proodduct`ionn Engineer Challenger Contact Email: Matthew.Bergene©bp.com Authorized Signature: v�-V Date: 2..tirOGt- (7 Contact Phone: +1 9075644849 Form 10-404 Revised 04/2017 0/7,I '/'7[ / z/1--/l ��� � t - � i 2017 Submit Original Only • • V. Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary October 26, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Addition of Perforations for Well N-22B, PTD # 206-161. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 d a. 000000 ca N- CO CO '— O O O N V' •cr Ln N- U % 0 0 0 0 0 0 L.. co I,- r- V co co • O co 00 N V CO CO CO I- co 00 V O O O CO ' LO O LO 00 CO CO M cr O Ch CO CO CO CO H - CO LC) O CO N CO N.- 01 �M M N CO N (7 N - CO CO G) Nr C) co O N- r co CO N O M N <- I- O) CS) o III I 4.0 A11 < N CO N O co I- CO I- a) I01 M N CO O 1"-- N Z - I� O EL O O 00 o O U OO co co O M J J CO = N CO N *k *k J It .N X V �$ CV CO O 0\0 N U , LoI� � N co O O 4 t LO CS) 10 II O in CO N O� CO -4- C C CO ON- CO CO 1— J N - LC) N (r) O W W CC H Q Q • � 0 0 •)• UUWW co U o LL W OLCCW Z Z c W W W LI J �p O D H H Z Z D O Cn Z Z J J H . • Packers and SSV's Attachment PBU N-22B SW Name Type MD TVD Depscription N-22B PACKER 7089.95 6232.03 7" Baker ZXP Top Packer N-22B TBG PACKER 9714.42 8342.95 4-1/2" Baker S-3 Perm Packer N-22B PACKER 9778.05 8393.84 5" Baker ZXP Top Packer 1 41 • U I- Oz a) U _0 O J - N J m J p) 2 D o fl m 3 p ❑ o 2 0 Q' U) F- O O m CtF- ((j 1 J N a = O0 I 0l O 2 I-- 20D ❑ WW ❑ 0 Li � � WW ❑ W � � O L oLii p• 1- Cl) 0 Q� a) OF- F- ❑ � � ~ 2Q 2 U a) .r � 2J - 00 S OW N 3W *K F- Ow F- WFWz cewe Tow —D c r <a Q D li m a c- W (t < < 00 m O Z0 z0 = H 300 OZO UmH1— w � U ° 0 rna) ON AEU fccwQ L � F- O < 0 +. cpi_ C 1-° 51- 0 5F- 0 I-J> F- Z ZWJcp aCJamm Lb 2❑ acnW Z W --z "z pa) ooc u) 0 - 0ZQ0 Qa � a ~ aN a ,- � 0_ -,E1 m ,, ,,, OH C J CC 2 M > N o UYOn d2 M - cc2 ❑ O >- W - 0II 2 Q- 2 () - OIIOF- OW z W a ) * u_ o ou_ oHO. ao , WwpLo Wwa2i 2Q -mTWO p cm �, `- « 4 ❑ 0ODU_O F- m 10 }, v7 * o1- F ~ > � Q , * } M F- b o a) E N } E' RQ } ERz F- * CC 2 c,') � ❑ C ❑ Z U mmr` I- I- 0 2 3 �C) L mw = � Zw = 0OU W Z eF- WnH OJ ❑ 18 c � � o ww - mowOOJ r CL -I WO , _I a) eL-0 F- -JCtOF- Jfl � O ar- O M CO -)• 11±1 .-'-' co M U I- oo O W p E W W W O U W W _ . 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N _2 2 B "".F ROM E TUBING"'" ACTUATOR= BAKER OPoG KB.ELEV 80.3' ORIG BF H-EV 44.5 // 911 Of G KOP= 31017 Max Angle= 102"I, 10809' 1�� ��•V 1759' 9-5/8'EES ES OEMEIYTER Datura MD= 10406' 4/• 141 Datura TVD= 8800'SS , ' 2216' —14-1/2 HIES X N63,D=3.813 GAS LFT MANDRELS 9-5/8'CSG,47#,L-80,D=8.681" —1 1814' ST, MD TVD DEV TYPE VLV LATCH PORT DATE 4 3412 3401 17 MMC DOAE RK 16 09/20/08 13-3/8'CSG,72#,L-80,13=12.347" H 2693' 3 6378 5690 42 MMC SO RK 20 09/20/08 2 8209 7126 38 KBG2 OMY BK 0 09/20/08 Minimum ID =3.725" @ 9758' 1 9624 8271 36 KBG2 DMY BK 0 09/20/08 4-1/2" XN NIPPLE .� 7078' '-9-5/8"x 7'BKR C2 ZXP LT PKR,D=6.26" w/11.6'TIEBACK&l-MC LIR HGR 9-5/8"CSG,47#,L-80,13=8.681' H 72400 9.5/8-MLLOtlr WINDOW 7240'-725T I I i 9693' H4-1/2 I ES X NP,D=3.813 S X 97140 H7"x 4-1/2"BKR S-3 PKR,D=3.875" I I I 9738' --4-112 HES X NP,D=3.813 I i 9758' —14-112 HES XN NP,D=3.725 4-1/2'TBG,12.6#,13C410, 9771' VAM TOP .0152bpf,D=3.958' 9766' I-7"x 5"BKR ZXP LT PKR,D=4.4? w/11.4'TEBACK&HMC LNR HGR TOP OF 4-1/2-LNR H 9766' f---I 9771' H 4-1/2 WLEG,D=3.958" H ELMD NOT LOGGED r twit,26#,L-80,BTC-M,D=6.276" —1 9908' 4 L PEWORATpN SUMMARY REF LOG EWR/RORALLYCTN ON 3/7/07 ANGLE AT TOP PERF:84'@ 12075' Note:Refer to Roduction DB for historical perf data SIZE SPF FITI37VAL Opn/Sgz DATE 2-1/2" 6 12075-12085 0 10/01/17 2-1/7' 6 12085-12095 0 09/30/17 2-7/8' 4 12250-12430 0 03/07/07 2-7/8" 4 12840-13060 0 03/07/07 PBTD — 13068' 1.114 4-1/2"LNR,12.6#,L-80,BT,.0152 bpf,D=3.958" —1 13155' DATE FEV BY CONSENTS DATE REV BY COMMENTS PRU]IOEBAY UNIT 03/28/86 IMTIAL COMPLETION 08/20/12 PPVPJC PERF REF LOG PFO WELL N-226 04/25/98 SIDETRACK(N.22A) 09/04/12 SET/,NAD DRAWING CORRECTIONS PERMIT No: 2061610 03/10/07 N2B5 SIDETRACK(N-22B) 10/12/17 NXW/JMD ADPERFS AR No: 50-029-21349-02 11/11/09 JLS/SV MAL DRAFT SEC 8,T11N,R13E,706'FSL&531'FWL 03/09/11 PJC SFTY NOTE C ORECTION 08/17/12 PF/PJC TOP PERF ANGLE BP Exploration(Alaska) • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday,June 10, 2017 1:36 PM To: AK, GWO SUPT Well Integrity;AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Well Pad MN;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead;AK, OPS EOC Specialists; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; Regg,James B (DOA); Bergene, Matthew Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J;AKIMS App User;AK, GWO Well Integrity Well Information Subject: OPERABLE: Producer N-22B (PTD#2061610) Outer Annulus Repressurization Test Passed All, Producer N-22B(PTD#2061610)was made under evaluation on 5/25/17 for having sustained OA casing pressure above NOL. An outer annulus repressurization test was completed on 6/7/17 and passed with a buildup rate of ^'31psi/day. Follow up monitors indicate the OA pressure is stable and the repressurization is manageable by bleeds. The well is now classified as OPERABLE. Please reply if in conflict, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068KAMM f , LIN WO From: AK, GWO S • -II Integrity Sent: Thursday, May 25, 20 • 3 PM To: AK, GWO SUPT Well Integrity; A c• GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad MN; AK, OPS Prod Controllers; AK, •• • C Ops Lead; AK, OPS EOC Specialists; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GP: t Wells Opt Engr; Wellman,Julie; 'Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov) Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well IntegrityGWO Completions Well Integrity; AK, OPS FF Well Ops Comp Rep; 'chris.wallace@alaska.gov' (chris.wallace@alaska.gov); Hi.• , Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R; Tempel,Troy; Wo •ton, Aras J; AKIMS App User; AK, 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com> Sent: Sunday, October 23, 2016 12:57 PM To: AK, GWO SUPT Well Integrity;AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Well Pad MN;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead;AK, OPS EOC Specialists;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;Wellman,Julie; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel, Troy;Worthington,Aras J;AK, GWO Well Integrity Well Information Subject: OPERABLE: Producer N-22B (PTD#2061610)Verified two compentant barriers All, Producer N-22B (PTD#2061610)was found to have sustained OA casing pressure above MOASP on 09/26/16,one day after being shut in.The well was reclassified as Under Evaluation for further diagnostics.After reenergizing the Y-seal on the inner casing packoff,a positive pressure packoff test passed on 10/08/16.A subsequent outer annulus repressurization test passed verifying two competent barriers.The well is now reclassified as Operable. Thanks, (7eAd Prnowa rt BP Well Integrity Engineer scANNED Mffi 9:?n iT Office:907-659-5525 Harmony-5415 AItk;rna1c: Rvaa Morn' GW Global Welts y S/ Orctanazat or From: AK, GWO . 'T Well Integrity Sent: Thursday, Septe :- 29, 2016 4:26 PM To: AK, OPS GC2 OSM; AK, 0' C2 Field O&M IL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad MN; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; , *PS EOC Specialists; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Ilman, Julie; 'Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov) Cc: AK, GWO SUPT Well Integrity; AK, GWO DHD Well In - ; AK, GWO Projects Well Integrity; AK, GWO Completions Well Integrity; AK, OPS FF Well Ops Comp Rep; 'chris.wallace@a ,a.gov' (chris.wallace@alaska.gov); Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Be. .• Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, Aras J Subject: UNDER EVALUATION: Producer N-22B (PTD #2061610) Sustained OA g Pressure above MOASP All, Producer N-22B (PTD#2061610)was found to have sustained OA casing pressure above MOASP on 06 6/16,one day after being shut in. Confirmed wellhead pressures were TBG/IA/OA= 1100/1250/1250 psi.The well is recla 'fled as Under Evaluation for further diagnostics. 1 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, September 29, 2016 4:26 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad MN; AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; AK, OPS EOC Specialists; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; Wellman, Julie; Regg, James B (DOA) Cc: AK, GWO SUPT Well Integrity;AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity; AK, OPS FF Well Ops Comp Rep; Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, Aras J Subject: UNDER EVALUATION: Producer N-22B (PTD #2061610) Sustained OA Casing Pressure above MOASP Attachments: Producer N-22B (PTD #2061610)TIO Plot 2016-09-29.docx All, Producer N-22B (PTD#2061610) was found to have sustained OA casing pressure above MOASP on 09/26/16, one day after being shut in. Confirmed wellhead pressures were TBG/IA/OA= 1100/1250/1250 psi.The well is reclassified as Under Evaluation for further diagnostics. Plan forward: 1. Downhole Diagnostics: OART 2. Wellhead: PPPOT-IC A TIO plot is attached for reference. Please reply if in conflict with proposed plan. SCANNED FEB 1 3 2011 Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C: (907)943-0296 H: 2376 Email: AKDCWeIllntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Tuesday, Marc -2 .Z, 2012 6:05 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS-P. odd Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Phillips, Patti J Cc: Walker, Greg (D&C); Olson, Andrew Subject: OPERABLE: Producer N-22B (PTD #2061610) OA Pressure Stable All 1 • Producer N-22B(PTD#2061610) TIO Plot 09/29/2016 ''... Well&11 +Tb9 tk iCa -+-OF ,.. -4-000A •••••On araraf 101 1;1 "':J616 9'1116 O'ic16 6"<?16 OEVY6 am mint 96116 anis 439"16 aa-.4'96 931716 (61&16 • �t( - zzS Regg, James B (DOA) Prb 206/6, to From: AK, D &C Well Integrity Coordinator [ AKDCWeIllntegrityCoordinator @bp.com] Sent: Tuesday, March 27, 2012 6:05 PM � 1 5/Z-7/1 To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Phillips, Patti J Cc: Walker, Greg (D &C); Olson, Andrew Subject: OPERABLE: Producer N -22B (PTD #2061610) OA Pressure Stable Attachments: N -22B TIO 03- 27- 12.doc All, Producer N -22B (PTD #2061610) has been monitored over the last 20 days and the OA is not exhibiting any signs of repressurization as seen in the attached TIO plot. The well is reclassified as Operable. Thank you, Mehreen VazirA R `1:01‘. (11tcrrncite: Gerald t hirph r) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegritvCoordinator @BP.com From: Reynolds, Charles (Alaska) Sent: Monday, March 05, 2012 2:59 PM To: AK, D &C Well Integrity Coordinator; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Pro. ontrollers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services 0• rations Team Lead; AK, RES GPB West Wells Opt Engr; Phillips, Patti 3 Cc: Walker, Greg (D &C); Clingingsmith, Mike J; Olson, Andrew Subject: UNDER EVALUATION: Producer N -22B (PTD #2061610) Sustai • -d OA Pressure Above MOASP All, Producer N -22B (PTD # 2061610) was found to have sustain- OA casing pressure above MOASP after being shut in. The wellhead pressures were tubing /IA/OA equal to 620/14.I/1500 on 03/03/2012. The well has been reclassified as Under Evaluation while diagnostics are conducted. Plan forward: 1. D: Cold OART 2. W: Cold PPPOT -IC A TIO plot and wellbore schematic hay: seen included for reference. 1 PBU N -22B PTD # 2061610 3/27/2012 TIO Pressures Plot Well: N -22 4,000 • 3.000 - Tbg —IN— IA 2000- — DA • • • .. — 000A On 1.000 - • 12/31/11 01/07/12 01/14/12 01/21/12 01/26/12 02/04/12 - - 02/11/12 02/18/12 02/25/12 03/03/12 03/10/12 03/17/12 03/24/12 • P& 4 ,J z z rj PT) 266,160 Regg, James B (DOA) From: Reynolds, Charles (Alaska) [Charles.Reynolds ©bp.com] Sent: Monday, March 05, 2012 2:59 PM ��( ���'� To: AK, D &C Well Integrity Coordinator; Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Phillips, Patti J Cc: Walker, Greg (D &C); Clingingsmith, Mike J; Olson, Andrew Subject: UNDER EVALUATION: Producer N -22B (PTD #2061610) Sustained OA Pressure Above MOASP Attachments: Producer N -22B (PTD # 2061610) TIO.doc; N- 22B.pdf All, Producer N -22B (PTD # 2061610) was found to have sustained OA casing pressure above MOASP after being shut in. The wellhead pressures were tubing /IA/OA equal to 620/1460/1500 on 03/03/2012. The well has been reclassified as Under Evaluation while diagnostics are conducted. Plan forward: 1. D: Cold OART 2. W: Cold PPPOT -IC A TIO plot and wellbore schematic have been included for reference. OA -Cf • Thank You, N'L `f = 53 60 r ;; Charles Reynolds . rKA s � L`�� li+ YYF =7 Filling in for... o k- Mehreen Vazir t. 11tc:'rnatc': t;era /J.tlu ph31 Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegritvCoordinator @BP.com 1 PBU N -22B PTD # 2061610 3/5/2012 TIO Pressures Plot Wef= N -22 4.000 I • 3,000 - ■ ■ I j # Tbg t w 2.000 - — + —OA OOA —♦ 000A On 1 Y I 1.000 - I ` 1 I I 12/10/11 12/17/11 12/24/11 12/31/11 01/07/12 01/14/12 01/21/12 01/28/12 02/04/12 02/11/12 02/18/12 02/25/12 03/03/12 TREE = CNd • WELLHEAD = MCEVOY N -2 2 B SAFETY NOTES: ** *CHROME TUBING ACTUATOR= BAKER // ORIG KB. ELEV = 80.3' ORIG BF. ELEV = 44.5' , 0'1, ORIG KOP = 3100' Max Angle = 102° @ 10809' 0 $ 0 * 1759' I- 19 -5t8" HES ES CEMENTER 1� Datum MD = 10406' : 1 Datum TVD = 8800' SS 2216" --f 4 -1/2 HES X NIP, ID = 3.813 I GAS LIFT MANDRELS 9 -58" CSG, 474, L -80, ID= 8.681" H 1814' 1 ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3412 3401 17 MMG DOME RK 16 09/20/08 ° 13 -3/8" CSG, 72 #, L -80, ID = 12.347" I---I 2693' 3 6378 5690 42 MMG SO RK 20 09/20/08 2 8209 7126 38 KBG2 DMY BK 0 09/20/08 Minimum ID = 3.725" @ 9758' 1 9624 8271 36 KBG2 DMY BK 0 09/20/08 4-1/2" XN NIPPLE 1 7078' I- 9 -5/8" x 7" BKR C2 ZXP LT PKR, ID = 6.26" ID w /11.6' TIEBACK & HMC LNR HGR 9 -5/8" CSG, 47#, L -80, ID = 8.681" H 7240' 1 - 9-5/8" MILLOUT WINDOW 7240' - 7257' U I 9693' H4 -1/2 HES X NIP, ID = 3.813 I 0 e 9714' H7" x 4 -1/2" BKR S -3 PKR, ID = 3.875" I I 9738' H4 -1/2 HES X NIP, ID = 3.813 I I 9759' H4 -1/2 HES XN NIP, ID = 3.725 I 4 -1/2" TBG, 12.64, 13CR80, H 9771' _�- 9766' I- 7" x 5" BKR ZXP LT PKR, ID = 4.41" VAM TOP, .0152bpf, ID = 3.958" - w /11.4' TIEBACK & HMC LNR HGR TOP OF 4 -1/2" LNR I-1 9766' ' 9771' - 14 -1/2 WLEG, ID = 3.958" I I I-I ELMD NOT LOGGED I 7" LNR, 26 #, L -80, BTC-M, ID = 6.276" I-1 9908' I bh PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: ° @ 12840' I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 4 12840 - 13060 0 03/07/07 I 2 -7/8" 4 12250 - 12430 0 03/07/07 I PBTD H 13068' I Oa 1 14 -1 /2" LNR, 12.64, L -80, IBT,.0152 bpf, ID = 3.958" I-I 13155' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/28/86 ORIGINAL COMPLETION WELL: N -22B 04/25/98 SIDETRACK (N -22A) PERMIT No: 2061610 03/10/07 N2ES SIDETRACK (N -22B) API No: 50- 029 - 21349 -02 11/11/09 JLS /SV FINAL DRAFT SEC 8, T11N, R13E, 706' FSL & 531' FWL 03/09/11 PJC SFTY NOTE CORECTION BP Exploration (Alaska) UNDER EVALUATION: Producer N•B (PTD #2061610) Sustained Casingssure on the 0... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator @bp.com] Sent: Monday, January 31, 2011 8:32 PM (� 2-11/1/ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Subject: UNDER EVALUATION: Producer N -22B (PTD #2061610) Sustained Casing Pressure on the OA - POP to eval IAxOA comm Attachments: N -22B TIO Plot 01- 31- 11.doc; N- 22B.pdf All, Producer N -22B (PTD # 2061610) was classified as Not Operable during the shut down due to sustained casing pressure on the OA. The wellhead pressures were tubing /IA/OA equal to SSV/1360/1340 psi on 01/13/2011. The well has been reclassified as Under Evaluation so that it may be placed on production to perform diagnostics. Please notify Well Integrity after the well has thermally stabilized so DHD can begin monitoring for OA repressurization. The plan forward is as follows: 1. W: PPPOT -IC DEB 0 7 7.011 2. DHD: OART A TIO plot and wellbore schematic have been included for reference. «N -22B TIO Plot 01- 31- 11.doc» «N- 22B.pdf» - Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 2/1/2011 PBU N -22B PTD 2061610 1/31/2011 TIO Pressures Plot Well: N -22 4,000 I 3,000 - — 4110— Tbg —a— IA 2,000 - —A— OA 00A —� 000A On 1,0_!00 F FF� • • 12104/10 12/11/10 12110110 12/25/10 01/01/11 01/60/11 01/15/11 01/22/11 01/29/11 TREE= CIW WELLHEAD = MCEVOY SAFETTES: ***CHROM E TUBING*** ACTUATOR = BAKER ORIG KB. ELEV = 80.3' ORIG BF. ELEV = 44.5' ♦ 1�1!' ORIG KOP = 3100' 1 11 Max Angle = 102° @ 10809' 1 1759' I- 9 -518" HES ES CEMENTER 1� 1 Datum MD = 10406' ++ 1 *1 Datum TV D = 8800' SS: 2216' 1-14-1/2 HES X NIP, ID = 3.813 I GAS LIFT MANDRELS 9 -58" CSG, 47 #, L -80, ID = 8.681" I-f 1814' I ST) MD TVD DEV TYPE VLV LATCH PORT DATE 4 3412 3401 17 MMG DOME RK 16 09/20/08 13 -3/8" CSG, 72 #, L -80, ID = 12.347" I-I 2693' 3 6378 5690 42 MMG SO RK 20 09/20/08 2 8209 7126 38 KBG2 DMY BK 0 09/20/08 Minimum ID = 3.725" @ 9758' 1 _ 9624 8271 36 KBG2 DMY _ BK 0 09/20/08 4 -1/2" XN NIPPLE 7078' 1- 9 -5/8" x 7" BKR C2 ZXP LT PKR, ID = 6.26" w /11.6' TIEBACK & HMC LNR HGR 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 7240' }- 9 -5/8" MILLOUT WINDOW 7240' - 7257' I 9693' I I4 -1/2 HES X NIP, ID = 3.813 9714' H7" x 4 -1/2" BKR S -3 PKR, ID = 3.875" I 1 9738' 1-14-1/2 HES X NIP, ID = 3.813 I 9759' H4 -1/2 HES XN NIP, ID = 3.725 I I 9766' I- 7" x 5" BKR ZXP LT PKR, ID = 4.41" 4 -1/2" TBG, 12.6 #, 13CR80, 9771' w/11.4' TIEBACK & HMC LNR HGR VAM TOP, .0152bpf, ID = 3.958" 9771' H4 -1/2 WLEGI H ELMD NOT LOGGED I 7" LNR, 26 #, L -80, BTC-M, ID = 6.276" I -- { 9908' I A PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: ° @ 12840' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 4 12840 - 13060 0 03/07/07 2 -7/8" 4 12250 - 12430 0 03/07/07 PBTD H 13068' I r•v I',, 4 -1/2" LNR, 12.64, L -80, IBT,.0152 bpf, ID = 3.958" H 13155' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/28/86 ORIGINAL COM PLETION WELL: N -22B 04/25/98 SIDETRACK (N -22A) PERMIT No: 2061610 03/10/07 N2ES SIDETRACK (N -22B) API No: 50- 029 - 21349 -02 11/11/09 JLS /SV FINAL DRAFT SEC 8, T11N, R13E BP Exploration (Alaska) • � Page l of l Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Friday, January 14, 2011 10:34 PM 1ciq' 01 )1( To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr; AK, OPS GC3 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC1 OSM; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, OPS Well Pad DFT N2; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Bommarito, Olivia 0; Robertson, Daniel B (Alaska); Ramsay, Gavin; Stone, Christopher; Kirchner, Carolyn J; Longden, Kaity; Phillips, Patti J; Sayed, Mohamed; Holt, Ryan P (ASRC) Subject: Producers with sustained casing pressure on IA and OA due to proration All, The following producers were found to have sustained casing pressure on the IA during the proration January 12 -14. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 11 -05A (PTD #1961570) C -15A (PTD #2090520) E -17A (PTD #2042040) E -27A (PTD #1990590) F -04B (PTD #2100870) W -01A (PTD #2031760) FEB 0 7 2U W -16A (PTD #2031000) W -21A (PTD #2011110) W -25A (PTD #2091020) W -38A (PTD #2021910) The following producers were found to have sustained casing pressure on the OA during the proration January 12 -14. The immediate action is to perform an OA repressurization test and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. 09 -34A (PTD #1932010) M -21A (PTD #1930750) C am' -228 (PTD #2051610) All the wells listed above will be classified as Not Operable until start-up operations commence and are stable or the well passes a pressure test proving integrity. After start -up, the wells will then be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 1/24/2011 • ~ `~ ~, ;; .~ . `~`' ~..~ ~,~~ ~ ~,. ,. ,~ e ~, ~~ ~~~t r ~, ~ a ,~,, ~ a ~ __ ~~ ~ ' ' .: ~' ...~~ ,,~ r"~ #' ``' ~ . . ~n ^~ ~ a=' 4 ,~ ~, ~_ ~~ ~ t ~~u~~ ~ fi .~ ~ Ilf MLCROFILMED 6/30/20.10 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc DATA SUBMITTAL COMPLIANCE REPORT 3/26/2009 Permit to Drill 2061610 Well Name/No. PRUDHOE BAY UNIT N-22B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21349-02-00 MD 13155 TVD 8956 Completion Date 3/10/2007 Complet ion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION /may Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR! GR /RES ! PWD, USIT, DIR / GR /RES /DEN / NEU, SC (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name - Scale Media No Start Stop CH Received Comments -- og Sic C.tv~~.~-C~„ia( 5 Col 1 0 7500 Case 4/20/2007 USIT, Cement BL, GR, I CCL 14-Feb-2007 og ~Snaic C++r~u)j a .. 5 Col 1 0 7500 Case 4/20/2007 USIT, Corrosion BL, GR, CCL 14-Feb-2007 Log Cement Evaluation 5 Col 1 7090 10450 Case 4/20/2007 SCMT CBL, VDL, GR, CCL 6-Mar-2007 C Las 15491 ~ uction/Resistivity 7032 13155 Open 10/3/2007 DRHO, RPM, FNCL, GR, CNCL, NPHI, RHOB, ROP w/PDS graphics Field Data LIS Verification 7032 13155 Open 5/19/2008 LIS Veri, GR, ROP, RPD, FET, RPM, RPX, RPS, NPHI, NCNT, FCNT, RHOB,DRHO C Lis 16266 ~duction/Resistivity 7032 13155 Open 5/19/2008 LIS Veri, GR, ROP, RPD, FET, RPM, RPX, RPS, - NPHI, NCNT, FCNT, RHOB,DRHO Induction/Resistivity 25 Col 7240 13155 Open 11/3/2008 MD DGR, EWR, ROP, ALD, CTN 7-Mar-07 Induction/Resistivity 25 Col 6349 8955 Open 11/3/2008 TVD DGR, EWR, ROP, ALD7-Mar-07 ~(~ ~ } .t. C 17120~~e-Notiss iy ~ 0 0 11/3/2008 PDS, EMF and CGM ya ~/~t r ~ ~ ~ ~~ ~ graphics of EWR logs. DATA SUBMITTAL COMPLIANCE REPORT 3/26/2009 Permit to Drill 2061610 Well Name/No. PRUDHOE BAY UNIT N-226 Operator BP EXPLORATION (ALASKA) INC MD 13155 TVD 8956 Completion Date 3/10/2007 Completion Status 1-OIL Current Status 1-OIL Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ,I 1~ Chips Received? R'1-N-' Analysis "?'TI~^ Received? Comments: Daily History Received? ~/ N Formation Tops ~ N API No. 50-029-21349-02-00 UIC N Compliance Reviewed By - __ _ _ Date: __`~ _OW`-~J WELL LOG TRANSMITTAL To: State of Alaska October 9, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: N-22B AK-MW-4872790 N-22B: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-21349-02 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-21349-02 Digital Log Images: 1 CD Rom 50-029-21349-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Bryan Burinda Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 907.273-3536 Date: Signed: ao~-i~~ ~ ~ ~~aa -~ WELL LOG TRANSMITTAL To: State of Alaska Apri131, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: N-22B AK-MW-4872790 1 LDWG formatted CD rom with verification listing. API#: 50-029-21349-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 _.. J Y Date:; ~ ~;~~ Signed: / ~UC~ -l ~ ~ ~~~~ ~~ Date 09-20-2007 Transmittal Number:92904 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) have any questions, please contact llouglas llortch at the Yll(_; at J64-4y /.5 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 09-15A ao'~-ua9 ~ ~S`!~0 __._ __ _ __ AG1-1OA~o6-i3S ~' i5~/$a _ _ __ _ ___ - _ _ ___ __ F-O1A ao~-tar * iSti~3 IIQ5`t1f`/ F-01 APB1 _____ F-09Bao~-~t3 ~ ~5~/1s5 F-42A 2a'~- U~3 " a 5~l~Slo L-204L1 a~_pc~3 ~ t5~/~'~ L-204L2 ~ p~_ bg y ~ tS~/~`d L-204L3 a(~(o-0~2S ~t5~1g9 L-204L4 a U(o-p~ ~, '~ t Ste! ~ ~ V-205L1 ~V~- l~~ ~' IS~1Sa V-205L2 c9UCo- f $c7 ~ t 5~3 W-204L1_c?_U(o~ _S9 g t_'sSj°i_~! __ W-204L2 w(o-l fo_D *' 1~L14 5 Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2- l 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 t 5' ., ~chlumb~r~er Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~ ? u 200 -1~:a?k~ t,3il ash t~~s f;t~tn~. f ~~lt~@€~~:„~. ~Ik? ~A, .4`~~~; -~ ~ i Wall _Inh ~t :.... ns~.. ..a:..., NO 4214 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay n: 04/16/07 DS 04-01 11637323 SCMT 03/13/07 1 2-34/P-14 11638622 USIT 03/20/07 1 N-22B . 11594483 SCMT 03/06/07 1 N-226 N!A USIT (CORROSION) 02/13/07 1 N•226 N/A USIT (CEMENT BOND) 02113!07 1 P2-506 11626472 SCMT 03/17/07 1 09-11 ~ 11638619 USIT (CEMENT EVALUATION) 03/16/07 1 09-11 11638619 USIT (CORROSION) 03/16/07 1 09-11 11638621 CEMENT BOND LOG 03/19/07 1 L2-32 11221617 RST 10/13/06 1 1 A-24 11221856 RST 03!23/06 1 1 ~~~ ..~wv~ ..w~.. . v. ~w..u.v ~.w roc ~ vnr~mv vl~c vvr 1 G/1Vfl I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I~E~EIVEC3 APR 1 1 2007 Alaska Gil ~ des Cons. Commissiotl 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAACZS.~os zoAACZS.i~o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One O 1b. Well Class: ItChOrage ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date om , Susp., or Ab~ryt~. ~ 3/10/2007 ~ ~D 12. Permit to Drill Number 206-161 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded (~ 2/ /2007 ~1N1 .~`~ 13. API Number 50-029-21349-02-00 4a. Location of Well (Governmental Section): Surface: ' 1' 7. Date T.D. Reached 3/4/2007 14. Well Name and Number: PBU N-226 706 FSL, 53 FWL, SEC. 08, T11 N, R13E, UM Top of Productive Horizon: 2668' FNL, 3266' FWL, SEC. 17, T11 N, R13E, UM 8. KB Elevation (ft): 72.58' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2705' FNL, 627' FWL, SEC. 16, T11 N, R13E, UM 9. Plug Back Depth (MD+TVD) 13068 + 8956 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 634407 y- 5966610 Zone- ASP4 10. Total Depth (MD+TVD) 13155 + 8956 Ft 16. Property Designation: ADL 028284 TPI: x- 637213 y- 5963286 Zone- ASP4 Total Depth: x- 639854 y- 5963298 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD DIR / GR /RES /PWD, USIT, DIR / GR /RES /DEN / NEU, SCMT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD 1-10LE AMOUNT SIZE WT. PER FT. GRADE TOP ' ' BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2693' Surface 2693' 17-1/2" 3720 cu ft Permafrost'E' & PF 9-5/8" 47# L-80 Surface 7 Surface 6349' 12-1/4" 1890 cu ft 'G', 230 cu ft'G', 674 cu ft'G' 7" 26# L-80 7078' 9908' 6223' 8499' 8-1/2" 390 cu ft LiteCrete 196 cu ft Class 4-1/2" 12.6# L-80 9766' 13155' 8384' 8956' 6-1/8" 483 cu ft Class'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gun Diameter, 4 spf 4-1l2", 12.6#, 13Cr80 9771' 9714' MD TVD MD TVD 12250' - 12430' 8929' - 8944' 12840' - 13060' 8968' - 8956' 2rj, ACID,. FRACTURE, CEMENT'SOUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Hi KIND OF MATERIAL USED Freeze Protect w/ Diesel 26. PRODUCTION TEST Date First Production: April 4, 2007 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 4/9/2007 Hours Tested 4 PRODUCTION FOR TEST PERIOD DIL-BBL 639 GAS-MCF 388 WATER-BBL 396 CHOKE SIZE 95 GAS-OIL RATIO 606 FIOW TUbing Press. 220 CaSing PreSSUfe 1,680 CALCULATED 24-HOUR RATE OIL-BBL 3,836 GAS-McF 2,325 WATER-BBL 2,376 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheen,-jf nec~s,~. Submit core chips; if none, state "none". ~ ~~ APR ~ ~ ?~~~ ~ ~ ~~ - `'~ None '~ ~~~~ ~ i Form 10-407 Revised 12/2003 R ~ G I N A CONTINUED ON REVERSE SIDE y.~~`~~ f~``** ~. 28 GEOLOGIC MARKS 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAMe MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". TSGR 9908' 8499' None TSHA 9948' 8531' TSHB 10000' 8573' TSHC 10025' 8593' TSAD 10054' 8617' TGCL /Zone 3 10250' 8774' BCGL /Zone 2C 10410' 8875' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~^^~~~-/ Si d V `~~a/b7 / ~ gne Title Technical Assistant Date Terrie Hubble PBU N-22B 206-161 Prepared By Name/Number.~ Terrie Hubble, 564-4628 Well Number Permit No. / A rOV81 NO. Drilling Engineer: ,/Ohn ROSe, 564-5271 INSTRUCTIONS GeNeRn~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Suppfy 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. IreM 4b: TPI (Top of Producing Interval). IreM 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: N-22 Common Name: N-22 Test Date l- Test Type -. 2/19/2007 FIT 2/26/2007 FIT Test Depth (TMD~ Test Depth (TVD AMW 1 Surface Pressure Leak Off Pressure (BHP) i EMW 7,270.0 (ft) 6,355.0 (ft) 10.50 (ppg) 520 (psi) 3,986 (psi) 12.08 (ppg) 9,928.0 (ft) 8,515.0 (ft) 8.40 (ppg) 750 (psi) 4,466 (psi) 10.10 (ppg) Printed: 3/12/2007 11:59:46 AM BP EXPLORATION Operations Summary Report Legal Well Name: N-22 Common Well Name: N-22 Event Name: REENTER+COMPLETE Start: 1/10/2007 Contractor Name:. NABOBS ALASKA DRILLING I Rig Release: 3/10/2007 Rig Name: NABOBS 2ES Rig Number: Date !From - To I Hours I Task I Code I NPT I Phase 2/9/2007 (10:30 - 12:30 I 2.00 ~ MOB I P ~ PRE 12:30 - 13:30 I 1.001 MOB I N I WAIT I PRE 13:30 - 19:30 6.00 MOB P PRE 19:30 - 22:00 2.50 MOB N WAIT PRE 22:00 - 00:00 2.00 MOB P PRE 2/10/2007 00:00 - 06:30 6.50 MOB P PRE 06:30 - 07:30 1.00 RIGU P PRE 07:30 - 09:30 2.00 RIGU P PRE 09:30 - 14:00 4.50 RIGU P PRE 14:00 - 14:30 I 0.501 W HSUR I P I I DECOMP 14:30 - 15:00 0.50 WHSUR P DECOMP 15:00 - 15:30 0.50 WHSUR P DECOMP 15:30 - 16:30 1.00 WHSUR P DECOMP 16:30 - 17:00 0.50 WHSUR P DECOMP 17:00 - 20:00 3.00 WHSUR P DECOMP 20:00 - 21:00 1.001 W HSUR P DECOMP 21:00 - 23:30 2.50 WHSUR P DECOMP 23:30 - 00:00 0.50 WHSUR P DECOMP 2/11/2007 00:00 - 04:00 4.00 WHSUR P DECOMP 04:00 - 11:00 7.00 BOPSU P DECOMP 11:00 - 16:00 5.00 BOPSU~N SFAL DECOMP 16:00 - 18:00 2.00 BOPSU P DECOMP 18:00 - 18:30 0.50 BOPSUFj P DECOMP 18:30 - 19:30 1.00 BOPSU P DECOMP 19:30 - 20:30 1.00 PULL P DECOMP 20:30 - 22:30 2.001 PULL P DECOMP Page 1 of 15 Spud Date: 5/27/1985 End: 3/10/2007 Description of Operations Rig down lines. Pull pits away from sub. Lay derrick over and back rig off well. Move pits, shop, camp from A to N pad. Wait on security to escort Nordic 2 to Oxbow turnoff before beginning move. Move camp, shop, pits to N Pad. Wait on security to escort Nordic 1 camp from G to C Pad. Move sub complex from A to N Pad. Transport sub to N Pad,lay herculite and spot sub. PJSM. Raise and pin derrick. PJSM. Spot and connect Pits. Spot cuttings tank,shop,camp, and support buildings. Rig up rig floor and berming. Bridle down and complete pre-spud list. Rig accept 14:00 02/10/2007. Pre-Spud meeting with all personnel. Rig up secondary annulus valve. Rig up circulating lines from tree to cuttings tank through choke. Rig up DSM,pull BPV with lubricator. Rig up circulating lines and test to 2000 psi. Reverse circulate clean seawater down annulus to displace diesel freeze protect from tubing. When tubing cleared swap directions and pump down tubing until diesel out of annulus. Circulate clean seawater around through tubing cut at 9306',6 BPM ~ 530 psi. Verify well is dead,shut in and blow down circulating lines. Dry rod TWC,test from below to 1000 psi. Blow down and rig down circulating lines. Nipple down tree and adaptor. Nipple up BOP's Nipple up BOP.Cut riser to fit. PJSM. Fill stack,test BOP's and related equipment,including hydraulic and manual chokes, to 250 psi low and 4000 psi high with 5 1/2" test joint. Test Hydril to 250 psi low and 2500 psi high. Test witness waived by Chuck Scheve AOGCC, test witness by Blair Neufeld and Dick Maskell BP, WSL. Change out failed 5" dart valve and test IBOP. Lower IBOP (mud saver) failed low pressure test. Grease, function and re-test, failed. PJSM. Remove saver sub, change out lower IBOP valve. Test lower IBOP and outer mud cross, 250 psi low and 4000 psi high. Blow down surface equipment, and rig down testing equipment. Circulate on top of TWC to clear any debris. Rig up DSM lubricator, pull TWC. Rig up 5 1/2" handling equipment, make up spear and engage in tubing. Back out lock down screws. Attempt to pull 5 1/2" 17# tubing. Pull 280k,work pipe, break circulation. Pull and work pipe at 325k, circulate 5 BPM ~ 230 psi, work pipe while waiting on slick line. 11' of pipe stretch at 300k pull =stuck @ -5500' (not accurate Printed: 3/12/2007 11:59:51 AM BP EXPLORATION Operations Summary Report Page 2 of 15 Legal Well Name: N-22 Common Well Name: N-22 Spud Date: 5/27/1985 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 3/10/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/10/2007 Rig Name: NABOBS 2ES Rig Number: Date ;From - To 'Hours Task Code NPT Phase I Description of Operations 2/11/2007 20:30 - 22:30 2.00 PULL P DECOMP due to deviated hole) 22:30 - 00:00 1.50 PULL N DPRB DECOMP 2/12/2007 00:00 - 02:30 2.50 PULL N DPRB DECOMP 02:30 - 03:00 0.50 PULL N DPRB DECOMP 03:00 - 05:30 2.50 PULL N DPRB DECOMP 05:30 - 09:00 3.50 PULL N DPRB DECOMP 09:00 - 10:00 1.00 PULL P DECOMP 10:00 - 10:30 0.50 PULL N DPRB DECOMP 10:30 - 11:30 1.00 PULL P DECOMP 11:30 - 12:30 1.00 PULL P DECOMP 12:30 - 16:00 3.50 PULL P DECOMP 16:00 - 21:30 5.50 PULL P DECOMP 21:30 - 23:30 2.00 CLEAN P DECOMP 23:30 - 00:00 0.50 CLEAN P DECOMP 2/13/2007 00:00 - 03:30 3.50 CLEAN P DECOMP 03:30 - 10:00 6.50 CLEAN P DECOMP 10:00 - 11:00 1.00 CLEAN P DECOMP 11:00 - 11:30 0.50 CLEAN P DECOMP 11:30 - 13:30 2.00 CLEAN P DECOMP 13:30 - 16:00 2.50 CLEAN P DECOMP 16:00 - 17:30 1.50 CLEAN P DECOMP 17:30 - 00:00 6.50 EVAL P DECOMP 2/14/2007 00:00 - 02:00 2.00 EVAL P DECOMP 02:00 - 04:00 2.00 DHEOP P DECOMP 04:00 - 05:30 1.50 DHEOP N DFAL DECOMP Release spear from tubing and lay down same. Blow down top drive. Wait on SWS E line unit to cut tubing. Wait on wireline unit to re-cut tubing. Pre-job safety meeting with crew and Schlumberger personnel. Spot wireline unit. Rig up shooting nipple & sheaves for wireline Run in hole with CCL, jet cutter to 7800'. Log on depth and fire jet cutter at 7595' MD. POH with E line & LD cutter. LD sheaves and lubricator on rig floor. MU spear and engage top tubing joint. Back out LDS. PU to 140 klbs and pipe was moving -good cut. Pull hanger to floor. Dis-engage spear. Cut control lines and flatten same. Break out tubing hanger and LD. RD all SWS equipment and clear floor. Lay down spear and hanger,pick up single and break cross over. Clear floor and re-hang rig tongs to lay down tubing. Rig up power tongs, and spooling unit. Lay down 5 1/2",17# tubing from 7595' to SSSV. Rig down spooling unit. Lay down 5 1/2",17# tubing from 5506' to surface.Clear and clean floor. Recovered 5 SS bands,26 clamps,SSSV, and 2 GLM's. 178 jts one 28.97' cut off. Rig up 4" test joint,install test plug. Test upper and Tower rams to 250 psi low and 4000 psi high. Test Hydril to 250 psi low and 2500 psi high. Test witnessed by BP rep. Blair Neufeld (WSL). Pull test plug and install wear ring. Bring BHA components to rig floor up beaver slide. PJSM Pick up and make up 9 5/8" scraper assembly to 322'. PJSM. Pick up DP and RIH to 7560'. Up weight 155k, down 125k. Slip and cut 128' of drilling line. Service top drive and draworks. Tag stump at 7595'. Pump hi-vis sweep surface to surface at 570 gpm with 2065 psi. Pump one more bottoms up. Pump dry job and blow down top drive. POOH to 322'. Change out handling equipment. POOH and lay down BHA. Nothing in boot baskets. Clear and clean floor. Spot and rig up SWS. Make up tools. RIH with USIT/CBUGR to 7500'. Log up to surface, checking for top of cement and corrosion. Log out with USIT/CBL. TOC at 1900'. Second joint above TOC at 1824'. Cut to be at -1808'. No significant corrosion detected. Change out SWS line head. PJSM. Pick up and make up string shot assembly. RIH and locate second collar above TOC at 1824'. Spot string shot 6' above and 6' below collar and attempt to fire. Fire failed. Pull up, run back down. Pull up to space out and attempt to fire again. Fire failed. POOH with wireline to PU new string shot assembly. Panted: 3/12/2007 11:59:51 AM BP EXPLORATION Page 3 of 15 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: 'Rig Name: N-22 N-22 Spud Date: 5/27/1985 REENTER+COMPLETE Start: 1/10/2007 End: 3/10/2007 NABOBS ALASKA DRILLING I Rig Release: 3/10/2007 NABOBS 2ES Rig Number: Date I From - To Hours I Task ;Code 2/14/2007 ~ 05:30 - 07:30 07:30 - 08:00 08:00 - 09:00 09:00 - 11:30 2.00 DHEOP N 0.50 DHEOP P 1.00 CASE P 2.50 CASE P 11:30 - 16:00 16:00 - 16:30 16:30 - 21:00 4.50 I CASE I N 0.50 CASE P 4.50 CASE P 21:00 - 22:00 I 1.001 CASE I P 22:00 - 00:00 2/15/2007 00:00 - 03:30 03:30 - 10:30 2.00 CASE P 3.50 CASE P 7.00 CASE P 10:30 - 13:30 13:30 - 14:00 14:00 - 14:30 14:30 - 15:30 15:30 - 16:00 3.001 CASE I P 0.50 CASE P 0.50 CASE P 1.00 CASE P 0.50 CASE P NPT ~ Phase ~ Description of Operations DFAL DECOMP PJSM. Trouble shoot and re-run string shot. Locate second collar above TOC at 1824'. Fire string shot. DECOMP POOH with string shot. Fired OK. Rig down SWS. DECOMP PJSM. Pick up casing cutter tools. Change out elevators. Pick up single. Make up multi-string casing cutter, pump out sub and XO's. DECOMP RIH. Locate casing collar at 1811'. Verify by locating collar above at 1771' and collar below at 1849'. Lay down 2 singles. Up weight 55k, down 50k, RT 52k. Pull up 16' and cut 9-5/8" casing at 1795'. Free torque 1 k, cutting 2-4k at 50 rpm. Pump at 220 gpm with 880 psi. WOB 3-5k. 9-5/8" casing stub at 1795'. SFAL DECOMP PJSM. LRS (Hot Oil) having trouble with unit. Close bag. Line up cuttings tank and gain immediate returns without pumping. Allow to u-tube while rolling pump periodically to warm up mud lines. Waiting on LRS. Circulate 30 bbls seawater down DP taking crude returns to cuttings tank. Pump at 63 gpm with 80 psi. Shut down and monitor returns. Returns fall off to trickle. Roll pumps at 63 gpm every 15 minutes to warm up lines and wait for LRS. DECOMP Rig up LRS hot oil truck. DECOMP PJSM. Circulate 75 bbls of 100 degree diesel down DP and up 13-3/8" x 9-5/8" annulus with LRS. Chase with 100 degree seawater. Pump at 42 gpm to displace diesel out of well into cuttings tank. Once diesel out of hole increase rate to 210 gpm and pump down 9-5/8" x 4" annulus through cut and into cuttings tank. Open hydril. Blow down and rig down circulating lines and LRS. DECOMP POOH. Lay down casing cutter. Cutters in good shape. Clear and clean floor. DECOMP Change out top variable rams to 9-5/8" rams. Pull wear ring. Install test plug. Rig up 9-5/8" test joint. Test 9-5/8" rams and door seals to 250 psi low, 4000 psi high as per AOGCC. Pull test plug and rig down test joint. DECOMP PJSM. Pick up false bowl and 9-5/8" handling equpment. Install false bowl. Make up 9-5/8" spear assembly. RIH and engage spear. Back out lock down screws. Unseat 9-5/8" casing with 135k up weight. Free up weight 105k. Pull hanger and pack off to rig floor. DECOMP Break out and lay down spear assembly. Pull and lay down 9-5/8" casing. Recovered 46 full joints and cut joint of 24.45'. Recovered 13 turbulators. Rig down tongs and false bowl. Clear and clean floor. DECOMP PJSM. Pick up, steam and make up washpipe assembly, jars, bumper sub and float. RIH to 342'. Change out handling equipment. DECOMP RIH to 1780'. Up and down weight 70k. DECOMP Break circulation at 1 bpm. Rotate down over 9-5/8" stub at 1795'. Swallow to 1823' and pull up to 1816'. DECOMP Circulate soap around with 100 degree seawater at 336 gpm with 540 psi. Blow down top drive. Remove blower hose. DECOMP POOH to 342' and change out handling equipment. Printed: 3/12/2007 11:59:51 AM BP EXPLORATION Page 4 of 15 ~ Operations Summary Report Legal Well Name: N-22 Common Well Name: N-22 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date ;' From -To Hours Task Code; NPT Spud Date: 5/27/1985 Start: 1 /10/2007 End: 3/10/2007 Rig Release: 3/10/2007 Rig Number: Phase j Description of Operations 2/15/2007 16:00 - 17:30 1.50 CASE P DECOMP POOH and lay down washpipe assembly. Clear floor. 17:30 - 19:30 2.00 CASE P DECOMP Pick up and make up back off tool assembly to 321'. 19:30 - 21:00 1.50 CASE P DECOMP RIH to 2115'. Fill every 5 stands. Up and down weight 75k. Rig up test pump to drill string. 21:00 - 23:00 2.00 CASE P DECOMP Pick up and place upper anchor at 1801', lower anchor at 1827' with collar at 1811'. Pressure up string to set anchors with 1000 psi for bottom and 2500 psi for top. Attempt to break 9-5/8" connection with 5000 psi. Unsuccessful with 2 tries. Close bag and pressure up to 200 psi to take out any slack in pipe. Bleed off and pressure up to 5000 psi again to try and back off 9-5/8" casing. Unsuccessful with 2 more tries. Rig down test pump. 23:00 - 00:00 1.00 CASE N DFAL DECOMP Drop dart and open circ sub. Pump dry job and blow down top drive. POOH to 883'. 2/16/2007 00:00 - 00:30 0.50 CASE N DFAL DECOMP POOH with Backoff tool assembly to 321'. 00:30 - 01:30 1.00 CASE N DFAL DECOMP PJSM. LD BHA. Break and lay down backoff tool assembly. Stand back DC's. Break out XO's, pump out sub and blanking sub. 01:30 - 04:00 2.50 CASE N DFAL DECOMP Spot SWS unit for second string shot run. Running 5 strand string shot as per Jim Nigh. PJSM. Rig up E-Llne unit. 04:00 - 05:30 1.50 CASE N DFAL DECOMP RIH with E-Line string shot. Shoot 6' above and 6' below collar at 1811'. Shot fired OK. 05:30 - 06:00 0.50 CASE N DFAL DECOMP Rig down SWS E-line unit. Prepare for second run with backoff toot assembly. 06:00 - 07:30 1.50 CASE N DFAL DECOMP PJSM. Make up backoff tool BHA to 321'. 07:30 - 09:00 1.50 CASE N DFAL DECOMP Change out handling equipment. RIH to 2215' filling every 5 stands. Rig up test pump to drill string. 09:00 - 10:30 1.50 CASE N DFAL DECOMP Pick up and set top anchor at 1801' and bottom anchor at 1826'. Collar at 1811'. Pressure up drill string to 2000 psi. Connection broke at 20klbs. Back off 4 turns. 10:30 - 11:00 0.50 CASE P DECOMP Pick up and release tool. Rig down test pump. Drop dart and open circ sub. Circulate and pump dry job. Blow down top drive. 11:00 - 11:30 0.50 CASE P DECOMP POOH to 321'. 11:30 - 13:00 1.50 CASE P DECOMP Change out handling equipment. Lay down backoff tool. Rack back drill collars. Clear and clean floor. 13:00 - 13:30 0.50 CASE P DECOMP Pick up and make up 9-5/8" spear assembly to 25'. Change out handling equipment. 13:30 - 14:30 1.00 CASE P DECOMP RIH to 1795'. Up weight 53k. Pick up single. Engage spear and verify with 20k over pull. Stack off. Make 5 turns to the left. Pick up free. 14:30 - 15:30 1.00 CASE P DECOMP POOH to 25'. 15:30 - 17:30 2.00 CASE P DECOMP PJSM. Install false bowl. Lay down bumper sub. Remove spear and lay down cut joint. Cut joint at 15.14'. Service break spear assembly. Clear and clean floor. 17:30 - 19:00 1.50 CASE P DECOMP PJSM. Change out bales. Rig up to run 9-5/8", 47#, L-80, TCII casing. 19:00 - 21:00 2.00 CASE P DECOMP PJSM. Make up screw in sub/baffle collar and pup. Run ES cementer and XO. Run one joint TCII casing. 21:00 - 22:00 1.00 CASE N SFAL DECOMP Unable to achieve optimum torque with power tongs. Swap out casing power tongs. 22:00 - 00:00 2.00 CASE P DECOMP Continue to run 9-5/8" 47#, L-80 TCII casing to 742'. 2/17/2007 00:00 - 04:00 4.00 CASE P DECOMP PJSM. Continue to run 9-5/8" 47# L-80 TCII casing. Tag up. Up weight 100k, down 95k. Printed: 3/12/2007 11:59:51 AM i, • BP EXPLORATION Page 5 of 15 Operations Summary Report Legal Well Name: N-22 Common Well Name: N-22 Spud Date: 5/27/1985 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 3/10/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/10/2007 Rig Name: NABOBS 2ES Rig Number: Date 'From - To ~ Hours Task Code; NPT Phase Description of Operations 2/17/2007 104:00 - 05:00 I 1.001 CASE I P I I DECOMP 05:00 - 07:00 2.001 CASE ~ P DECOMP 07:00 - 07:15 0.25 ~ CASE I P DECOMP 07:15 - 07:30 I 0.251 CASE I P I I DECOMP 07:30 - 08:30 ~ 1.00 ~ CASE ~ P ~ ~ DECOMP 08:30 - 09:00 I 0.501 CASE I P I I DECOMP 09:00 - 11:00 I 2.001 CASE I P I I DECOMP 11:00 - 14:30 ~ 3.501 CASE P ~ (DECOMP 14:30 - 16:30 I 2.001 CASE I P I I DECOMP 16:30 - 21:30 I 5.001 CASE I P I I DECOMP 21:30 - 22:30 1.00 CASE P DECOMP 22:30 - 00:00 1.50 CASE P DECOMP 2/18/2007 00:00 - 01:30 1.50 CLEAN P DECOMP 01:30 - 03:00 1.50 CLEAN P DECOMP 03:00 - 04:00 1.00 CLEAN P DECOMP 04:00 - 05:00 1.00 CLEAN P DECOMP 05:00 - 06:00 I 1.001 CLEAN I P I I DECOMP 06:00 - 06:30 0.50 CLEAN P DECOMP 06:30 - 08:30 2.00 CLEAN P DECOMP 08:30 - 11:00 2.50 CLEAN P DECOMP 11:00 - 12:00 I 1.001 CLEAN I P I I DECOMP Space out. Make up screw in sub to 9-5/8" casing. Screw in and work torque down. Max torque at floor 12k. Pull 250k to verify. Load cement head and verify flag working ok. Rig up for casing test and cement job. Test casing to 2000 psi for 15 min - OK. PJSM for cement job concurrent. Pressure up to 2800 psi and open ES cementer. Circ while cementers air up & prime up. Pump 5 bbls freshwater and test fines to 4000 psi. Pump 75 bbls 9.8 ppg NaCI brine followed by 120 bbls (580 sx) 15.8 ppg Class G Gasblok cement - 4 bpm C~? 620 psi. Release ES cementer closing plug and displace cement with 133 bbls seawater at 5-6 bpm ~ 625 psi. See dye in brine at 98 bbls away and switch returns straight to cuttings tank. Continue displacement and land plug on cementer at 133 bbls away. Got back 20 bbls cement to surface. Flush stack through kill line and open annular preventer. PU to 150 klbs on weight indicator and pressure up to 1700 psi to close cementer. Bleed off pressure and verify closed - OK. CIP at 09:00 hrs. Rig down cement head and lines. Blow down lines. Clear floor. Suck out stack and 9-5/8" joint for cutting. PJSM. Remove mouse hole. Let air out of boots. Break tubing spool. Nipple down. Split BOP and casing spoils. Atign casing and set casing in tension with 150k in emergency slips with primary packoff. Run in lock down screws. Rig up WACH's cutter and cut 9-5/8" casing. Lay down cut joint. Lower stack and drop casing spool. Pull riser. Set stack back on pedistal. Remove secondary annular valve. Remove casing head from cellar. Bring in prep, install and torque new McEvoy spoil with secondary packoff. Test packoff to 3800 psi. Hold for 30 minutes. Test OK. Install secondary annular valve. Nipple up BOP. Install mouse hole. Reassmble cellar floor. PJSM. Change out upper rams to 3-1/2" x 6" variables. Make up test joint. Install test plug and test top rams, doors, body and flange to 250 psi low, 4000 psi high as per AOGCC. Pull test plug. Install wear ring. Break and lay down test joint. PJSM. PU Baker tools PJSM. Make up Bit and pick up BHA to 315'. RIH with 4" DP to 1715'. Install blower hose. Make up top drive. Wash down at 402 gpm with 475 psi. Tag cement at 1749'. Tag plug at 1759'. Drill out cement and top plug at 28 rpm with 1-3k torque on bottom, 1-2k torque off bottom. WOB 5-15k. Up and down weight 65k, RT 70k. Stop 7' above baffle adapter. Circulate hi-vis sweep surface to surface until clean. PJSM. Test casing to 4000 psi for 10 minutes. Good test. Drill out baffle collar at 1808'. Pump sweep surface to surface. Remove blower hose. Blow down top drive. Continue to run in hole to 7595'. Tag tubing stump at 7595'. Rack back one stand. Up weight 150k, down 130k. Circulate hi-vis sweep surface to surface at 500 gpm with 1580 Printed: 3/12/2007 11:59:51 AM DECOMP DECOMP DECOMP WEXIT WEXIT BP EXPLORATION Operations Summary Report Legal Well Name: N-22 Common Well Name: N-22 Event Name: REENTER+COMPLETE Start: 1/10/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/10/2007 Rig Name: NABOBS 2ES Rig Number: Date 'From - To Hours Task j Code NPT Phase 2/18/2007 11:00 - 12:00 ( 1.00 CLEAN 1 P DECOMP 12:00 - 14:30 14:30 - 16:30 2.50 CLEAN P 2.00 CLEAN P DECOMP DECOMP 16:30 - 18:30 18:30 - 21:00 21:00 - 21:30 21:30 - 00:00 2/19/2007 00:00 - 01:30 01:30 - 06:30 06:30 - 08:00 ~~ `~ 08:00 - 17:00 ~' ~ '~ ~~®7`° 2.00 DHB P 2.50 DHB P 0.50 DHB P 2.50 STWHIP P 1.50 STWHIP P 5.00 STWHIP P 1.50 STWHIP P 9.00 STWHIP P 17:00-17:30 0.50 STWHIP P 17:30-21:00 3.50 STWHIP P 21:00 - 00:00 3.00 STWHIP P 2/20/2007 00:00 - 01:00 1.00 STWHIP P 01:00 - 02:00 1.00 STWHIP P 02:00 - 03:00 03:00 - 06:30 1.00 STWHIP P 3.50 STWHIP P 06:30 - 08:00 1.501 STWHIPI P WEXIT WEXIT Page 6 of 15 Spud Date: 5/27/1985 End: 3/10/2007 Description of Operations psi. Circulate hole clean. Reciprocate and rotate at 30 rpm. Pump dry job. POOH to 315'. POOH with BHA. Stand back drill collars. Break and lay down scraper BHA. Clean out boot baskets. Recover 1/2 gallon of cement, small pieces of metal and rubber. Clear floor. PJSM. Spot and rig up SWS E-Line. Make up EZSV. RIH with CCL and EZSV. Set top of plug at 7240'. Weight indicator showed good set. POOH and rig down SWS. Line up and test 9-5/8" casing and plug to 4000 psi, hold for 30 minutes and record on chart. Good test. PJSM. Pick up and makeup 9-5/8" whipstock BHA to 111'. Upload MWD. PJSM. Finish uploading MWD. Finish picking up BHA to 397'. PU first stand of DP and surface test MW D at 490 gpm with 715 psi. Good test. RIH with 9-5/8" whipstock at 75 fpm filling every 30 stands. Pick up last stand at 7180'. Make up blower hose. Orient whipstock to 70 degrees right. Set whipstock. Up weight 160k, down 120k. PJSM. Displace well to 10.5 ppg LSND mud at 526 gpm with 1690 psi. Reciprocate and rotate pipe at 75 rpm. Trucks could not keep up. Slow rate to 394 gpm with 1490 psi. Circulate to 10.5 ppg in and out. SPR #1 30/20, 45/350, #2 30/280, 45/350 at 7236'/0800 hrs. Start milling operations at 502 gpm with 2150 psi. Off bottom torque 2-3k, on bottom 5-7k at 70 rpm. WOB 2k. Up weight 160k, down 120k, RT 135k. Caught 100 pounds of metal by 1200 hrs. Finish milling window and 20' of new hole to 7270'. Pumping at 500 gpm with 2200 psi. Torque off bottom at 3k, on bottom at 4-5k at 85 rpm. WOB 8-15k. Up weight 145k, down 125k, RT 135k. Pump sweeps and clean up hole. Recovered a total of 200 pounds of metal. Ream and drift window. Pull up into casing. Mud weight in and out 10.5 ppg. Top of window at 7240', bottom at 7257'. WEXIT Line up and perform FIT to 12.07 ppg EMW with 520 psi. WEXIT PJSM. Mud weight in and out before trip 10.5 ppg. Pump dry job. Blow down top drive, kill and choke lines. Remove blower hose install air slips. POOH to 376'. WEXIT PJSM. Lay down drill collars and bumper sub. Download MWD and flush with fresh water. Lay down MWD, float sub, mills and HWDP. String mill in full guage. Clear floor. WEXIT PJSM. Continue to lay down tools from rig floor. WEXIT Pull wear ring. PU BOP jetting tool and flush stack. Lay down BOP jetting tool and install wear ring. Blow down kill and choke HCR's. Function test rams and Hydril. Blow down top drive. WEXIT PJSM. Pick up tools for 8-1/2" BHA. WEXIT PJSM. Pick up motor. Make up bit. PU MWD and upload. Continue picking up BHA to 824'. PJSM. Pick up joint of DP. Test MWD at 495 gpm with 1140 psi. Good test. Blow down top drive. WEXIT Pick up Drill Pipe singles to 3534'. Break circulation at 502 gpm Printed: 3/12/2007 11:59:51 AM BP EXPLORATION Page 7 of 15 Operations Summary Report Legal Well Name: N-22 Common Well Name: N-22 Spud Date: 5/27/1985 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 3/10/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/10/2007 Rig Name: NABOBS 2ES Rig Number: Date i From - To Hours Task Code NPT Phase i Description of Operations __ 2/20/2007 06:30 - 08:00 1.50 STWHIP P WEXIT with 1750 psi. 08:00 - 10:00 2.00 STWHIP P WEXIT Cointinue to run in hole to 7083'. Break circulation. Test MWD. 10:00 - 12:00 ~ 2.001 STWHIP P WEXIT 12:00 - 12:30 0.501 STWHIP~ P WEXIT 12:30 - 00:00 I 11.501 DRILL I P I I INT1 2/21/2007 100:00 - 12:00 12.001 DRILL P I INT1 12:00 - 00:00 I 12.001 DRILL I P I I INT1 2/22/2007 00:00 - 02:00 2.00 DRILL P INT1 02:00 - 04:00 2.00 DRILL N RREP INTt 04:00 - 04:30 0.50 DRILL P INT1 04:30 - 12:00 7.50 DRILL P INT1 12:00 - 12:30 I 0.501 DRILL I P I I INT1 12:30 - 13:30 I 1.001 DRILL I P I I INT1 13:30 - 16:30 I 3.001 DRILL I P f I INT1 16:30 - 18:00 1.50 DRILL N SFAL INT1 18:00 - 20:30 2.50 DRILL P INT1 20:30 - 00:00 I 3.501 DRILL I N I SFAL I INT1 2/23/2007 100:00 - 05:00 5.001 DRILL N SFAL INT1 05:00 - 05:30 I 0.501 DRILL I P I I INTi Blow down top drive. Up weight 150k, down 125k. PJSM. Slip and cut 80' of drilling line. Service top drive, drawworks and crown. Finish RIH. Orient and slip through window with no problem at 7249'. RIH to bottom at 7270'. Drill ahead to 7957'. Up weight 155k, down 130k, RT 147k. Pump at 500 gpm with 2600 psi off bottom, 2800 psi on bottom. Torque 4-5k off bottom, 6-7k on bottom at 80 rpm. WOB 10-15k. SPR's both pumps, 30/360, 45/430 at 7835'/2200 hrs. Mud weight in and out 10.6 ppg. ECD's 11.3. No losses encountered. Drill ahead to 8478' MD. Up weight 160k, down 134k, RT 148k. Pump at 451 gpm with 2430 psi off bottom, 2575 psi on bottom. Torque at 4-5k off bottom, 5-7k on bottom at 80 rpm. WOB 10-15k. Weight in and out 10.7 ppg. ECD's at 11.37 ppg EMW. Pump sweeps as needed. Drill ahead to 9032' MD, 7788' TVD. Up weight 175k, down 135k, RT 155k. Pump at 450 gpm with 2650 psi off bottom, 2880 psi on bottom. Torque at 6-7k off bottom, 7-9k on bottom at 80 rpm. WOB 10-25k. SPR's both pumps 30/340, 45/420 at 1230 hours/8486' MD. Mud weight in and out 10.7 ppg, ECD 11.3 ppg EMW. No losses encountered. Drill ahead to 9139' MD, 9066' TVD. Blower hose failure. Blower hose unraveled but did not part. Replaced hose and fittings. Serivice rig and top drive. Drilled ahead to 9469' MD. Up weight 190k, down 138k, RT 160k. Pump at 450 gpm with 2660 psi off bottom, 2989 psi on bottom. Torque 7-8k off bottom, 9-10k on bottom at 80 rpm. WOB 10-25k. Mud weight in and out 10.7 ppg. ECD 11.31 ppg EMW, calculated 11.21 ppg EMW. Adding tube for rising torque. No losses encountered. SPR #1 30/340, 45/430, #2 30/360, 45/440 at 9139'/1200 hrs. Hold follow up safety stand down meeting with Mike Schultz and Dan Hebert. Inspect pump and change out liner cap gasket #2 cyl. #2 mud pump. Drili ahead to 9657'. Up weight 190k, down 140k, RT 165k. Pump at 450 gpm with 2500 psi off bottom, 2600 psi on bottom. Torque 6-7k off bottom, 7-9k on bottom at 80 rpm. SPR's both pumps, 30/340, 45/430 at 9513'/1300 hrs. Attemp to seal suction cap gasket without success. Found hairline crack in discharge seat webbing on #2 mud pump. PJSM. Mud weight in and out 10.7 ppg. POOH wet inside window at 7176'. Up weight 200k, max up 220k. No problems. PJSM. Remove and replace #2 mud pump fluid end. Install new seats. PJSM. Repair and replace fluid end on mud pump #2. Service top drive and rig. Break circulation at 450 gpm with 2286 psi at top of window. Test MW D and orient to 70 degrees right. Printed: 3/12/2007 11:59:51 AM BP EXPLORATION Operations .Summary Report Legal Well Name: N-22 Common Well Name: N-22 Event Name: REENTER+COMPLETE Start: 1/10/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/10/2007 Rig Name: NABOBS 2ES Rig Number: Date ~ From - To ~ Hours , Task j Code ~ NPT -- ~ -- ' ~ 2/23/2007 05:30 - 08:00 2.50 DRILL P 08:00 - 12:00 4.00 DRILL P Phase INTi INTi 12:00 - 13:00 I 1.001 DRILL I P I I INT1 13:00 - 14:30 I 1.501 DRILL I P I I INT1 14:30 - 15:30 I 1.001 DRILL I P I I INT1 15:30 - 17:30 I 2.001 DRILL I P I I INT1 17:30 - 18:30 1.00 DRILL P INT1 18:30 - 19:00 0.50 DRILL P INT1 19:00 - 22:00 3.00 DRILL P INT1 22:00 - 00:00 2.00 DRILL P INT1 2/24/2007 00:00 - 02:30 2.50 DRILL P INTi 02:30 - 03:00 0.50 CASE P LNR1 03:00 - 03:30 0.50 CASE P LNR1 03:30 - 15:00 11.50 CASE P LNR1 15:00 - 18:30 I 3.50 I CEMT I P I I LNR1 Page 3 of 15 Spud Date: 5!27/1985 End: 3/10/2007 Description of Operations PJSM. Blow down top drive. RIH to 9657'. Directional drill to 9887'. Up weight 195k, down 145k, RT 175k. Pump at 450 gpm with 3150 psi off bottom, 3300 psi on bottom. Torque at 7-9k on bottom, 6-7k off bottom with 80 rpm. WOB 10-20k. SPR's both pumps, 30/280, 45/360 at 1200 hrs/9887'. Directional drill to intermediate TD of 9908' MD, TVD. Up weight 195k, down 145k, RT 170k. Torque on bottom 9-10k, off bottom 6-7k at 80 rpm. Pump at 450 gpm with 3220 psi off bottom, 3370 psi on bottom. WOB 10k. SPR's both pumps 30/280, 45/360 at 9887'/1200 hrs. Circulate sample to surface at 450 gpm with 3200 psi. Geologist called TD. Pump up survey. Short trip to 9600' with no problems. Go back to bottom. Make up top drive. Up weight 200k, down 140k, RT 170k. Circulate hi-vis sweep surface to surface at 240 gpm with 1404 psi. Mud pump #2 down, circulating with one pump. Rotate and reciprocate. Pump dry job and blow down top drive. PJSM. POOH to 7270' with no problems. MAD pass from 7270' to 7070' at 600 fph. POOH to 824'. Make up top drive and flush BHA with fresh water. Blow down top drive. PJSM. Lay down BHA to MWD. Download MWD. PJSM. Lay down BHA. PJSM. Lower BHA down beaver slide. Pick up liner running tools to rig floor. Rig up liner running tools. Run 7", 26#, L-80, BTC-M liner. Average torque 6600. RIH with float equipment, hanger, packer and 2802' of liner. RIH to 2971 and circulate one liner volume at 208 gpm with 235 psi. Continued running liner in hole on drill pipe to top of window at 7240 filling every 10 stands. Break circulation at window. Circulate 1.5 times DP and liner volume at 220 gpm with 560 psi. Up weight 150k, down 120k. PJSM. Continue to run in hole to TD at 9908' with no problems. PU cement head. Make up top drive and establish circulation at 1 bpm with 490 psi. Slack off, tag bottom, lose returns. Bring up rate to 3 bpm with 325 psi. Reciprocate pipe and re-establish returns. Continue to work pipe, up weight 210k, down 130k. Bring up rate to 4.5 bpm with 779 psi. Still loosing mud but have returns. Increase rate to 5 bpm with 836 psi with full returns. Line up to cementers. Pump 5 bbls water, test lines to 4000 psi. Pump Mudpush II and flush lines. Pump 31 bbls Mudpush II, followed by 69 bbls 12.5 ppg LiteCRETE lead slurry. Follow with 37 bbls 15.8 GASBLOK tail slurry. Shut down and clear lines with 5 bbls water. Displace with 63 bbls of 10.7 ppg mud and latch up to liner wiper plug. Continue to displace with 168 bbls of 10.7 ppg mud at 5 bpm for a total displacement of 173 bbls. Slowed pumps to 2 bpm with 171 bbls away and bumped blug, pressuring to 3500 psi to set hanger. Bleed off, 1.5 bbls back, check float, float holding. Rotate off packer with 1000 psi. Unsling verify pressure drop and circulate 40 bbls. Slow pumps and set down 50k to set packer. Packer set. Rotate and set back down 50k and verify Printed: 3/12/2007 11:59:51 AM t ~ BP EXPLORATION Page 9 of 15 ~ Operations Summary Report Legal Well Name: N-22 Common Well Name: N-22 Spud Date: 5/27/1985 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 3h 0/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/10/2007 Rig Name: NABOBS 2ES Rig Number: Date ~ From - To '. Hours Task Code ~ NPT ~ Phase Description of Operations 2/24/2007 ~ 15:00 - 18:30 ~ 3.50 CEMT P ~ LNR1 ~ set. 18:30 - 20:00 ~ 1.50 ~ CEMT ~ P ~ ~ LNR1 20:00 - 00:00 I 4.00 I CEMT I N I SFAL I LNR1 2/25/2007 00:00 - 01:00 1.00 CEMT N SFAL LNR1 01:00 - 02:00 1.00 CEMT P LNR1 02:00 - 02:30 0.50 CEMT P LNR1 02:30 - 06:30 4.00 CEMT P LNR1 06:30 - 14:00 I 7.501 BOPSUR P I I PROD1 14:00 - 15:00 1.00 BOPSU P PROD1 15:00 - 17:30 2.50 DRILL P PROD1 17:30 - 20:00 2.50 DRILL N DPRB PROD1 20:00 - 21:00 I 1.001 DRILL I P I I PROD1 21:00 - 23:00 I 2.001 DRILL I P I I PROD1 23:00 - 00:00 I 1.001 DRILL I P I I PROD1 2/26/2007 ~ 00:00 - 00:30 ~ 0.50 ~ DRILL ~ P ~ ~ PROD1 00:30 - 03:00 2.50 DRILL P PROD1 03:00 - 04:30 1.50 DRILL P PROD1 04:30 - 06:30 I 2.001 DRILL I P I I PROD1 06:30 - 0.00 PROD1 06:30 - 08:00 1.50 DRILL P PROD1 08:00 - 08:45 0.75 DRILL P PROD1 08:45 - 10:00 1.25 DRILL N WAIT PROD1 10:00 - 13:30 3.50 DRILL P PROD1 CIP at 1830 hrs. Losses at 30-35 bbls while pumping cemet. Lost 280 bbls mud during intial circulation. Pick up and circulate at 453 gpm with 2455 psi. Circulate until good mud back. No cement back to surface. Small amount of Mudpush II back on bottoms up. PJSM. Break out single and cemet head. Rig down and clear floor. Trouble shoot top drive. Frozen quill and lower valve. Got lower IBOP functioning. Thawing with whip hose and steam. Remove kelly hose from top drive and continue to thaw. PJSM. Continue to thaw kelly hose. PJSM. Slip and cut 80' of drilling line. PJSM. Service top drive. PJSM. Pump dry job. POOH with 4" DP and liner hanger running tool. Lay down liner hanger running tool. Clear and clean floor. PJSM. Pull wear. PJSM. Rig up and test ROPE and choke manifold. Test to 250 psi low, 4000 psi high. Test upper rams and annulur with 4-1/2" test joint. Test annular to 250 psi low, 2500 psi high. Test witness waived by Jeff Jones. Test witnessed by Bill Decker and Ronnie Dalton. Break out test joint and remove test plug. Install wear ring. PJSM. Pick up tools for 6-1/8" BHA up beaver slide. PJSM. PU motor and make up bit. Make up and RIH with flex collars. Upload MWD. DM tool failure. POOH and lay down flex collars, TM collar, RLL and change out DM collar. Pick up DM, TX and Flex collars. Upload MWD. PU remaining BHA and RIH to 364'. Pick up 1 joint of DP. Make up top drive and surface test MW D at 265 gpm with 1521 psi. Good test. Blow down top drive. PJSM. Pick up and RIH with 4" DP to 3449'. Break circulation at 260 gpm with 1860 psi. Fluid out of ba-ance. Make up top drive and circulate at 262 gpm with 1742 psi. Up and down weight 80k. While making up top drive drilling fluid was coming over the top and approximately 3 gallons of mud was blown over the windwall. Discharge was reported to 5700 for proper notification. Discharge was 100% cleaned up. Continue circulating to balance fluid. Hold PJSM for running in hole. RIH to 6800'. PJSM. Hold 4 stand stripping drill. All hands participated. Good meeting and feed back. Continue to RIH to landing collar for casing test. Fill pipe at 8772' with 250 gpm and 2200 psi. Tagged up at 9813'. Circulate and condition mud at 250 gpm with 2200 psi. Pull up to 9801' for casing test. PJSM. Test 7" casing to 4000 psi for 30 minutes. Good test. Waiting on trucks for fluid displacement. Drill cement from 9813' to 9826', through landing collar. Up Printed: 3/12/2007 11:59:51 AM ~ ~ BP EXPLORATION Page 10 of 15 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-22 N-22 Spud Date: 5/27/1985 REENTER+COMPLETE Start: 1/10/2007 End: 3/10/2007 NABOBS ALASKA DRILLING I Rig Release: 3/10/2007 NABOBS 2ES Rig Number: Date From - To Hours Task Code NPT -_ ---- 2/26/2007 ~ 10:00 - 13:30 3.50 DRILL P 13:30 - 16:30 3.001 DRILL P 16:30 - 18:30 I 2.001 DRILL I P 18:30 - 20:00 I 1.501 DRILL I P 20:00 - 20:30 I 0.501 DRILL I P 20:30 - 00:00 3.501 DRILL P 2/27/2007 100:00 - 12:00 I 12.001 DRILL I P 12:00 - 00:00 ~ 12.001 DRILL P 2/28/2007 100:00 - 12:00 12.00 I DRILL P 12:00 - 19:30 I 7.501 DRILL I P 19:30 - 21:30 I 2.001 DRILL I P Phase Description of Operations PROD1 weight 185k, down 125k, RT 150k. WOB 10-20k. Pumping at 250 gpm with 2300 psi on bottom, 2250 psi off bottom. Torque 6-7k off bottom, 8-9k on bottom at 20 rpm. SPR's both pumps, 30/490, 45/690 at 9810'/1000 hrs. Continue to drill through cement to 9895' pumping at 250 gpm with 2279 psi on bottom. Up weight 190k, down 125, RT 150k. PROD1 PJSM. Displace 10.7 ppg LSND with 8.4 ppg Flo-Pro. Pump 150 bbls water followed by 50 bbls hi-vis spacer. Chase with 8.4 ppg Flo-Pro mud at 250 gpm with 2267 psi. Pump surface to surface as per mud engineer. Shut down. Slowdown top drive while cleaning up shakers. SPR #1 30/570, 45/690; #2 30/560, 45/680 at 9895'/1600 hrs. PRODi PJSM. Drill out remaining shoe track and 20' of new formation to 9928' at 274 gpm with 1790 psi off bottom, 1830 psi on bottom. Up weight 165k, down 140k, RT 155k. WOB 2-12k. PROD1 Circulate bottoms up while reciprocating until mud weight in and out 8.4 ppg. PJSM. Rack back one stand. PROD1 Pertorm FIT, 9928' MD, 8515' TVD. Pressue up to 750 psi with 27 strokes for an FIT of 10.1 ppg EMW. Hold for 10 minutes and record data. Blow down kill line. Make up stand and RIH. PROD1 Directional drill to 9972' MD. WOB 5-20k. Pump at 274 gpm with 1790 psi off bottom, 1870 psi on bottom. Torque 2-4k off bottom, 4-5k on bottom at 20 rpm. Up weight 165k, down 145k, RT 155k. Mud weight in and out 8.4 ppg. No losses encountered. PROD1 Directional drill to 10,244'. Up weight 170k, down 145k, RT 160k. Pumping at 274 gpm with 1760 psi off bottom, 1850 psi on bottom. Torque 4-5k off bottom, 5-6k on bottom at 20 rpm. WOB 5-17k. Mud weight in and out 8.4 ppg. No losses encountered. PROD1 Drill 6 1/8" hole from 10,244' to 10,468',WOB 15-17k,RPM 20. Up wt. 175k,down wt. 140k,rotating wt. 160k. 279 GPM,1816 psi off bottom and 1860 psi on bottom. Mud wt in and out 8.4 ppg,vis 46,adding 8 BPH water, centrifuge and mud cleaner running to control drilled solids. Pumped hi-vis sweep with little to no difference noted in cutting load. PROD1 Drill 6 1/8" hole from 10,468' to 10,674' WOB 15-17k,RPM 20. Torque off bottom 4-5k and on bottom 5-6k Up wt. 175k,down wt. 140k,rotating wt. 160k. 279 GPM,1830 psi off bottom and 1900 psi on bottom. Mud wt in and out 8.4 ppg,vis 46,adding 8 BPH water, centrifuge and mud cleaner running to control drilled solids. PROD1 Drill 6 1/8" hole from 10,674' to 10,799' WOB 15-17k,RPM 20. Torque off bottom 4-5k and on bottom 5-6k Up wt. 175k,down wt. 140k,rotating wt. 160k. 279 GPM,1830 psi off bottom and 1900 psi on bottom. Mud wt in and out 8.4 ppg,vis 46,adding 8 BPH water, centrifuge and mud cleaner running to control drilled solids. PROD1 Circulate Hi-Vis sweep 272 GPM,1880 psi. with no increase in cuttings load when back to surface. Printed: 3/12/2007 11:59:51 AM BP EXPLORATION Operations Summary Report Legal Well Name: N-22 Common Well Name: N-22 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date i From - To j Hours Task Code NPT 2/28/2007 19:30 - 21:30 2.00 DRILL P 21:30 - 22:30 1.00 DRILL P 22:30 - 00:00 1.50 DRILL P 3/1/2007 00:00 - 02:30 2.50 DRILL P 02:30 - 04:00 1.50 DRILL P 04:00 - 04:30 0.50 DRILL P 04:30 - 08:00 3.50 DRILL P Start: 1 /10/2007 Rig Release: 3/10/2007 Rig Number: Page 11 of 15 ~ Spud Date: 5/27/1985 End: 3/10/2007 Phase Description of Operations PROD1 Blow down top drive. PROD1 PJSM. POOH from 10,799' to 9885',pump dry job,remove blower hose. Hole in good condition with no overpull and took correct displacement. PROD1 POOH from 9885' to 7002', hole taking correct displacement. PROD1 PJSM. POOH from 7002' to 364', hole took correct displacement. PROD1 PJSM. Handle BHA,Iay down TM collar,mud motor and bit. PROD1 Clear and clean floor. PROD1 PJSM. Make up BHA, new motor,bit and MW D with Neutron Density to 390'. Up-Load and shallow test MWD,250 GPM 2 680 psi. PJSM. Load radioactive sources. 08:00 - 10:00 I 2.001 DRILL I N I WAIT I PROD1 Safety stand down and derrick inspection after a 1 1/2" x 1 1/2" 10:00 - 14:00 4.00 DRILL P 14:00 - 14:30 0.50 DRILL P 14:30 - 00:00 I 9.501 DRILL I C 3/2/2007 100:00 - 02:00 I 2.001 DRILL I C 02:00 - 02:30 0.50 DRILL P 02:30 - 03:00 0.50 DRILL C 03:00 - 03:30 I 0.501 DRILL I P 03:30 - 12:00 8.50 DRILL P 12:00 - 00:00 12.00 DRILL P piece of metal and spring fell out of derrick. Remove damaged proximity arm from derrick. Object was from link tilt alarm switch. IR # 2172702 PROD1 Run in hole from 390' to 9908' filling pipe every 3000'. Make up top drive and circulate pipe volume,install blower hose. Blow down top drive. PROD1 Run in hole 9908' to bottom at 10,799',no fill,hole in good condition. PROD1 MAD pass log (real time) with MWD from bottom (10,799') to 10,200',220 GPM ~ 1360 psi.105 Whr,RPM 30. Up wt. 175k,down wt. 140k,rotating wt. 160k,torque off bottom 5-6k. Mud wt. in and out 8.4 ppg. PROD1 MAD pass log with MWD from 11,200' to 9980' X250 ft/hr, 220 GPM,1230 psi,30 RPM. Blow down top drive. PROD1 PJSM. Service top drive. PROD1 MAD pass log with MWD from 10,016' to 9950 ' 03250 fUhr, 220 GPM,1230 psi,30 RPM. Blow down top drive. PROD1 PJSM. Run in hole from 9950' to 10,799', no fill,hole in good condition. PROD1 Drill 6 1/8" hole from 10,799' to 11,043' WOB 8-12k,RPM 30. Torque off bottom 4-5k and on bottom 6-8k Up wt. 175k,down wt. 137k,rotating wt. 155k. 279 GPM,1760 psi off bottom and 1890 psi on bottom. Mud wt in and out 8.4 ppg,vis 45,adding 15 BPH water, centrifuge and mud cleaner running to control drilled solids. PRODi Drill 6 1/8" hole from 11,043' to 11,346' WOB 8-14k,RPM 60. Torque off bottom 5-6k and on bottom 7-8k Up wt. 185k,down wt. 135k,rotating wt. 160k. 280 GPM,1750 psi off bottom and 1970 psi on bottom. Mud wt in and out 8.5 ppg,adding 15 BPH water, centrifuge and mud cleaner running to control drilled solids. Cutting load light on shakers. OWC found and well path adjusted to follow down-dip. Printed: 3/12/2007 11:59:51 AM BP EXPLORATION Page 12 of 15 Operations Summary Report Legal Well Name: N-22 Common Well Name: N-22 Spud Date: 5/27h 985 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 3/10/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/10/2007 Rig Name: NABORS 2ES Rig Number: Date ~ From - To II Hours ~ Task Code NPT Phase Description of Operations 3/3/2007 00:00 - 12:00 12.00 DRILL P PROD1 12:00 - 00:00 12.00 DRILL P PROD1 3/4/2007 00:00 - 12:00 12.00 DRILL P PROD1 12:00 - 19:30 7.50 DRILL P PROD1 19:30 - 21:30 2.00 DRILL P PROD1 21:30 - 00:00 2.50 DRILL P PROD1 3/5/2007 00:00 - 02:30 2.50 DRILL P PROD1 02:30 - 04:00 1.50 DRILL P PROD1 04:00 - 05:00 1.00 DRILL P PROD1 05:00 - 06:00 1.00 DRILL P PROD1 Drill 6 1/8" hole from 11,346' to 11,977'. WOB 10-12k,RPM 80. Torque off bottom 7k and on bottom 8k Up wt. 180k,down wt. 130k,rotating wt. 155k. 280 GPM,1830 psi off bottom and 2130 psi on bottom. Mud wt in and out 8.5 ppg,adding 15 BPH water, centrifuge and mud cleaner running to control drilled solids. Cutting load light on shakers. Drill 6 1/8" hole from 11,977' to 12,462'. WOB 10-12k,RPM 80. Torque off bottom 6k and on bottom 7- 8k Up wt. 185k,down wt. 135k,rotating wt. 155k. 280 GPM,1820 psi off bottom and 2100 psi on bottom. Mud wt in 8.4+ppg and out 8.5 ppg,adding 15 BPH water, centrifuge and mud cleaner running to control drilled solids. Cutting load light on shakers. Well path going up and down chasing OWC. Drill 6 1!8" hole from 12,462' to 12,899'. WOB 10-12k,RPM 80. Torque off bottom 7k and on bottom 8k Up wt. 185k,down wt. 125k,rotating wt. 155k. 280 GPM,1800 psi off bottom and 2100 psi on bottom. Mud wt in 8.4+ppg and out 8.5 ppg,adding 15 BPH water, centrifuge and mud cleaner running to control drilled solids. Cutting load light on shakers. Well path going up to OW C. Drill 6 1/8" hole from 12,899' to TD at 13,155'. WOB 10-12k,RPM 80. Torque off bottom 7k and on bottom 8k Up wt. 185k,down wt. 125k,rotating wt. 160k. 280 GPM,1840 psi off bottom and 2130 psi on bottom. Mud wt in 8.5ppg and out 8.5 ppg,adding 15 BPH water, centrifuge and mud cleaner running to control drilled solids. Cutting load light on shakers. Well path following OWC. Circulate Lo-Vis/weighted sweep,300 GPM ~ 2030 psi,rotate and reciprocate. No increase in cuttings toad with sweep to surface. PJSM. Monitor well. Pump out of hole from 13,155' to 11,696'. 280 GPm @ 1800 psi. Up wt 180k,down wt. 130k, mud weight in and out 8.5 ppg. Pump out of hole from 13,155' to 11,696'. 280 GPM @ 1800 psi. Hole in good condition,no over pull. Drop circulation sub dart and pressure up to 2000 psi to open. Circulate bottoms up at 500 GPM ~ 1360 psi,rotate 20 RPM and reciprocate pipe. Pump dry job. Blow down top drive,remove blower hose POOH to top of 7" liner at 7075'. Circulate at 500 GPM,rotate at 20 RPM and wash up from 30' below liner lap to 30' above lap. Blow down top drive. Printed: 3/12/2007 11:59:51 AM BP EXPLORATION Page 13 of 15 Operations Summary Report Legal Well Name: N-22 Common Well Name: N-22 Spud Date: 5/27/1985 Event Name: REENTER+COMPLETE Start: 1/10/2007 End: 3/10/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/10/2007 Rig Name: NABOBS 2ES Rig Number: Date From - To ~ Hours I Task ~ Code i NPT - -- - _ - ~ ____ l 3/5/2007 06:00 - 08:30 2.50 DRILL P 08:30 - 12:00 3.50 DRILL P 12:00 - 13:00 1.00 CASE P 13:00 - 16:30 3.50 CASE P 16:30 - 17:00 ~ 0.50 ~ CASE ~ P 17:00 - 17:30 0.50 CASE P 17:30 - 22:00 4.50 CASE P 22:00 - 23:30 1.501 CASE P 23:30 - 00:00 I 0.501 CASE P 3/6/2007 100:00 - 02:00 2.00 I CASE P 02:00 - 02:30 I 0.50 I CASE I P 02:30 - 03:30 1.00 CASE P 03:30 - 07:00 3.50 CEMT P Phase j Description of Operations -- PROD1 POOH from 7494' to 390'. PROD1 Lay down BHA from 390',remove radioactive sources,and download MWD tools. Flush MWD & motor with water and lay down. Clear floor RUNPRD Rig up to run 4 1/2",12.6#,L-80,IBT-M liner. RUNPRD PJSM. Run 3555' of 4 1/2",12.6#,L-80,IBT-M production liner. Torque to 3800 fUlbs. RUNPRD Pick up liner hanger, liner top packer,crossover and pup joint. Liner wt. 35k. RUNPRD Circuiate liner volume 185 GPM @ 140 psi. RUNPRD PJSM. Run in hole with liner on drill pipe to 9865' filling every 10 stands. Depth GPM PSI Up wt. Down wt. 4348' 185 150 75k 75k 5285' 200 220 90k 85k 6218' 200 250 100k 95k 7062' 200 275 115k 105k 7997' 200 350 130k 110k 9022' 200 420 145k 120k RUNPRD Circulate bottoms up at Shoe 208 GPM ~ 535 psi. Up wt. 160k, dow wt. 125k Strokes Pressure 20 325psi 30 340psi 40 350psi 50 365psi RUNPRD Run in hole with 4 1/2",12.6#,L-80, IBT-M liner from 9865' to 10,332'. RUNPRD Run in hole with 4 1/2",12.6#,L-80,IBT-M,production liner from 10,332'to 11,135'. Depth up wt. down wt 10,888 165k 130k 11,882' 175k 124k 12,758' 175k 120k RUNPRD Make up cement head and pick up single,fill pipe,break circulation. RUNPRD Tag bottom at 13,155' and stage pumps up to 5 BPM. RUNPRD Pump 5bbl water and test lines to 4000 psi. Pump 47bb1 11 ppg Mud Push 11. (Reciprocate pipe.) Pump 86bb1 15.8ppg class G cement with Gas Blok. Clean lines through Tee Drop plug,pump 60.5bb1 perf pill. Pump 84 bbl 8.5ppg mud. Stop reciprocation with 15 bbl. through shoe as hole becomes tight. Bump plug with 145.2bb1 displacement,pressure up to 3500 psi. to set Hanger. Slack off to 75k. Bleed off and check floats,good. Pick up to 110k,rotate 20 turns to release running tool. Pressure up to 1000 psi and pick up to un-sting. Pump 40 bbl at 430 GPM C~ 2091 psi. Set 80k down to set packer. Printed: 3/12/2007 11:59:51 AM BP EXPLORATION Page ~4 of 15 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To ~ N-22 N-22 REENTE NABOB NABOB Hours R+COM S ALASK S 2ES Task PLET A DRI Code ~ E LLING NPT i Start I Rig Rig Phase ( Spud Date: 5/27/1985 : 1/10/2007 End: 3/10/2007 Release: 3/10/2007 Number: Description of Operations 3/6/2007 03:30 - 07:00 3.50 CEMT P RUNPRD Pick up,un-sting and circulate out cement 425 GPM C~ 1620 psi. Approximately 20 Bbls contaminated cement to surface. Cement in place at 04:55. 07:00 - 09:00 2.00 CEMT P RUNPRD Displace well to seawater, 180 SPM @ 2400 psi. Pump dry job,lay down cement head and single,and blow down surface equipment. 09:00 - 10:00 1.00 CEMT P RUNPRD Cut 109' of drilling line,service drawworks and brakes. 10:00 - 10:30 0.50 CEMT P RUNPRD Service top drive. 10:30 - 15:30 5.00 CEMT P RUNPRD PJSM. POOH from 13,100 to surface. Lay down liner running tool. 15:30 - 16:00 0.50 EVAL P RUNPRD Clear and clean rig floor. 16:00 - 17:00 1.00 EVAL P RUNPRD PJSM. pick up wire line tools and rig up wire line unit. 17:00 - 17:30 0.50 EVAL P RUNPRD PJSM. Make up logging tools. 17:30 - 23:30 6.00 EVAL P RUNPRD RIH with SCMT logging tools. 23:30 - 00:00 0.50 EVAL P RUNPRD PJSM. Test casing and liner to 4000 psi,hold and chart for 30 minutes.Good test. 3/7/2007 00:00 - 01:30 1.50 PERFO P OTHCMP Rig up to run perforating guns on drill pipe. 01:30 - 07:00 5.50 PERFO P OTHCMP PJSM with all personnel on picking up and safe handling of the guns. Pick up guns and 2 7/8" PAC drill pipe.Rig down 2 7/8" handling equipment. 07:00 - 12:00 5.00 PERFO P OTHCMP Run in hole from 3346' to 13,087',tag and pick up to firing depth at 13,060'. 12:00 - 13:00 1.00 PERFO P OTHCMP PJSM. Bottom guns at 13,060' and top set at 12,250'.2 7/8" HSD power jet 2906, with 4 shots per foot. Shot intervals,13,060' to 12,840' / 12,430 to 12,250'. Close well in and pressure up to 3000 psi,hold for 2 minutes. Bleed off and wait for 20 minutes with no indication of guns firing. Pressure up well to 3000 psi,pressure bled down to 2100 psi. over 2 minutes. Bleed pressure off and wait for 15 minutes,no indication of guns firing. Blow down top drive and kill line. 13:00 - 17:30 4.50 PERFO P OTHCMP PJSM. POOH from 13,060' to 3346' racking back pipe in derrick. 17:30 - 18:00 0.50 PERFO P OTHCMP PJSM. Rig up 2 7/8" handling equipment. 18:00 - 19:30 1.50 PERFO P OTHCMP PJSM. POOH from 3346' to 848' stand back 2 7/8" pipe in derrick.. 19:30 - 22:00 2.50 PERFO P OTHCMP PJSM. Lay down perforating guns,all guns fired. 22:00 - 23:30 1.50 PERFO P OTHCMP Clear and clean rig floor. 23:30 - 00:00 0.50 PERFO N DPRB OTHCMP PJSM. Run in hole with 2 7/8" pipe to 833'. 3/8/2007 00:00 - 01:30 1.50 PERFO N DPRB OTHCMP Run in hole with 2 7/8" PAC pipe from 833' to 2800'. Rig up to lay down. 01:30 - 05:30 4.00 PERFO P OTHCMP PJSM. Lay down 2 7/8" drill pipe.Rig down 2 7/8" handling equipment. 05:30 - 06:00 0.50 CLEAN N DPRB CLEAN PJSM. Make up bit,scraper and bit sub to drill pipe and run in hole. 06:00 - 09:30 3.50 CLEAN N DPRB CLEAN Run in hole to 9540' and wash down to tag up at 9767'. Up wt. 175k down wt. 135k. 09:30 - 11:30 2.00 CLEAN N DPRB CLEAN Circulate Hi-Vis sweep around at 495 GPM ~ 2290 psi. Rotate and reciprocate. Monitor well,pump dry job,blow down surface Printed: 3/12/2007 11:59:51 AM u BP EXPLORATION U Page 15 of 15 Operations Summary Report Legal Well Name: N-22 Common Well Name: N-22 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Start: 1 /10/2007 Rig Release: 3/10/2007 Rig Number: Spud Date: 5/27/1985 End: 3/10/2007 Date From - To ~ Hours Task Code I NPT ~ ~ , 3/8/2007 09:30 - 11:30 2.00 CLEAN N DPRB CLEAN 11:30 - 19:30 8.00 CLEAN P CLEAN 19:30 - 21:00 1.50 CLEAN P CLEAN 21:00 - 22:00 1.00 CLEAN P CLEAN 22:00 - 00:00 2.00 CLEAN P CLEAN 3/9/2007 00:00 - 01:00 1.00 CLEAN P CLEAN 01:00 - 03:00 2.00 BUNCO RUNCMP 03:00 - 17:30 14.50 BUNCO RUNCMP 17:30 - 19:30 I 2.001 RUNCOAY~ I I RUNCMP 19:30 - 23:00 I 3.501 RUNCON'P I I RUNCMP 23:00 - 00:00 I 1.001 RUNCON'P i I RUNCMP 3/10/2007 ~ 00:00 - 01:30 ~ 1.50 ~ RUNCOI~ ~ ~ RUNCMP 01:30 - 02:00 I 0.501 BOPSUR P I I RUNCMP 02:00 - 04:00 2.00 BOPSU~ P RUNCMP 04:00 - 06:00 2.00 W HSUB P RUNCMP 06:00 - 08:00 2.00 WHSUB P RUNCMP 08:00 - 09:30 1.50 WHSUB P RUNCMP 09:30 - 14:30 5.00 WHSUB P RUNCMP 14:30 - 15:30 1.00 WHSUB P RUNCMP 15:30 - 16:00 0.50 WHSUB P RUNCMP 16:00 - 16:30 0.50 WHSUB P RUNCMP 16:30 - 17:30 1.00 WHSUB P RUNCMP 17:30 - 18:00 0.50 WHSUB P RUNCMP equipment,remove blower hose. POOH laying down 4" drill pipe from 9767' to surface. Run in hole with 4" pipe from derrick to 3272'. PJSM. Cut and slip 81' of drilling line. PJSM. POOH laying down 4" drill pipe from 3272' to 320' Lay down 4" drill pipe from 320'. Lay down scraper and bit. Clear rig floor,pull wear ring. Install long bales,rig up torque turn equipment. Make up WLEG,XN nipple,2 x X nipples,Packer and #1GLM. Baker Lok joints below packer. Torque turn and run 4 1/2",12.6#,13Cr,Vam top tubing to no go at 9769'. Optimum torque 4400 ft/Ibs. Up wt. 142k down wt 104k. Tag upon liner top at 9757'and no go at 9769.68', space out with 2.02' pup putting tubing 5.86' above no go. Change out elevators,rig down compensator,make up hanger and landing joint. Land tubing on hanger,run in lock down screws. Rig up secondary kill line to annulus and reverse in corrosion inhibited seawater. Drop 1 7/8" ball & rod,lay down landing joint. Test tubing to 4000 psi,chart and hold for 30 minutes. PJSM.Test tubing to 4000 psi,chart and hold for 30 minutes. Bleed tubing pressure to 1500 psi and pressure up annulus to 4000 psi,chart and hold for 30 minutes.Bleed pressure off annulus and tubing. Pressure up annulus to shear DCR valve,sheared early at 1500 psi. Circulate 5 bbl through valve. Install TWC and test from below to 1000 psi. Blow down circulating lines. PJSM.Nipple down BOP's Nipple up adaptor flange and tree. PJSM. Test adaptor flange to 5000 psi for 30 minutes. Test tree to 5000 psi for 30 minutes. PJSM. Rig up lubricator and pull TWC. Rig down lubricator. Rig up Little Red Hot Oil Services circulating lines. Reverse circulate diesel freeze protect,3 BPM ~ 500 psi. U-tube freeze protect into tubing. Suck circulating lines back to unit. Rig down circulating lines. Dry rod BPV (Cameron). Test from below to 1000 psi. Rig down all circulating lines. Remove secondary annulus valve. Secure well. Rig release 18:00 03/10/2007 Description of Operations Phase Printed: 3/12/2007 11:59:51 AM Halliburton Company Survey Report Company: BP Amoco Date: 4/8/2007 'l'ime: 21:38:56 Page: I Field: Prudhoe Bay Co-ordinatefNE) Reference: Well: N-22, True North Sitr. PB N Pad ~ Vertical ("TVD) Ref'cr ence: N- 22B 72.6 I Wcll: N-22 Wellpath: N-226 Section (VS) Keference: Well (O.OON,O.OOE,122.35Azi) Survey Calculation D3cthod: Minimum Curvature Dh: Oracle ~~ _ _ _ - - _ - Field: Prudhoe Bay - -- _ _ North Slope UNITED STATES Map System:US State Pla ne Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: N-22 Slot Name: 22 N-22 Well Position: +N/-S 1171.21 ft Northing: 5966610.00 ft Latitude: 70 19 0.189 N +E/-W 1023.42 ft Easting : 634407.00 ft Longitude: 148 54 37.866 W Position Uncertainty: 0.00 ft Wellpath: N-226 Drilled From: N-22 500292134902 Tie-on Depth: 7 217.28 ft Current Datum: N-22B Height 72.58 ft Above System Datum: Mean Sea Level Magnetic Data: 2/15/2007 Declination: 23.94 deg Field Strength: 57648 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28 .08 0.00 0.00 122.35 Survey Program for Definitive Wellpath Date: 4/8/2007 Validated: Yes Version: 10 Actual From To Survey Toolcode Tool Name ft ft 92.28 7217.28 N-22 GYRODATA (92.28-9801.08) GYD-CT-CMS Gyrodata cont.casing m/s 7240.00 13108.53 N-22B IIFR+MS+Sag (7240.00-131 MWD+IFR+MS MWD +IFR + Multi Station Survey MD Intl Azim "1'VD Sys "1'VD N/S E/~i' t•9apN MapL•' Tool ft deg deg ft ft ft ft ft ft 28.08 0.00 0.00 28.08 -44.50 0.00 0.00 5966610.00 634407.00 TIE LfNE 92.28 0.10 129.95 92.28 19.70 -0.04 0.04 5966609.97 634407.04 GYD-CT-CMS 192.28 0.20 259.89 192.28 119.70 -0.12 -0.06 5966609.88 634406.94 GYD-CT-CMS 292.28 0.28 235.10 292.28 219.70 -0.29 -0.43 5966609.70 634406.57 GYD-CT-CMS 392.28 0.35 206.59 392.28 319.70 -0.71 -0.77 5966609.28 634406.24 GYD-CT-CMS 492.28 0.39 204.05 492.28 419.70 -1.29 -1.05 5966608.69 634405.98 GYD-CT-CMS 592.28 0.43 202.20 592.27 519.69 -1.95 -1.33 5966608.03 634405.71 GYD-CT-CMS 692.28 0.42 195.19 692.27 619.69 -2.65 -1.57 5966607.32 634405.48 GYD-CT-CMS 792.28 0.41 188.05 792.27 719.69 -3.36 -1.71 5966606.61 634405.35 GYD-CT-CMS 892.28 0.27 200.51 892.27 819.69 -3.93 -1.84 5966606.04 634405.23 GYD-CT-CMS 992.28 0.13 213.47 992.27 919.69 -4.25 -1.99 5966605.72 634405.09 GYD-CT-CMS 1092.28 0.08 176.35 1092.26 1019.68 -4.41 -2.05 5966605.55 634405.03 GYD-CT-CMS 1192.28 0.03 137.67 1192.26 1119.68 -4.50 -2.02 5966605.46 634405.06 GYD-CT-CMS 1292.28 0.23 108.31 1292.26 1219.68 -4.58 -1.82 5966605.39 634405.27 GYD-CT-CMS 1392.28 0.43 79.23 1392.26 1319.68 -4.58 -1.26 5966605.40 634405.82 GYD-CT-CMS 1492.28 0.50 80.36 1492.26 1419.68 -4.43 -0.46 5966605.56 634406.62 GYD-CT-CMS 1592.28 0.57 82.48 1592.26 1519.68 -4.29 0.46 5966605.71 634407.54 GYD-CT-CMS 1692.28 0.59 88.64 1692.25 1619.67 -4.22 1.47 5966605.81 634408.55 GYD-CT-CMS 1792.28 0.60 94.93 1792.24 1719.66 -4.25 2.51 5966605.80 634409.58 GYD-CT-CMS 1892.28 0.45 95.23 1892.24 1819.66 -4.33 3.42 5966605.73 634410.50 GYD-CT-CMS 1992.28 0.28 95.33 1992.24 1919.66 -4.39 4.06 5966605.68 634411.13 GYD-CT-CMS 2092.28 0.32 78.23 2092.24 2019.66 -4.36 4.57 5966605.73 634411.65 GYD-CT-CMS 2192.28 0.36 60.54 2192.24 2119.66 -4.14 5.12 5966605.95 634412.19 GYD-CT-CMS 2292.28 0.38 65.08 2292.23 2219.65 -3.85 5.69 5966606.25 634412.76 GYD-CT-CMS 2392.28 0.39 70.34 2392.23 2319.65 -3.60 6.31 5966606.52 634413.38 GYD-CT-CMS 2492.28 0.39 70.30 2492.23 2419.65 -3.37 6.96 5966606.76 634414.01 GYD-CT-CMS 2592.28 0.39 70.17 2592.23 2519.65 -3.14 7.60 5966607.00 634414.65 GYD-CT-CMS 2692.28 1.66 70.80 2692.21 2619.63 -2.54 9.28 5966607.62 634416.33 GYD-CT-CMS 2792.28 2.94 71.45 2792.13 2719.55 -1.25 13.08 5966608.98 634420.10 GYD-CT-CMS Halliburton Company Surve Re ort Y P G~mpaup: BP Amoco Field: Prudhoe Bay Site: PB N Pad ~ Well: N-22 ~i'cllpalh: N-22B Sun~ev -- = _ IVIU 1ncl ft deg im deg D ft s TVD ft Date: 4/8/2007 Time: 21:38:56 Page: 2 Co-ordinate(NE) Reference: Well: N-22, True North Vertical (TVll) Reference: N-226 72.6 Section (VS) Reference: Well (O.OON,O.OOE,122.35Azi) Survey Calculation Method: Minimum Curvature Dh: Oracle _ N/S F./W VIapN AIapE '1'001 ft ft ft ft 2892.28 5.48 84.08 2891.85 2819.27 0.06 20.27 5966610.42 634427.26 GYD-CT-CMS 2992.28 7.39 107.08 2991.23 2918.65 -1.34 31.17 5966609.22 634438.18 GYD-CT-CMS 3092.28 9.55 119.49 3090.14 3017.56 -7.31 44.54 5966603.49 634451.66 GYD-CT-CMS 3192.28 11.97 120.45 3188.38 3115.80 -16.65 60.70 5966594.44 634467.98 GYD-CT-CMS 3292.28 14.44 121.45 3285.73 3213.15 -28.42 80.28 5966583.03 634487.77 GYD-CT-CMS 3317.28 15.18 121.42 3309.90 3237.32 -31.75 85.73 5966579.79 634493.28 GYD-CT-CMS 3342.28 15.88 122.15 3333.98 3261.40 -35.28 91.42 5966576.37 634499.03 GYD-CT-CMS 3367.28 16.33 121.54 3358.00 3285.42 -38.93 97.31 5966572.82 634504.98 GYD-CT-CMS 3392.28 16.90 122.81 3381.96 3309.38 -42.74 103.36 5966569.12 634511.10 GYD-CT-CMS 3417.28 17.17 123.28 3405.86 3333.28 -46.74 109.50 5966565.24 634517.31 GYD-CT-CMS 3442.28 17.66 123.95 3429.71 3357.13 -50.88 115.73 5966561.21 634523.61 GYD-CT-CMS 3467.28 17.97 124.37 3453.52 3380.94 -55.17 122.06 5966557.03 634530.02 GYD-CT-CMS 3492.28 18.64 124.84 3477.25 3404.67 -59.63 128.52 5966552.68 634536.56 GYD-CT-CMS 3517.28 19.53 125.46 3500.88 3428.30 -64.34 135.20 5966548.10 634543.32 GYD-CT-CMS 3542.28 20.18 125.98 3524.39 3451.81 -69.30 142.10 5966543.26 634550.30 GYD-CT-CMS 3567.28 21.02 126.23 3547.79 3475.21 -74.48 149.20 5966538.21 634557.50 GYD-CT-CMS 3592.28 21.53 126.55 3571.09 3498.51 -79.86 156.51 5966532.96 634564.90 GYD-CT-CMS 3617.28 21.92 126.71 3594.31 3521.73 -85.38 163.93 5966527.57 634572.42 GYD-CT-CMS 3642.28 22.53 126.98 3617.45 3544.87 -91.05 171.50 5966522.04 634580.09 GYD-CT-CMS 3667.28 23.13 127.15 3640.50 3567.92 -96.90 179.24 5966516.33 634587.93 GYD-CT-CMS 3692.28 23.83 127.32 3663.43 3590.85 -102.93 187.17 5966510.45 634595.97 GYD-CT-CMS 3717.28 24.52 127.46 3686.23 3613.65 -109.15 195.30 5966504.38 634604.21 GYD-CT-CMS 3742.28 25.52 127.58 3708.89 3636.31 -115.59 203.69 5966498.09 634612.71 GYD-CT-CMS 3767.28 26.49 127.79 3731.36 3658.78 -122.29 212.36 5966491.55 634621.50 GYD-CT-CMS 3792.28 27.15 128.17 3753.67 3681.09 -129.23 221.25 5966484.76 634630.51 GYD-CT-CMS 3817.28 27.73 128.51 3775.85 3703.27 -136.37 230.29 5966477.78 634639.68 GYD-CT-CMS 3842.28 28.19 128.76 3797.93 3725.35 -143.69 239.45 5966470.63 634648.96 GYD-CT-CMS 3867.28 28.84 129.13 3819.90 3747.32 -151.19 248.73 5966463.29 634658.37 GYD-CT-CMS 3892.28 29.72 130.07 3841.71 3769.13 -158.99 258.15 5966455.67 634667.93 GYD-CT-CMS 3917.28 30.44 130.77 3863.34 3790.76 -167.11 267.69 5966447.72 634677.61 GYD-CT-CMS 3942.28 31.34 131.54 3884.79 3812.21 -175.56 277.35 5966439.45 634687.43 GYD-CT-CMS 3967.28 32.26 132.18 3906.04 3833.46 -184.35 287.16 5966430.83 634697.39 GYD-CT-CMS 3992.28 33.14 132.40 3927.08 3854.50 -193.44 297.15 5966421.93 634707.54 GYD-CT-CMS 4017.28 34.36 132.66 3947.87 3875.29 -202.83 307.39 5966412.72 634717.94 GYD-CT-CMS 4042.28 35.22 132.84 3968.40 3895.82 -212.51 317.86 5966403.23 634728.59 GYD-CT-CMS 4067.28 36.28 133.33 3988.69 3916.11 -222.49 328.53 5966393.44 634739.43 GYD-CT-CMS 4092.28 37.76 134.86 4008.65 3936.07 -232.97 339.33 5966383.16 634750.42 GYD-CT-CMS 4117.28 39.22 135.64 4028.21 3955.63 -244.02 350.29 5966372.31 634761.57 GYD-CT-CMS 4142.28 40.78 136.19 4047.36 3974.78 -255.56 361.46 5966360.97 634772.95 GYD-CT-CMS 4167.28 41.10 136.26 4066.25 3993.67 -267.39 372.80 5966349.35 634784.49 GYD-CT-CMS 4192.28 41.31 136.25 4085.06 4012.48 -279.29 384.19 5966337.66 634796.09 GYD-CT-CMS 4217.28 41.36 136.17 4103.83 4031.25 -291.21 395.61 5966325.95 634807.73 GYD-CT-CMS 4242.28 41.37 136.34 4122.59 4050.01 -303.14 407.04 5966314.22 634819.36 GYD-CT-CMS 4267.28 41.56 136.24 4141.33 4068.75 -315.11 418.47 5966302.46 634831.01 GYD-CT-CMS 4292.28 41.80 136.28 4160.00 4087.42 -327.12 429.97 5966290.66 634842.72 GYD-CT-CMS 4317.28 41.99 136.28 4178.61 4106.03 -339.18 441.51 5966278.80 634854.47 GYD-CT-CMS 4342.28 41.93 136.29 4197.20 4124.62 -351.26 453.06 5966266.93 634866.24 GYD-CT-CMS 4367.28 41.96 136.41 4215.79 4143.21 -363.36 464.59 5966255.05 634877.98 GYD-CT-CMS 4392.28 41.95 136.52 4234.38 4161.80 -375.47 476.10 5966243.14 634889.71 GYD-CT-CMS 4417.28 42.11 136.49 4252.95 4180.37 -387.61 487.62 5966231.21 634901.45 GYD-CT-CMS 4442.28 42.22 136.59 4271.48 4198.90 -399.80 499.17 5966219.24 634913.21 GYD-CT-CMS 4467.28 42.22 136.81 4290.00 4217.42 -412.02 510.69 5966207.22 634924.94 GYD-CT-CMS ~, ~ ~ • H alliburton Com an P Y Survey Report I Company: BP AMOCO Datc: 4/8/2007 Timc: 21:38:56 Pa~c: 3 Field: Prudhoe Bay Co-ordinatc(NF.) Reference: Well: N-22, True North Site: PB N Pad Vertical (f Vlll Reference N-22B 72.6 Nell: N-22 Section (VS) Reference: Well (O.OON,O.OOE,122.35Azi) !i Wellpath: N-22B Survey Calculation Method: Minimum Curvature Db: Oracle Sun'cr IVID Incl Arim TVll Sys'I'VD N/S F./~V A4apN 1\1apE "Cool ft deg deg ft ft ft ft ft ft 4492.28 42.27 136.73 4308.51 4235.93 -424.27 522.20 5966195.18 634936.67 GYD-CT-CMS 4517.28 42.32 136.84 4327.00 4254.42 -436.53 533.72 5966183.13 634948.41 GYD-CT-CMS 4542.28 42.57 137.02 4345.45 4272.87 -448.85 545.24 5966171.01 634960.15 GYD-CT-CMS 4567.28 42.60 137.02 4363.85 4291.27 -461.23 556.78 5966158.85 634971.90 GYD-CT-CMS 4592.28 42.77 137.17 4382.23 4309.65 -473.65 568.31 5966146.64 634983.66 GYD-CT-CMS 4617.28 42.76 137.23 4400.58 4328.00 -486.10 579.85 5966134.40 634995.41 GYD-CT-CMS 4642.28 42.71 137.28 4418.95 4346.37 -498.56 591.36 5966122.15 635007.15 GYD-CT-CMS 4667.28 42.67 137.26 4437.32 4364.74 -511.01 602.86 5966109.90 635018.87 GYD-CT-CMS 4692.28 42.38 137.37 4455.75 4383.17 -523.43 614.32 5966097.69 635030.54 GYD-CT-CMS 4717.28 42.49 137.22 4474.20 4401.62 -535.83 625.76 5966085.50 635042.20 GYD-CT-CMS 4742.28 42.66 137.32 4492.61 4420.03 -548.25 637.24 5966073.29 635053.90 GYD-CT-CMS 4767.28 42.64 137.21 4511.00 4438.42 -560.69 648.73 5966061.05 635065.61 GYD-CT-CMS 4792.28 42.55 137.17 4529.40 4456.82 -573.11 660.23 5966048.85 635077.33 GYD-CT-CMS 4817.28 42.55 137.22 4547.82 4475.24 -585.51 671.72 5966036.66 635089.04 GYD-CT-CMS 4842.28 42.58 137.11 4566.23 4493.65 -597.91 683.22 5966024.46 635100.76 GYD-CT-CMS 4867.28 42.32 137.20 4584.68 4512.10 -610.28 694.69 5966012.30 635112.45 GYD-CT-CMS 4892.28 42.24 137.30 4603.17 4530.59 -622.63 706.11 5966000.16 635124.08 GYD-CT-CMS 4917.28 42.45 137.22 4621.65 4549.07 -635.00 717.54 5965988.00 835135.73 GYD-CT-CMS 4942.28 42.56 137.29 4640.08 4567.50 -647.41 729.00 5965975.80 .635147.42 GYD-CT-CMS 4967.28 42.66 137.29 4658.48 4585.90 -659.84 740.48 5965963.57 635159.12 GYD-CT-CMS 4992.28 42.65 137.37 4676.87 4604.29 -672.30 751.96 5965951.33 635170.82 GYD-CT-CMS 5017.28 42.91 137.43 4695.22 4622.64 -684.80 763.46 5965939.04 635182.53 GYD-CT-CMS 5042.28 43.26 137.37 4713.47 4640.89 -697.37 775.01 5965926.68 635194.31 GYD-CT-CMS 5067.28 43.57 137.34 4731.63 4659.05 -710.00 786.65 5965914.25 635206.18 GYD-CT-CMS 5092.28 43.70 137.43 4749.73 4677.15 -722.70 798.33 5965901.76 635218.08 GYD-CT-CMS 5117.28 43.70 137.37 4767.80 4695.22 -735.41 810.03 5965889.26 635230.00 GYD-CT-CMS 5142.28 43.70 137.59 4785.88 4713.30 -748.14 821.70 5965876.75 635241.90 GYD-CT-CMS 5167.28 43.66 137.59 4803.96 4731.38 -760.89 833.34 5965864.21 635253.77 GYD-CT-CMS 5192.28 43.71 137.81 4822.03 4749.45 -773.66 844.96 5965851.65 635265.61 GYD-CT-CMS 5217.28 43.87 137.98 4840.08 4767.50 -786.50 856.56 5965839.02 635277.44 GYD-CT-CMS 5242.28 43.80 138.06 4858.12 4785.54 -799.37 868.15 5965826.36 635289.25 GYD-CT-CMS 5267.28 43.67 138.21 4876.18 4803.60 -812.24 879.68 5965813.70 635301.01 GYD-CT-CMS 5292.28 43.68 138.19 4894.26 4821.68 -825.11 891.19 5965801.04 635312.74 GYD-CT-CMS 5317.28 43.56 138.50 4912.36 4839.78 -838.00 902.65 5965788.36 635324.44 GYD-CT-CMS 5342.28 43.53 138.31 4930.48 4857.90 -850.88 914.08 5965775.69 635336.10 GYD-CT-CMS 5367.28 43.49 138.60 4948.61 4876.03 -863.76 925.50 5965763.02 635347.74 GYD-CT-CMS 5392.28 43.38 138.59 4966.77 4894.19 -876.65 936.87 5965750.33 635359.34 GYD-CT-CMS 5417.28 43.41 138.77 4984.93 4912.35 -889.55 948.21 5965737.64 635370.90 GYD-CT-CMS 5442.28 43.36 138.95 5003.10 4930.52 -902.48 959.51 5965724.91 635382.43 GYD-CT-CMS 5467.28 43.50 138.98 5021.26 4948.68 -915.45 970.79 5965712.15 635393.94 GYD-CT-CMS 5492.28 43.20 139.18 5039.43 4966.85 -928.42 982.03 5965699.39 635405.41 GYD-CT-CMS 5517.28 43.19 139.34 5057.66 4985.08 -941.38 993.20 5965686.62 635416.81 GYD-CT-CMS 5542.28 43.07 139.31 5075.91 5003.33 -954.34 1004.34 5965673.86 635428.18 GYD-CT-CMS 5567.28 42.81 139.35 5094.21 5021.63 -967.26 1015.44 5965661.15 635439.51 GYD-CT-CMS 5592.28 43.01 139.61 5112.52 5039.94 -980.20 1026.49 5965648.41 635450.80 GYD-CT-CMS 5617.28 42.80 139.71 5130.83 5058.25 -993.17 1037.51 5965635.64 635462.04 GYD-CT-CMS 5642.28 42.49 139.83 5149.22 5076.64 -1006.10 1048.45 5965622.91 635473.21 GYD-CT-CMS 5667.28 42.49 139.95 5167.65 5095.07 -1019.02 1059.33 5965610.19 635484.32 GYD-CT-CMS 5692.28 42.38 139.92 5186.10 5113.52 -1031.93 1070.19 5965597.48 635495.40 GYD-CT-CMS 5717.28 42.49 139.96 5204.56 5131.98 -1044.84 1081.04 5965584.76 635506.49 GYD-CT-CMS 5742.28 42.43 140.02 5223.00 5150.42 -1057.77 1091.89 5965572.04 635517.57 GYD-CT-CMS 5767.28 42.60 139.91 5241.43 5168.85 -1070.70 1102.76 5965559.30 635528.67 GYD-CT-CMS 5792.28 42.77 139.91 5259.80 5187.22 -1083.67 1113.68 5965546.53 635539.81 GYD-CT-CMS • ~ • Halhburton Company Survey Report Company: BP AmoCO Date: 4(8/2007 Time: 21:38:56 Page: d Field: Prudhoe Bay Co-ordinatMNP> Reference: Well: N-22, True North Site: PB N Pad Vertical (fVD) Reference N-22B 72.6 Well: N-22 Section (VS) Reference Well (O.OON,O.OOE,122.35Azi) Wcllpath: -- N-22B Survey Calculation Dlethod: Minimum Curvature Db: Oracle - - __ Survc~ - - __ - __ N1D Inc( Azim TVD Sys "1'VU ft deg deg ft ft 5817.28 42.70 139.95 5278.17 5205.59 5842.28 42.60 139.81 5296.55 5223.97 5867.28 42.41 139.81 5314.98 5242.40 5892.28 42.61 139.89 5333.41 5260.83 5917.28 42.76 139.83 5351.79 5279.21 5942.28 42.78 139.88 5370.14 5297.56 5967.28 42.88 140.03 5388.48 5315.90 5992.28 42.81 139.98 5406.81 5334.23 6017.28 42.75 139.88 5425.16 5352.58 6042.28 42.71 139.78 5443.52 5370.94 6067.28 42.68 139.80 5461.90 5389.32 6092.28 42.89 139.91 5480.24 5407.66 6117.28 42.96 139.95 5498.55 5425.97 6142.28 42.79 139.97 5516.87 5444.29 6167.28 42.80 140.00 5535.21 5462.63 6192.28 42.82 139.91 5553.55 5480.97 6217.28 42.82 140.16 5571.89 5499.31 6242.28 42.54 140.28 5590.27 5517.69 6267.28 42.63 140.38 5608.68 5536.10 6292.28 42.60 140.38 5627.08 5554.50 6317.28 42.44 140.46 5645.50 5572.92 6342.28 42.54 140.49 5663.94 5591.36 6367.28 42.33 140.57 5682.39 5609.81 6392.28 42.18 140.71 5700.89 5628.31 6417.28 42.21 140.71 5719.41 5646.83 6442.28 41.99 140.90 5737.96 5665.38 6467.28 42.04 140.99 5756.54 5683.96 6492.28 41.64 141.01 5775.16 5702.58 6517.28 41.19 141.10 5793.91 5721.33 6542.28 41.29 141.10 5812.71 5740.13 6567.28 41.13 141.29 5831.52 5758.94 6592.28 41.07 141.36 5850.36 5777.78 6617.28 40.94 141.45 5869.22 5796.64 6642.28 40.74 141.57 5888.14 5815.56 6667.28 40.64 141.50 5907.09 5834.51 6692.28 40.34 141.63 5926.11 5853.53 6717.28 40.30 141.94 5945.17 5872.59 6742.28 40.16 141.83 5964.25 5891.67 6767.28 39.85 141.37 5983.40 5910.82 6792.28 39.53 140.44 6002.64 5930.06 6817.28 39.06 138.37 6021.99 5949.41 6842.28 39.14 136.75 6041.39 5968.81 6867.28 39.30 134.96 6060.76 5988.18 6892.28 39.57 133.34 6080.07 6007.49 6917.28 39.83 132.67 6099.30 6026.72 6942.28 40.04 132.17 6118.47 6045.89 N/S - ft -1096.65 -1109.60 -1122.51 -1135.42 -1148.38 -1161.35 -1174.36 -1187.39 -1200.38 -1213.34 -1226.29 -1239.27 -1252.30 -1265.32 -1278.33 -1291.34 -1304.36 -1317.38 -1330.41 -1343.45 -1356.47 -1369.49 -1382.51 -1395.51 -1408.51 -1421.50 -1434.49 -1447.45 -1460.31 -1473.14 -1485.97 -1498.81 -1511.63 -1524.42 -1537.18 -1549.90 -1562.61 -1575.31 -1587.91 -1600.30 -1612.32 -1623.96 -1635.30 -1646.36 -1657.25 -1668.07 6967.28 40.17 131 .82 6137.59 6065.01 -1678.85 6992.28 39.98 131 .95 6156.72 6084.14 -1689.59 7017.28 39.78 131 .95 6175.91 6103.33 -1700.31 7042.28 39.51 131 .96 6195.16 6122.58 -1710.97 7067.28 39.28 132 .39 6214.48 6141.90 -1721.63 7092.28 39.26 132.29 6233.83 6161.25 -1732.28 F./VV _ N1apN ft ft 1124.60 5965533.75 1135.51 5965520.99 1146.41 5965508.29 1157.31 5965495.57 1168.23 5965482.81 1179.18 5965470.04 1190.11 5965457.22 1201.04 5965444.40 1211.97 5965431.60 1222.91 5965418.84 1233.86 5965406.09 1244.80 5965393.31 1255.76 5965380.48 1266.71 5965367.66 1277.63 5965354.85 1288.56 5965342.04 1299.47 5965329.22 1310.32 5965316.39 1321.12 5965303.56 1331.91 5965290.72 1342.68 5965277.89 1353.42 5965265.06 1364.14 5965252.24 1374.81 5965239.43 1385.44 5965226.63 1396.03 5965213.84 1406.57 5965201.03 1417.07 5965188.26 1427.46 5965175.59 1437.81 5965162.95 1448.14 5965150.31 1458.40 5965137.66 1468.64 5965125.03 1478.81 5965112.42 1488.95 5965099.84 1499.04 5965087.31 1509.05 5965074.78 1519.02 5965062.26 1529.00 5965049.85 1539.07 5965037.64 1549.37 5965025.80 1560.00 5965014.36 1571.01 5965003.22 1582.41 5964992.37 1594.09 5964981.69 1605.93 5964971.08 1617.90 5964960.52 1629.88 5964949.99 1641.81 5964939.49 1653.67 5964929.04 1665.43 5964918.60 1677.12 5964908.16 n4apE Tool ft ___ 635550.96 GYD-CT-CMS 635562.10 GYD-CT-CMS 635573.23 GYD-CT-CMS 635584.35 GYD-CT-CMS 635595.51 GYD-CT-CMS 635606.68 GYD-CT-CMS 635617.85 GYD-CT-CMS 635629.01 GYD-CT-CMS 635640.17 GYD-CT-CMS 635651.34 GYD-CT-CMS 635662.51 GYD-CT-CMS 635673.69 GYD-CT-CMS 635684.88 GYD-CT-CMS 635696.05 GYD-CT-CMS 635707.21 GYD-CT-CMS 635718.37 GYD-CT-CMS 635729.51 GYD-CT-CMS 635740.59 GYD-CT-CMS 635751.62 GYD-CT-CMS 635762.64 GYD-CT-CMS 635773.64 GYD-CT-CMS 635784.61 GYD-CT-CMS 635795.57 GYD-CT-CMS 635806.46 GYD-CT-CMS 635817.32 GYD-CT-CMS 635828.14 GYD-CT-CMS 635838.92 GYD-CT-CMS 635849.64 GYD-CT-CMS 635860.26 GYD-CT-CMS 635870.84 GYD-CT-CMS 635881.39 GYD-CT-CMS 635891.89 GYD-CT-CMS 635902.35 GYD-CT-CMS 635912.75 GYD-CT-CMS 635923.11 GYD-CT-CMS 635933.43 GYD-CT-CMS 635943.66 GYD-CT-CMS 635953.85 GYD-CT-CMS 635964.06 GYD-CT-CMS 635974.34 GYD-CT-CMS 635984.86 GYD-CT-CMS 635995.70 GYD-CT-CMS 636006.91 GYD-CT-CMS 636018.50 GYD-CT-CMS 636030.37 GYD-CT-CMS 636042.41 GYD-CT-CMS 636054.57 GYD-CT-CMS 636066.74 GYD-CT-CMS 636078.85 GYD-CT-CMS 636090.90 GYD-CT-CMS 636102.85 GYD-CT-CMS 636114.73 GYD-CT-CMS • Halliburton Company Survey Report Company: BP AmoCO Date: 4/8/2007 Time: 21:38:56 Pale: 5 Tield: Prudhoe Bay Co-~~rdinatetNEl Reference: Well: N-22, True North Site: PB N Pad Vertical (TVllI Reference: N-22B 72.6 ~i yy'ell: N-22 Section (~'S) Reference: Well (O.OON,O.OOE,122.35Azi) ~Vellpath: N-22B Survey Calculation method: Minimum Curvature Db: OraCle Survcv MD Incl Anm TVD Sys TVD N/5 F,/~V ]1IapN AI ~pE Tool ft deg deg ft ft ft ft ft ft 7117.28 38.98 132.38 6253.23 6180.65 -1742.91 1688.78 5964897.74 636126.58 GYD-CT-CMS 7142.28 38.81 132.46 6272.69 6200.11 -1753.50 1700.37 5964887.37 636138.35 GYD-CT-CMS 7167.28 38.64 132.67 6292.19 6219.61 -1764.07 1711.89 5964877.00 636150.06 GYD-CT-CMS 7192.28 38.25 132.93 6311.77 6239.19 -1774.64 1723.30 5964866.64 636161.65 GYD-CT-CMS 7217.28 38.09 132.99 6331.42 6258.84 -1785.16 1734.60 5964856.32 636173.14 GYD-CT-CMS 7240.00 37.80 133.12 6349.34 6276.76 -1794.70 1744.81 5964846.96 636183.52 MWD+IFR+MS 7326.09 38.88 137.13 6416.88 6344.30 -1832.54 1782.46 5964809.80 636221.84 MWD+IFR+MS 7417.86 37.04 141.58 6489.24 6416.66 -1875.32 1819.24 5964767.70 636259.37 MWD+lFR+MS 7512.33 35.90 146.33 6565.23 6492.65 -1920.67 1852.28 5964722.95 636293.22 MWD+IFR+MS 7605.33 35.31 151.12 6640.85 6568.27 -1966.91 1880.39 5964677.22 636322.15 MWD+IFR+MS 7697.73 34.75 155.97 6716.53 6643.95 -2014.35 1904.01 5964630.21 636346.62 MWD+IFR+MS 7791.33 36.16 151.16 6792.79 6720.21 -2062.92 1928.20 5964582.09 636371.67 MWD+IFR+MS 7884.68 35.48 152.09 6868.48 6795.90 -2110.98 1954.17 5964534.51 636398.49 MWD+IFR+MS 7978.16 37.26 153.75 6943.75 6871.17 -2160.34 1979.38 5964485.61 636424.58 MWD+IFR+MS 8071.30 38.39 153.79 7017.32 6944.74 -2211.58 2004.63 5964434.84 636450.74 MWD+IFR+MS 8164.49 37.95 153.53 7090.58 7018.00 -2263.19 2030.18 5964383.70 636477.21 MWD+IFR+MS 8257.49 37.69 155.73 7164.05 7091.47 -2314.71 2054.61 5964332.63 636502.56 MWD+IFR+MS 8351.31 37.37 155.84 7238.45 7165.87 -2366.83 2078.05 5964280.94 636526.93 MWD+IFR+MS 8445.89 37.00 155.95 7313.80 7241.22 -2419.01 2101.40 5964229.19 636551.20 MWD+IFR+MS 8538.23 36.94 155.73 7387.58 7315.00 -2469.68 2124.13 5964178.94 636574,83 MWD+IFR+MS 8631.79 36.69 155.46 7462.48 7389.90 -2520.73 2147.29 5964128.31 636598.91 MWD+IFR+MS 8725.92 36.17 156.33 7538.22 7465.64 -2571.76 2170.13 5964077.71 636622.64 MWD+IFR+MS 8818.46 35.58 156.11 7613.20 7540.62 -2621.38 2191.99 5964028.49 636645.39 MWD+IFR+MS 8912.05 34.75 153.76 7689.71 7617.13 -2670.20 2214.81 5963980.09 636669.08 MWD+IFR+MS 9004.85 34.28 154.22 7766.18 7693.60 -2717.46 2237.87 5963933.26 636692.98 MWD+IFR+MS 9097.79 35.43 152.00 7842.45 7769.87 -2764.82 2261.90 5963886.34 636717.86 MWD+IFR+MS 9191.73 34.73 152.50 7919.32 7846.74 -2812.60 2287.04 5963839.02 636743.85 MWD+IFR+MS 9284.68 35.77 152.18 7995.23 7922.65 -2860.11 2311.95 5963791.97 636769.60 MWD+IFR+MS 9378.90 34.73 152.12 8072.17 7999.59 -2908.19 2337.35 5963744.35 636795.85 MWD+IFR+MS 9471.62 36.17 152.86 8147.70 8075.12 -2955.89 2362.19 5963697.11 636821.53 MWD+IFR+MS 9566.56 36.75 152.66 8224.06 8151.48 -3006.05 2388.01 5963647.42 636848.25 MWD+IFR+MS 9658.87 36.23 152.30 8298.27 8225.69 -3054.73 2413.37 5963599.21 636874.48 MWD+IFR+MS 9754.44 37.03 153.29 8374.97 8302.39 -3105.44 2439.44 5963548.97 636901.45 MWD+IFR+MS 9846.42 36.26 153.30 8448.77 8376.19 -3154.49 2464.11 5963500.38 636926.99 MWD+IFR+MS 9866.84 36.03 153.48 8465.26 8392.68 -3165.26 2469.50 5963489.71 636932.58 MWD+IFR+MS 9944.02 36.02 143.33 8527.73 8455.15 -3203.80 2493.21 5963451.60 636956.97 MWD+IFR+MS 9975.50 36.47 133.66 8553.14 8480.56 -3217.70 2505.52 5963437.93 636969.52 MWD+IFR+MS 10006.55 36.16 127.48 8578.17 8505.59 -3229.65 2519.47 5963426.23 636983.68 MWD+IFR+MS 10037.83 35.43 120.97 8603.55 8530.97 -3239.93 2534.57 5963416.22 636998.97 MWD+IFR+MS 10069.47 34.95 119.57 8629.41 8556.83 -3249.12 2550.32 5963407.31 637014.87 MWD+IFR+MS 10100.09 34.26 118.22 8654.61 8582,03 -3257.53 2565.54 5963399.18 637030.24 MWD+IFR+MS 10131.39 36.21 121.54 8680.18 8607,60 -3266.53 2581.19 5963390.46 637046.05 MWD+IFR+MS 10162.57 36.76 124.77 8705.25 8632.67 -3276.67 2596.70 5963380.60 637061.74 MWD+IFR+MS 10193.51 37.45 125.21 8729.93 8657.35 -3287.37 2611.99 5963370.17 637077.22 MWD+IFR+MS 10224.30 39.35 123.96 8754.06 8681.48 -3298.23 2627.74 5963359.61 637093.15 MWD+IFR+MS 10255.10 41.97 123.90 8777.42 8704.84 -3309.43 2644.39 5963348.71 637110.00 MWD+IFR+MS 10288.26 45.79 122.65 8801.32 8728.74 -3322.03 2663.61 5963336.45 637129.44 MWD+IFR+MS 10316.84 48.52 121.91 8820.75 8748.17 -3333.21 2681.32 5963325.59 637147.35 MWD+IFR+MS 10348.47 52.37 121.76 8840.89 8768.31 -3346.07 2702.04 5963313.10 637168.29 MWD+IFR+MS 10378.61 56.83 123.09 8858.34 8785.76 -3359.25 2722.76 5963300.30 637189.25 MWD+IFR+MS 10409.99 61.03 123.88 8874.53 8801.95 -3374.08 2745.17 5963285.87 637211.92 MWD+IFR+MS 10441.46 63.99 122.58 8889.06 8816.48 -3389.37 2768.52 5963271.00 637235.54 MWD+IFR+MS 10472.33 66.57 123.32 8901.97 8829.39 -3404.62 2792.05 5963256.18 637259.33 MWD+IFR+MS • • ' Halliburton Company Survey Report Company: BP AmoCO llate: 4/8/2007 Time: 21:38:56 Pale: 6 Field: Prudhoe Bay Co-ordinatc(Nti) Reference: Well: N-22, True North Site: PB N Pad Vertical (T'VD) Reference N-22B 72.6 Well: N-22 Section fVS) Reference: Well (O.OON,O.OOE,122.35Azi) Wellpath: N-22B Survey Calculation D4ethod: Minimum Curvature Db: Oracle Sure e~ 111D lnd Azim '1'Vll Sys TVD N/S F./W AIapN 1t~I ipF Too ft deg deg ft ft ft ft ft ft 111111 10503.40 70.41 123.49 8913.36 8840.78 -3420.54 2816.18 5963240.70 637283.74 MWD+IFR+MS 10534.68 73.66 121.65 8923.01 8850.43 -3436.55 2841.25 5963225.14 637309.09 MWD+IFR+MS 10565.72 77.10 122.01 8930.84 8858.26 -3452.39 2866.77 5963209.76 637334.88 MWD+IFR+MS 10596.57 80.87 122.28 8936.73 8864.15 -3468.50 2892.40 5963194.12 637360.80 MWD+IFR+MS 10628.03 83.42 120.51 8941.03 8868.45 -3484.73 2919.00 5963178.37 637387.68 MWD+IFR+MS 10658.40 87.33 119.08 8943.48 8870.90 -3499.76 2945.26 5963163.80 637414.21 MWD+IFR+MS 10689.33 90.85 116.94 8943.97 8871.39 -3514.28 2972.56 5963149.77 637441.76 MWD+IFR+MS 10720.82 94.24 114.84 8942.57 8869.99 -3528.02 3000.86 5963136.55 637470.30 MWD+IFR+MS 10751.97 97.23 114.13 8939.46 8866.88 -3540.86 3029.06 5963124.21 637498.72 MWD+IFR+MS 10777.68 100.61 115.74 8935.47 8862.89 -3551.57 3052.09 5963113.92 637521.94 MWD+IFR+MS 10809.12 102.31 115.01 8929.23 8856.65 -3564.77 3079.93 5963101.22 637550.01 MWD+IFR+MS 10839.99 102.19 115.30 8922.68 8850.10 -3577.60 3107.23 5963088.89 637577.53 MWD+IFR+MS 10871.06 100.68 112.74 8916.52 8843.94 -3589.99 3135.05 5963077.00 637605.56 MWD+IFR+MS 10902.15 98.66 111.36 8911.30 8838.72 -3601.49 3163.45 5963066.00 637634.17 MWD+IFR+MS 10933.44 96.86 109.70 8907.07 8834.49 -3612.36 3192.48 5963055.65 637663.39 MWD+IFR+MS 10965.28 95.81 107.71 8903.56 8830.98 -3622.51 3222.46 5963046.05 637693.53 MWD+IFR+MS 10996.45 95.18 106.40 8900.57 8827.99 -3631.61 3252.12 5963037.48 637723.35 MWD+IFR+MS 11027.62 93.08 104.16 8898.33 8825.75 -3639.80 3282.11 5963029.83 637753.48 MWD+IFR+MS 11058.98 91.28 101.24 8897.13 8824.55 -3646.69 3312.67 5963023.49 637784.16 MWD+IFR+MS 11090.70 90.05 98.04 8896.77 8824.19 -3652.00 3343.94 5963018.74 637815.51 MWD+IFR+MS 11122.27 90.93 93.62 8896.50 8823.92 -3655.21 3375.33 5963016.10 637846.96 MWD+IFR+MS 11153.02 91.60 89.84 8895.82 8823.24 -3656.13 3406.06 5963015.72 637877.69 MWD+IFR+MS 11183.25 91.17 86.86 8895.09 8822.51 -3655.26 3436.26 5963017.13 637907.87 MWD+IFR+MS 11215.67 90.74 83.01 8894.55 8821.97 -3652.40 3468.54 5963020.57 637940.10 MWD+IFR+MS 11245.72 90.08 80.94 8894.33 8821.75 -3648.21 3498.30 5963025.29 637969.77 MWD+IFR+MS 11276.62 86.92 81.94 8895.14 8822.56 -3643.61 3528.84 5963030.44 638000.22 MWD+IFR+MS 11308.39 86.54 81.96 8896.95 8824.37 -3639.17 3560.24 5963035.44 638031.54 MWD+IFR+MS 11339.22 88.22 81.97 8898.36 8825.78 -3634.86 3590.74 5963040.29 638061.95 MWD+IFR+MS 11370.13 88.84 81.29 8899.15 8826.57 -3630.37 3621.31 5963045.33 638092.43 MWD+IFR+MS 11401.44 90.12 81.48 8899.44 8826.86 -3625.68 3652.26 5963050.58 638123.30 MWD+IFR+MS 11431.32 89.77 81.68 8899.47 8826.89 -3621.30 3681.82 5963055.48 638152.77 MWD+IFR+MS 11463.61 90.37 83.01 8899.43 8826.85 -3617.00 3713.82 5963060.35 638184.68 MWD+IFR+MS 11507.34 91.31 83.01 8898.79 8826.21 -3611.68 3757.22 5963066.45 638227.98 MWD+IFR+MS 11556.99 90.87 82.88 8897.84 8825.26 -3605.58 3806.49 5963073.43 638277.12 MWD+IFR+MS 11600.97 90.19 82.99 8897.43 8824.85 -3600.17 3850.13 5963079.62 638320.66 MWD+IFR+MS 11649.41 92.23 83.53 8896.41 8823.83 -3594.49 3898.22 5963086.16 638368.64 MWD+IFR+MS 11681.95 91.61 83.28 8895.32 8822.74 -3590.75 3930.53 5963090.47 638400.87 MWD+IFR+MS 11711.73 91.42 83.58 8894.53 8821.95 -3587.35 3960.10 5963094.41 638430.38 MWD+IFR+MS 11742.56 90.26 83.45 8894.08 8821.50 -3583.87 3990.73 5963098.44 638460.93 MWD+IFR+MS 11805.10 87.72 83.14 8895.18 8822.60 -3576.57 4052.83 5963106.85 638522.89 MWD+IFR+MS 11837.32 87.11 83.98 8896.64 8824.06 -3572.96 4084.81 5963111.03 638554.80 MWD+IFR+MS 11881.98 86.62 84.18 8899.08 8826.50 -3568.36 4129.17 5963116.42 638599.06 MWD+IFR+MS 11929.67 85.62 84.37 8902.31 8829.73 -3563.61 4176.51 5963122.01 638646.31 MWD+IFR+MS 12023.51 84.76 85.12 8910.18 8837.60 -3555.05 4269.63 5963132.24 638739.25 MWD+IFR+MS 12073.73 84.26 84.95 8914.98 8842.40 -3550.72 4319.43 5963137.46 638788.96 MWD+IFR+MS 12117.13 84.39 84.04 8919.27 8846.69 -3546.58 4362.42 5963142.37 638831.86 MWD+IFR+MS 12164.67 84.56 83.53 8923.85 8851.27 -3541.45 4409.46 5963148.33 638878.80 MWD+IFR+MS 12210.28 87.05 81.95 8927.19 8854.61 -3535.70 4454.58 5963154.89 638923.80 MWD+IFR+MS 12256.31 86.55 82.64 8929.75 8857.17 -3529.54 4500.12 5963161.87 638969.23 MWD+IFR+MS 12303.90 86.17 82.60 8932.78 8860.20 -3523.44 4547.22 5963168.81 639016.21 MWD+IFR+MS 12349.23 85.44 82.63 8936.09 8863.51 -3517.63 4592.05 5963175.42 639060.92 MWD+IFR+MS 12397.31 84.87 81.80 8940.15 8867.57 -3511.14 4639.52 5963182.76 639108.26 MWD+IFR+MS • • Hall~burton Com an P Y Survey Report Grmpany: BP Amoco ', Field: Prudhoe Bay ', Site: PB N Pad ~~~ Well: N-22 ~ '~I Wellpath: N-22B ~ Sun~ev bill lncl tlzim 'IVll Svs'1'VD llate: 4/8/2007 Timc: 21:38:56 Pair. 7 Co-ordinatelNE) Reference: Well: N-22, True North Vertical (TVD) Reference. N-22B 72.6 Section (VS) Reference: Well (O.OON,O.OOE,122.35Azi) Survev Calcnlatiou,llcthod: Minimum Curvature Db: Oracle N/S F,/W b1apN MapE Tool u uey uey n i i n n n i i 12428.93 81.14 80.56 8944.00 8871.42 -3506.33 4670.53 5963188.12 639139.18 MWD+IFR+MS 12460.69 78.38 80.88 8949.65 8877.07 -3501.29 4701.37 5963193.71 639169.92 MWD+IFR+MS 12491.22 76.37 81.92 8956.32 8883.74 -3496.84 4730.82 5963198.69 639199.29 MWD+IFR+MS 12522.72 78.01 82.17 8963.31 8890.73 -3492.59 4761.24 5963203.49 639229.62 MWD+IFR+MS 12553.56 79.40 81.66 8969.35 8896.77 -3488.33 4791.18 5963208.28 639259.48 MWD+IFR+MS 12585.18 81.16 81.15 8974.68 8902.10 -3483.67 4822.00 5963213.48 639290.21 MWD+IFR+MS 12616.33 83.57 81.36 8978.82 8906.24 -3478.98 4852.51 5963218.72 639320.63 MWD+IFR+MS 12645.66 86.31 79.98 8981.41 8908.83 -3474.24 4881.34 5963223.97 639349.36 MWD+IFR+MS 12677.96 88.71 80.73 8982.81 8910.23 -3468.84 4913.15 5963229.95 639381.07 MWD+IFR+MS 12709.36 91.98 82.18 8982.62 8910.04 -3464.17 4944.19 5963235.17 639412.02 MWD+IFR+MS 12741.03 94.27 82.08 8980.90 8908.32 -3459.84 4975.52 5963240.06 639443.26 MWD+IFR+MS 12772.76 96.75 82.17 8977.85 8905.27 -3455.52 5006.80 5963244.94 639474.46 MWD+IFR+MS 12801.03 98.63 81.64 8974.07 8901.49 -3451.57 5034.53 5963249.38 639502.12 MWD+IFR+MS 12832.34 98.51 81.83 8969.40 8896.82 -3447.12 5065.17 5963254.38 639532.67 MWD+IFR+MS 12863.72 97.57 81.37 8965.01 8892.43 -3442.58 5095.91 5963259.47 639563.32 MWD+iFR+MS 12894.52 95.39 82.32 8961.54 8888.96 -3438.24 5126.20 5963264.35 639593.52 MWD+IFR+MS 12925.73 93.04 82.36 8959.24 8886.66 -3434.09 5157.05 5963269.05 639624.29 MWD+IFR+MS 12957.10 91.87 83.70 8957.90 8885.32 -3430.29 5188.16 5963273.41 639655.32 MWD+IFR+MS 13005.24 90.80 84.55 8956.78 8884.20 -3425.37 5236.03 5963279.19 639703.09 MWD+IFR+MS 13049.38 90.56 84.57 8956.25 8883.67 -3421.18 5279.97 5963284.16 639746.95 MWD+IFR+MS 13108.53 90.25 84.54 8955.84 8883.26 -3415.57 5338.85 5963290.83 639805.71 MWD+IFR+MS 13155.00 90.25 84.54 8955.63 8883.05 -3411.15 5385.11 5963296.08 639851.88 PROJECTED to TD TREE = 4 118" Cameron Wellhead McEvoy _..~ ,.~ SSH , ACTUATOR = ? KB. ELEV =_ .80.3' BF. ELEV = 44.5' KOP = 3100' -Max Angle = 101 @ 10886' Datum MD = Datum TV D = A-22 B " .. 2216' HES 4-1/2" X NIPPLE, ID = 3.813" 1759' HES 9-5/8" ES CEMENTER, ID =8.619 " 1809' 9-518" CSG, 47#, L-80, BTC SCREW IN SUB, ID =8.618 " 2693' 13-318" CSG, 72#, L-80, ID = 12.347" 7078, BOT 7" X 9-5l8" ZXP LINER TOP PKR, FLEXLOK LINER HANGER W/ 14' TBS, ID = 6.33" 7240' Top of w indow GAS LIFT MANDRELS BOT 9-5/8" WHIPSTOCK 7227' HES CIBP 7230' - 5-1l2" Tubing Cut -9306` MD ~ 5-1/2" Otis XA Sliding Slv - 9629' MD ~ 5-1/2" CMT RETAINER W/ 9666' 100' CMT ON TOP 5-1/2" Tubing Punch -9666` MD Area included in cmt vol calcs PBTD 9981' 9-5/8" CSG, 47#, L-80, 10016' ID = 8.681" ST MD TV D DEV TYPE V LV LATCH PORT DATE 4 3412 3401 17 Shear DCR RKP 0 03110107 3 6378 U690 42 KBG- DMY RK 0 03110107 2 8209 7126 38 KBG- DMY BK 0 03110;07 1 9624 8271 36 KBG-' DMY BK 0 03110!07 9624' ~-~ HES 4-1/2" X NIPPLE, ID = 3.$13" ~ 9714' BOT 7" X 4-1/2" S-3 PERM PKR, ID =3.875 ~ 9738' HES 4-1/2" X NIPPLE, iD = 3.813" ~' 9758' HES 4-1/2" XN NIPPLE, ID = 3.725" 9766' BOT 7" X 4-1/2" ZXP LINER TOP PKR, FLIXLOK LINER HANGER W/ 14' TBS, ID = " ~ 9908' 7" CSG, 26#, L-80, BTGM, ID = ", BPF = r 13,067' PBTD ___ 4-1/2" CSG, 12.6#, L-80, IBT, ID = " 13,155' DATE REV BY COMMENTS DATE REV BY COMMENTS 03!28186 ORIGINAL COMPLETION 11!01/06 jgr N-22B Planned Well 04125198 SIDETRACK COMPLETION 03/10/07 RBN N-226 Actual 10/05/02 BM/TP WANERSAFETY NOTE 03117,"07 JDNUPAG DRt_G DRAFT(;ORRECTIONS 06/29!05 RWUPJC FISH-IBP & TOOLS 07/05!05 EZL/TLH WANERSFTY NOTE DELETED 05/31/06 CO/DTM PERF CORRECTION (6/13/04) PRUDHOE BAY UNIT WELL: N-22Bi PERMIT No: API No: 50-029-21349-02 SEC 8, T11 N, R13E BP Exploration (Alaska) _ ._ ;~-_ - - -a ~ _ ~ . -~ ~. ~ ~ _~ ~ . _- - ~~ ~, .v ALASSIA OIL A1~TD GAS COI~TSER~PA'TI011T COl-IlKISSIOIIT Greg Hobbs Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-66123 • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU N-22B BP Exploration (Alaska) Inc. Permit No: 206-161 Surface Location: 706' FSL, 531' FWL, SEC. 08, T11N, R13E, UM Bottomhole Location: 2708' FNL, 597' FWL, SEC. 16, T11N, R13E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this day of November, 2006 cc Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. R~~~~~~~ STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMI7SJN PERMIT TO DRILL 20 AAC 25.005 ~vU~V 2 0 2006 .Alaska ~++ i~ Gas Cons. ~Of11tTNSSIt)1~ dnrl~nrAnP. 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service / ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU N-22B ~/~ oG 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13194 TVD 9023 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 706' FSL 531' FWL SEC 08 T11 N R13E UM 7. Property Designation: ADL 028284 Pool , , . , , , Top of Productive Horizon: 2795' FNL, 3449' FWL, SEC. 17, T11 N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: January 5, 2007 ~ Total Depth: 2708' FNL, 597' FWL, SEC. 16, T11N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 25,975' 4b. Location of Well (State Base Plane Coordinates): Surface: x-634407 y-5966610 Zone-ASP4 10. KB Elevation (Height above GL): 73.38 feet 15. Distance to Nearest Well Within Pool: 665' 16. Deviated Wells: Kickoff Depth: 7400 feet Maximum Hole An le: 100 de rees 17. Maximum Anticipated Pressures in psig (see 20 0~5) Downhole: 3722 Surface: 880 18: Casin F ram: _ S ~ t" s To - Settin h - B om uantit f c.f. ors cks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data N/A 9-5/8" 47# L-80 TC-I I 2200' Surfac Surface 2200' 2199' 840 cu ft Class 'G' 8-1 /2" 7" 26# L-80 BTC-M 2514' 7276' 6304' 9790' 8500' 344 cu ft LiteCrete 193 cu ft lass 'G' -1/8" 4-1/2" 12.6# L- 0 IBT-M 3572' 9622' 8362' 131 4' 9 2 ' 07 cu CI ' T g. PRESE NT WELL CONDITION SUMMARY (To be completed for RedriU and Re-entry Operations) Total Depth MD (ft): 11807 Total Depth TVD (ft): gg5g Plugs (measured): None Effective Depth MD (ft): 11741 Effective Depth TVD (ft): 8966 Junk (measured): 9716 Casing r Length Size ement Volume MD ' ` D Conductor /Structural 110' 20" x d n r 110' 110' Surface 2693' 13-3/8" 3720 cu ft Permafrost'E' & PF 2693' 2693' Intermediate 10019' 9-5/8" 1890 cu ft Class'G' 230 cu ft Class'G' 10019' 492' Pro uction Liner 302' 7" 389 cu ft Class 'G' 9748' - 10050' 8294' - 8514' Liner 1941' 2-7/8" 104 cu ft Class'G' 9862' - 11803' 8377' - 8959' Perforation Depth MD (ft): 10682' - 11691' Perforation Depth TVD (ft): 8887' - 8972' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact John Rose, 564-5271 Printed Name Greg Hobbs Title Senior Drilling Engineer Prepared By Name/Number: Si nature Phone 564-4191 Date f! Terrie Hubble, 564-4628 Commission Use On! Permit To Drill Number: API Number: 50-029-21349-02-00 Permit A D e: proval See cover letter for ther re uiremen s Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: ter- n Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes ~No 1 `~S ~ fL~.01~7~C ~ ~-D O p ~ ~' ~ ` HZS Measures: Yes ^ No Directional Survey Req'd:~Yes ^ NoI '02ther: ,l L~' 7.0 ~'~'t 25.0 ~i ~ ~~,) L ~ ~ ~ Q-~ ~~"' ti....~'"~ ~ 01~ ~ ~'~' CQ ~ k-~ tc vim.. ~~ YO ~lc° d u,v S u G.w Date ~~~ ~©~ PPROVED BY THE COMMISSION COMMISSIONER Form 10-401 Revised 12/2005 ~ r~ ~ ~ ~, t + ~ ~""~~ ~.~ Submit In Duplicate r • • To: Winton Aubert, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: John Rose, ODE Date: November 16, 2006 Re: N-22B Sidetrack Permit to Drill by The N-22B rotary sidetrack is scheduled to be drilled by Nabors 2ES with an estimated spud date of ~O1/10/07. The sidetrack plan is to exit the N-22 "main" wellbore from the 9-5/8" casing at 7430' MD with an 8-1/2" BHA. The 8-1/2" hole will then be drilled to the top of the Sag River formation where a 7" drilling liner will be run and cemented at 9790' MD. A 6-1/8" production hole will then be drilled building to horizontal in the Ivishak Zone 2B then drilled horizontally for approximately 2487' to a final TD of 13,194' MD. A solid 4-1/2" production liner will be run and cemented from TD to 150' back into the 7" drilling liner. This well will be completed with a 4-1/2" chrome completion. Please note the follow drilling and completion summary as provided below. N-22B Wellplan Summary (11/16/06) Horizontal Well Sidetrack Tar et Well N-22B (This well will be a g Zone 2B/2C Type zone 2 Producer prior Objective to conversion to a Zone4 in'ector AFE Number: PBD4P2559 API Number: 50-029-21349-02 Surface Northin Eastin Offsets TRS Location 5966610 634407 706' FSL / 531' FWL 11 N, 13 E, Sec 8 Target Northin Eastin Offsets TRS Location 5963163 637399 2485' FSL/1831' FEL 11 N, 13 E, Sec 17 Bottom Northin Eastin Offsets TRS Location 5963294 639824 2571' FSL/597' FWL 11 N, 13 E, Sec 16 Planned KOP: 7400' and Planned S ud: 01/05/07 Ri Nabors ES ,r Planned Lateral TD: 13,194' and Planned Lateral TVD: 9020\3' tvd G L: 30.28' RTE: 73.38' /~ N-22B Sidetrack Page 1 Directional Program A roved Well Ian: W P03 Exit oint: 7400' and / 6483' tvd Maximum Hole Inclination: Original well builds to --36° down to the 7400' MD KOP with the sidetracked well building to 101° at 10,886' MD in the planned 6-1/8" roduction horizontal with the hole an le at the final well TD bein ~88°. Survey Program: Gyro orientation will be required for the initial kick-off. Standard MW D+IIFR+MS Nearest Well: Well H-25, with acenter-to-center distance of 665' at 12,261' md. Nearest Property Line 25,975' Logging Program Hole Section: Required Sensors /Service Pre-Ri Work: Pre-rig GR for correlation. 9-5/8" Cased Hole: USIT to in to determine cut oint. 8-1/2" Intermediate Hole: MWD DIR/GR/RES/PWD throughout the interval all in real-time mode. 7" Cased Hole: USIT to in to confirm cement bond ualit . 6-1/8" Production Hole: DIR/GR/RES/DEN/NEU throughout the interval all in real-time mode. Neutron and Density tools will be picked up on the second run and a MAD performed over the build section BEFORE drilling the lateral. Two sample catchers will be re uired er wellsite eolo ist. 6-1/8" O en Hole: None tanned. 4-1/2" Cased Hoie: None tanned Mud Program Fresh water LSND Hole Secti on / o eration: 8-1/2" Intermediate Hole Flowline Depth (ft) Densit Funnel PV YP z API FL PH Chlorides MBT y (ppg) Vis (cP) (Ib/100ft ) (ml/30min) (mg/I) sec/ t 7400' MD window 9.0 50 - 60 15 - 22 30 - 40 < 6.0 9.0 - 9.5 <600 <20 millin 7400' MD - To HRZ g 0;9.3 42 - 48 12 - 18 22 - 28 < 6.0 9.0 - 9.5 <600 <20 Top HRZ - 10 9 42 - 52 18 - 25 22 - 28 < 8.0 cc's 9 0 - 9 5 <600 <20 9790' MD . f/200° HTHP , . Hole Section /operation: 6-1/8" Production Interval Type Density (ppg) PV YP LSRV API FL pH FloPro SF 8.4-8.5 8 - 15 24 - 30 > 20,000 7 - 9 9.0 - 9.5 Casing /Tubing Program Hole Casing/Tubing Wt. Grade f Connection Length Top Bottom Size Size ~ and / tvd and / tvd 13-3/8" 9-5/8" 40# L-80 TC-II 2200' Surface 2200/2199' Casin 8.5" 7" 26.# L-80 BTC-M 2514' 7276'/6304' 9790'/8500' 9-5/8 Casing (Coat agent 26# L-80 TC-II 4594' 2689'/2688' 7283'/6310' Scab Liner 6-1 /8" 4-1 /2" 12.6# L-80 I BT-M 3572' 9622'/8362' 13,194'/9023' Tubin 4-1/2" 12.6# 13Cr VamTo 9493' Surface 9493'/8249' N-22B Sidetrack Page 2 • • Cementing Program Casin Strin 9-5/8", 47#, L-80, TC-II, Tie-Back Casin Slurry Design Basis: Lead slurry: None Planned. Tail slurry: 2200' of 72#, 13-3/8" Casing x 47#, 9-5/8" annulus with 10% excess. Pre-Flush TBD Fl id S /V l S acer TBD u s equence o ume: Lead Slur None tanned Tail Slur 150 bbls / 840 ft 725 Class `G', 15.8 .16 /sk. BHST: 80° -- BHCT: 80° Casin Strin 7", 26#, L-80, BTC-M Intermediate Liner Slurry Design Basis: Lead slurry: Tail slurry: 1390' of 8-1/2" x 7" annulus with 40% excess, plus 150' of 9-5/8" X 7" liner lap, plus 200' of 9-5/8" X 4" drill pipe annulus. Tail slurry: 1000' of 8-1/2" x 7" annulus with 40% excess, plus 80' of 7", 26# shoe track. Pre-Flush TBD Fl id S /V l S acer TBD u s equence o ume: Lead Slur 61 bbl / 344 ft 1 , s Crete, 12.0 t- k. Tail Slur 34 bbl / 193 ft / 66 s Class `G', 15.8 ; 1.1 t /sk. BHST: 185° -° BHCT: 120° Casin Strin 4-1/2", 11.6#, L-80, LTC solid production liner Slurry Design Basis: Lead slurry: none planned Tail slurry: 3404' of 4-1/2" X 6-1/8" annulus with 40% excess, plus 80' of 4- 1/2", 11.6# shoe track, plus 150' of 7" X 4-1/2" liner lap, plus 200' of 7" X 4" drill i e annulus. Pre-Flush TBD Fl ids S /V l S acer TBD u equence o ume: Lead Slur None tanned Tail Slur 90 bbl / 507 ft / 37~sx Class `G', 15.8 .17r t /sk. BHST: 192° BHCT: 136° Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 9-5/8" Tie-Back Prior to Drill-Out ES Cementer Casing Test 30 min recorded 4000 psi surface 9-5/8" Casing Prior to Mill Window f/Whi stock De arture Casing Test 30 min recorded 4000 psi surface 9-5/8" Window 20' be and mid-window FIT 11.9 EMW 7" Liner to Surface Landing collar to surface Casing Test 30 min recorded 4000 psi surface 7" Shoe 20' be and shoe FIT 10.1 EMW 4-1/2" Liner Landing collar to surface Casing Test 30 min recorded 4000 psi surface N-22B Sidetrack Page 3 Well Control Well control equipment consisting of 5,000psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8'h" intermediate interval Maximum antici ated BHP: 3722 psi at 8420' sstvd. Maximum surface ressure: 2880 pSl (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) Calculated kick tolerance: Infinite with 10. EMW FIT FIT TO 11.9 PPG EMW Planned BOPE test pressure: 250psi low / si high - 7 day test cycle until a window is milled in 9-5/8" casin . Once a window is milled a 14 day test cycle can commence. -3~fl' Gi~ ~-ooo BOPE configuration for 7" Variable Bore Rams will remain installed, rather than C/O to 7" pipe rams Liner while running the 7" liner. In the event of a kick the rig will follow the current, best practice, making up a safety valve crossed over to casing thread, then changing elevators and picking up a joint of drill pipe. This confi uration rovides two sets of em to able rams, rather than one. Planned BOPE function test BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, exce t when the routine use of BOP equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this re uest will not com romise the inte rit of the BOP a ui ment. Well Interval: 6-1/8" production liner section Maximum antici ated BHP: 3,140psi at 8,800' sstvd. Maximum surface ressure: 2,260 Si (based upon BHP and a full column of gas from TD C~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 8.4 ,EMW FIT FIT to 10.1 EMW Planned BOPE test ressure: t~Gk' 250 ~Oo y~ Planned com letion fluid: 8.4pp seawater / 7.Opp Diesel Planned BOPE test ressure:. -14 day test c cle. Planned BOPE function test, BPXA reque a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this re uest will not com romise the inte rit of the BOP a ui ment. Disposal Annular In'ection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 ~ for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. -~:- N-226 Sidetrack Page 4 Geologic Prognosis (7) Formation Tops(TVDss) and Estimated Pore Pressures Est. Formation Tnar Uncertain Commercial Hydrocarbon Beartn Est. Pare Press. E.rt. Pore Pres.r. Formation (TVDss) (leer) (Yes/IVo) (Psi) (ppg EMW) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation to are re aired from surface to TD for all new wells Base Permafrost NA SVS NA SV4 NA SV3 NA SV2 NA SV1 NA UG4 NA UG3 NA UG2 NA UG1 NA WS2 NA WSi NA CM3 NA CM2 NA Kickoff 6403 CM1 6500* 10 THRZ 6777* 20 LCU/BHRZ 7045* 20 LCUlro Kin ak 7194* 20 LCU/TJG 7194* TJF 7488* 20 TJE 7689* 20 TJD 7902* 20 TJC 8163* 20 TJB 8263* 20 Sa River 8420 20 Yes Shublik 8460 20 Yes TSAD / TZ48 8545 20 Yes 3140 si @ 8800 TZ4A/42N 8680 20 Ves TCGL / TZ3 8734 20 Yes PGOC 8734 20 Yes POWC 8783 BCGL 8821 Yes 25N / T2B 8906 30 No MHO/HOT 8940 below TD Yes 22N 8965 below TD 20 No TZ18 9055 below TD 30 No TD Criteria TD Criteria 600' perforations + 100' rathole OR end of polygon horizontal): N-22B Sidetrack Page 5 • Fault Prognosis • (8) ault Details Formation Where Encounter Fault MD Intersect Intersect Est. Throw Direction Uncertainty Fault #L NA The N-22B won't intersect any mapped faults. Fault #1 is a small (-10 ft) down to the south fault which trends east west, parallel to and approximately 250 north (at Zone 2) of the planned trajectory. The most significant lost circulation event in the area was -4000 ft west at N-11 A which lost 3340 bbl into Z-4, in a heavily faulted area. Other significant LC problems in the area are below: WELL # Rig/Coil Barrels MD TVDSS Zone X LOC Y LOC N-Il rig 500 11605 8891 Sag River 628516 5966754 N-l l rig 380 12420 9556 Zone 2 628103 5966976 reaming N-IIA rig 3340 10167 8689 Zone4 634256 5963163 N-llB coil 350 10670 8711 Zone4 633829 5963639 Fault N-IIBPBt coil l00? 9500 8172 NA 634331 5963577 N-llBP6l coil 1200 10029 8563 Shublik 634229 5963252 Fault N-116PB2 250 10250 8689 Zone4 634055 5963276 Fault U-15B coil 1200 10200 8854 Zone 4B 633549 5962001 Fault U-156 coil 360 10961 8789 Zone 4B 634257 5962151 Fault U-ISBPBI coil 1500 10220 8827 Zone 46 633570 5961987 Fautt Fault Coordinates for Ma in X Y TVD Fault #1 First Point 638,690 5,963,570 at Zone 2 Fault #1 Second Point 639,405 5,963,560 at Zone 2 N-22B Planned Operations Summary (11/16/06) Pre-Rig Operations: 1. PPPOT-T and PPPOT-IC. Function all LDS, repair or replace as necessary. 2. MIRU pumping & E-line services to confirm injectivity capability/rate into the current coil sidetrack (top 2-7/8" liner 9862' MD) as follows; a. Drift the 5-1/2" x 4-1/2" tubing down to the top of the fill/junk in the 4-1/2" liner at 9700' MD. b. Run LDL as follows; i. Run static temp pass to top of fish -9700' MD (100 fpm) ii. Locate spinner log at top of fish~9700' iii. Establish injectivity down IA and log up to confirm "flow path" of the injection fluid (record stop counts) iv. While logging up, note temp log data to confirm possible cretaceous leaks in the 9- 5/8" casing 3. Assuming confirmed injectivity into 2-7/8" liner in Step #1, RU service coil to pump P&A cement as follows; a. RIH with a 5-1/2" retainer on the service coil and set in the middle of the last full joint of 5-1/2" tubing at 9666' MD. b. Establish injectivity and squeeze ~14 bbls of 15.8 ppg cement through the retainer (cased hole volume from PBTD at 11,741' MD to 9700' MD). c. Un-sting from the cement retainer and dump ~2.5 bbls of 15.8 ppg cement (equal to 100' of cement) on top of the retainer. 4. Make GR/JB run and tag the top cement at 9566' MD. 5. Pressure test the cement plug to 2050 psi to confirm integrity (.25 psi per vertical foot to top cement plu9)• 6. Run E-line gyro to the top of the cement plug to clear up some anti-collision issues with the directional plan for the planned sidetrack. 7. Jet cut tbg in the middle of the full joint of 5-1/2" tbg above the top of the cement plug at 9255 MD (this is also the first full joint of 5-1/2" tubing above the sliding sleeve which is located at 9630' MD). 8. Fluid pack the well with seawater and bleed OA, IA and tubing pressures to zero. 9. CMIT the T x IA to 3500 psi. MIT the OA to 2000 psi. 10. Freeze protect the IA and tubing with diesel to ~ 2200' md. 11. Bleed all pressures to zero. Set BPV. Secure well. 12. Verify that the well house is removed and that the flow lines are disconnected. If necessary, level the pad. N-22B Sidetrack Page 6 Rig Operations: 1. MIRU Nabors 2ES. 2. Pull BPV. Circulate out freeze protection and displace well to SW. 3. Monitor OA, IA and T for pressure. Verify well is dead. 4. Set TWC and pressure test T x IA to 600 psi to confirm barriers (LOT = 12.5 ppg at 2715' TVD). 5. Nipple down tree. Nipple up and test BOP. Pull TWC. 6. RU spooling unit for dual encapsulated control lines. Pull 5-'/z" tubing, control line and control line bands from pre-rig cut at 9255' MD. 7. MU an 8-1/2" clean-out assembly to include a 9-5/8" casing scrapper and clean-out the well to top of the tubing stub at 9255' MD. 8. MIRU E-line. Make CCVGR/JB and USIT logging runs from tubing stub to surface looking for 9-5/8' casing leaks below the surface shoe at 2693' MD and evidence of TOC behind 9-5/8" casing. (NOTE TOC estimated to be 2200' based upon the down-squeeze Arctic Pack procedure which was performed on the well as it was originally cased and cemented.) 9. With E-line, make string-shot across the first connection below the planned cut point in the 9-5/8' casing (as determined in Step #8) to improve the potential for a clean back-off at the connection. 10. MU Baker 9 5/e" mechanical cutter and RIH and make initial cut above down squeeze cement a: determined using USIT log data in step #8 (TOC should be -2200' MD). Circulate through cut tc confirm cut. (NOTE: The cut point should be ~16' above the 2"d 9-5/8" collar which is above the TOC as indicated in Step #8.) 11. Circulate through cut with surfactant wash per MI to clean annulus. POOH. 12. Remove W B, C/O to 9-5/s" rams and test ram cavity. 13. MU spear and pull 9 5/a" csg from the cut point and laying it down. 14. Make clean out/ wash over run with to 9-5/e" csg stub (may be 2 separate runs per BOT). 15. MU Baker 9-5/8" back-off assembly and RIH and back-off at is casing collar below the 9-5/8" cur point. 16. PU 9-%8" Baker screw-in sub w/ES cementer on 47# 9-5/8" casing &TIH and screw in to csg stub. 17. RU Schlumberger cement and cement OA to surface using ES Cementer (lead cement job 1 annular volume of 9.8 ppg brine). 18. ASAP after cementing, PU BOPE, split stack, install casing slips (w/100K wt on slips), RILDS, make casing cut w/Wachs cutter. 19. NU BOPE to include changing to 3-1/2" x 6" variable rams. Install new 9-5/8" packoff and test. Tesi BOPE to 4000 psi after cement reaches 1000 psi compressive strength (do not test against casing). Install WB. 20. PU 8-1/2" clean-out BHA on 4" drill pipe and clean-out the 9-5/8" casing to the top of the baffle adapter in the "new" 9-5/8" casing and test well to 4000 psi. (NOTE: Drill-out the ES cementer per HES procedure.) 21. With the well successfully tested, continue the 9-5/8" clea - ut down to 8000' MD. 22. RIH w/9-5/8" CIBP, set at 7430' MD and test well to 0 si. (NOTE: If the 9-5/8" casing does not test at this point, the "weak" casing will be identified "fixed" by extending the planned 7" liner lap OR by running a 7" scab liner later in the drilling program.) ~ 23. P 9 5/8" whipstock and TIH to CIBP at 7430'. j ~' 24. Displace to 10.5 ppg fresh water LSND milling fluid (per MI). 25. Shear off of whipstock, mill window and 20' of new formation and perform FIT to 11.9 ppg. .~ 26. POOH and LD milling assembly. 27. MU the 8-'/z" drilling assembly w/DIR/GR/RES/PW D. 28. Drill 8-'/2" intermediate interval as per directional plan to casing point at Top Sag River to an estimated depth of 9790' MD. 29. Run and cement the 7" BTC-M 26# liner to 9790' MD (with 150' lap). (NOTE: Any 9-5/8" casin 4 integrity problem as identified in Step #22 will be corrected at this time with additional 7" liner lap OR ~, scab 7" liner.) 30. MU 6-%8" BHA with DIR/GR/RES/NEU/DEN/Vibration and RIH to shoe tract. 31. Drill shoe tract. Swap over to 8.5 ppg Flo-Pro SF mud and drill 20' of new formation. Perform FIT t ~ 10.1 ppg. ^~ 32. Drill the 6-%8' production interval as per directional plan to and estimated TD of 13,194' MD (2 BHA's). 33. Run and cement a 4-'/z", 12.6#, L-80 IBT-M liner. Ensure that there is 150' of overlap from the 7' °'' shoe. Set liner han er nd liner top packer. Displace well to clean seawater above the liner top. 34. MIRU SWS. Run SI CBL in both the 4-1/2" & 7" liner to confirm cement quality. 35. RU Schlumberger RIH w/ 600' 2-%" 2906 Powerjet guns set C~4 SPF. Tag PBTD. l- 36. Put guns on depth and fire. POOH and verify all shots fired. 37. Run 4-~h", 12.6#, 13Cr-80 completion w/ Baker S-3 permanent packer. Space out and land tbg. a ~ o ,/ N-22B Sidetrack Page 7 38. Install TWC and test to 1,000 psi. ~~. 39. ND ROPE and NU adapter flange and tree. Test to 5,000 psi. 40. Pull TWC. 41. Reverse circulate corrosion inhibitor and seawater. Reverse in sufficient diesel for freeze protection to 2200' MD and allow to u-tube. 42. Drop ball and rod and set packer. 43. Test tubing and annulus to 4,000 psi for 30 minutes each, record tests. 44. Set BPV and secure the well. /~ 45. RDMO. Post-Rig Work: 1. Install well house and flow lines. 2. MIRU slickline. Pull the ball and rod / RHC plug from `X' nipple below the packer. 3. Install GLM valves as required. N-22B Sidetrack Page 8 • • N-Pad Potential Drilling Hazards (Post on Rig) • Pre-job HAZOP's and Safety meetings are recommended when there is a clear change in workscope. If at any time things don't feel or look right, STOP the job and discuss the situation before making the next move. • Flash Points o Dead Crude= <40degF o Methanol (neat)= 52degF o Diesel=100degF • Hydrogen Sulfide o N-Pad is not designated as an H2S pad, however, Standard ~° Operating rP ocedures for H2S precautions should still be followed at all times. o Closest SHL Well: N-09 - No Data o Max H2S reading: N-15 (01/09/00) & N-26 (02/01/02) w/100 ppm • Bottom Ho Pressure 0 14 psi (6.9 ppg) @ 8800'ss o e 8.4 ppg drilling fluid will provide a 704 psi static overbalance in the reservoir. • Maximum anticipated wellhead pressure: o psi w/ full column of gas • Potentia~~or loss circulation o Low • Faults - N-22B will not intersect any mapped faults • Close Approaches o H-15 - 1091' ctr - ctr ~ 11,175' M D o H-05 - 757' ctr - ctr 12,913' MD o H-25 - 665' ctr - ctr 12,261' MD N-22B Sidetrack Page 9 TREE = 6" MCEV OY WELLHEAD = MCEVOY ACTUATOR = _? KB. ELEV..- 80.3' BF. ELEV = 44.5' KOP = 3100' Max Angle = 108 @ 11517' Datum MD = 10670' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" Y NOTES: 70° @ 10994' & 90° @ 11088' N -22A 2107' 5-1/2" OTIS SSSV LAND. NIP, ID = 4.562" GAS LIFT MANDRELS Minimum ID = 2.441" @ 9862' TOP OF 2-7/8" LINER 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~ 9712' TOP OF 4-1 /2" TBG 9712' TOP OF 7" LNR 974$' TOP OF 2-7/8" LNR 9$62' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I~ 9909' 9-5/8" CSG, 47#, L-80, ID = 8.681" I~ 10016' PERFORATION SUMMARY REF LOG: SWS-MTNL ON 04/11/98 A NGLE AT TOP PERF: 53 @ 10682 Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10682 - 10692 O 07/30/01 2-1/8" 4 11626 - 11649 O 04/25/98 2-1/8" 4 11667 - 11691 O 04/25/98 PBTD 9981' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 10970' ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3941 3807 29 OTIS RA 5 6492 5703 42 OTIS RA 4 7792 6722 35 OTIS RA 3 8654 7411 39 OTIS RA 2 9109 7756 43 OTIS RA 1 9266 7870 44 OTIS RA 9~ 629' I~ 5-1/2" OTIS XA SLIDING SLV, ID = 4.562" 9697' BKR PBR 9712' 9-5/8" X 5-1/2" BKR PKR 9712' 5-1/2" X 4-1/2" XO 9716' FISH-IBP & TOOLS (6/29/05) 9857' 7" X 4-112" BKR SAB PKR, ID = 3.875" 9862' DEPLOYMENT SUB 9907' 4-1/2" MILLED OTIS XN NIP, ID = 3.80" 9909' 4-1/2" TUBING TAIL WLEG, ID = 3.958" ELMD TT NOT LOGGED MILLOUT WINDOW 10050' 11741' I~ FISH - 6" X 2" CHKS/ 2.11" X 7" NOZZLE ~~ I~ 11741' 2-7/8" LNR, 6.16#, L-80, .00579 bpf, ID = 2.441" I~ 11803' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/28/86 ORIGINAL COMPLETION 04/25/98 SIDETRACKCOMPLETION 10/05/02 BMITP WAVER SAFETY NOTE 06/29/05 RWUPJC FISH-IBP & TOOLS 07/05/05 EZL/TLH WAVERSFTY NOTE DELETED 05/31/06 CO/DTM PERF CORRECTION (6/13/04) PRUDHOE BAY UNfI- WELL: N-22A PERMIT No: 1980300 API No: 50-029-21349-01 SEC 8, T11 N, R13E BP 6cploration (Alaska) TREE = 6" MCEV OY Wellhead~= McEvo ACTUATOR.- SSH KB. ELEV = 80.3' BF. ELEV - 44.5' KOP = 3100' Max Angle = 101 @ 10886' Datum MD Datum TV D - N-22~PROPOSED ~^~T~~ 2200' -2154' HES 4-1/2" X NIPPLE, ID = 3.813" HES 9-5/8" ES CEMENTER, ID = " -2200' 9-5/8" CSG, 47#, L-80, BTC SCREW IN SUB, ID = " 2693' 13-3/8" CSG, 72#, L-80, ID = 12.347" The need for an extended 7" liner lap or TBD ~"scab liner to address 9-5/8" casing concerns w ill be considered. 7280, BOT 7" X 4-1/2" ZXP LINER TOP PKR, FLEXLOK LINER HANGER W/ 14' TBS, ID = " 7400' KICK OFF POINT GAS LIFT MANDRELS BOT 9-5/8" WHIPSTOCK 7430' - HES CIBP 7430' - 5-1/2" Tubing Cut - 9255' MD _ 5-1/2" Otis XA Sliding Slv - 9629` MDR 5-1/2" CMT RETAINER W/ 100' CMT ON TOP 9666' x PBTD 9981' 9-5/8" CSG, 47#, L-80, 10016' ID = 8.681" ~A110N Sl1vM4FN I~ LOG SV115-MR~L CN 04/11/98 AN3EATTOPFB~F 53@10682 Nxe: Fifer to Roductan CB far historical perf data SIZF I SFF I Y~IfffZVAL I Cor>/ScR I D41E ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 5 TBD DMY 4 TBD DMY 3 TBD DMY 2 TBD DMY 1 TBD Shea -9405' HES 4-1/2" X NIPPLE, ID = 3.813" -9426' I-i BOT 7" X 4-1/2" S-3 PERM PKR, ID = " ~" -9451' HES 4-1/2" X NIPPLE, ID = 3.813" ~' -9472' HES 4-1/2" X NIPPLE, ID = 3.813" ^9622' BOT 7" X 4-1/2" ZXP LINER TOP PKR, FLEXLOK LINER HANGER W/ 14' TBS, ID = " ~ 9790' 7" CSG, 26#, L-80, BTGM, ID = ", BPF = DATE REV BY COMMENTS DATE REV BY COMMENTS 03/28/86 ORIGINAL COMPLETION 11/01/06 jgr N-22B Planned Well 04/25/98 SIDETFtACKCOMPLETION 10/05/02 BMITP WAVER SAFETY NOTE 06/29/05 RWL/PJC FISH-IBP 8~ TOOLS 07/05/05 EZL/TLH WANER SFTY NOTE DELETED 05/31/06 CO/DTM PERF CORRECTION (6/13/04) 13108' PBTD 4-1/2" CSG, 12.6#, L-80, IBT, ID = " 13194' PRUDHOE BAY UNff WELL: N-226i PERMfT No: API No: 50-029-21349-02 SEC 8, T11 N, R13E BP 6cploration (Alaska) • • ~$ ~ y nv p F F F F ' > F ' S & m m m m N r I, i ^+ I ~ o y ri F z z z 2 I ~' - ,~ ~ ~ ' I' y .. .. ~ <O~-ONOO ~00NV~~0-- PM-rv~rr-PCOrI V~NP ? 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N ' ~ ' ~ N O-NMRVi -r r+T~n .or mP------ • Sperry-Sun BP Planning Report Company: BP Amoco Date: 7/10/2006 Time: 16:32:56 Page: I Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: N-22, True North Site: PB N .Pad Vertical (TVD) Reference: 33:22 5/27/1985 00:00 80.3 Well:. N-22 Section (VS) Reference: Welt (O:OONO.OOE,122.50Azi) Wellpath: Plan N-228 Survey Catcula6on Method: Minimum Curvature Db: Oracle Plan: N-226 wp03 Date Composed: 5/2/2006 Version: 28 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well CenVe Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB N Pad TR-11-13 UNITED STATES :North S lope Site Position: Northing: 5965420.89 ft Latitude: 70 18 48.671 N From: Map Easting: 633404.63 ft Longitude: 148 55 7.726 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.02 deg Well: N-22 Slot Name: 22 N-22 Well Position: +N/-S 1171.21 ft Northing: 5966610.00 ft Latitude: 70 19 0.189 N +E/-W 1023.42 ft Easting : 634407.00 ft Longitude: 148 54 37.866 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 9790.30 8500.30 7.000 8.500 7" 13194.00 9023.30 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 8341.58 7274.30 LCU/Top Kingak 0.00 0.00 8341.58 7274.30 LCU/TJG 0.00 0.00 8688.99 7568.30 TJF 0.00 0.00 8926.50 7769.30 TJE 0.00 0.00 9178.20 7982.30 TJD 0.00 0.00 9486.61 8243.30 TJC 0.00 0.00 9604.78 8343.30 TJ B 0.00 0.00 9790.30 8500.30 Sag River 0.00 0.00 9838.00 8540.30 Shublik 0.00 0.00 9951.46 8625.30 TSAD / TZ46 0.00 0.00 10214.52 8760.30 TZ4A/42N 0.00 0.00 10328.90 8814.30 TCGL / TZ3 0.00 0.00 10328.90 8814.30 PGOC 0.00 0.00 10432.69 8863.30 POWC 0.00 0.00 10513.18 8901.30 BCGL 0.00 0.00 12317.76 8986.30 25N / T26 0.00 0.00 13105.60 9020.30 MHO/HOT 0.00 0.00 0.00 22N 0.00 0.00 0.00 TZ1 B 0.00 0.00 Targets Map Map ~.-- Latitude --> <- Longitude --~ Name. Description: TVD +N/-S +E/-W Northing Easting , Deg Min Sec lleg Min Sec I)ip. Dir. ft ft ft ft ft N-226 T2 8900.30 -3650.00 3370.00 5963021.20 637841.53 70 18 24.284 N 148 52 59.588 W N-22B T1 8955.30 -3500.00 2930.00 5963163.29 637398.95 70 18 25.761 N 148 53 12.418 W N-22B T3 8997.30 -3498.00 4621.91 5963195.58 639090.42 70 18 25.773 N 148 52 23.077 W N-226 T4 9023.30 -3413.00 5357.07 5963293.72 639823. 88 70 18 26.604 N 148 52 1.635 W • Sperry-Sun BP Planning Report • Company: BP Amoco Date: 7/10/2006 Tune: 16:32;56 Page: 2 F1eld: Prudhoe Bay Co-ordinate(NE} Reference: Well: N-22, True North Site: PB N Pad Vertical (TVD) Reference: 33 :22 5/27/1985 00 :00 80}3 WeO: N-22 Section (VS) Reference: Well (O.OON,O.OOE,122.50Azi) WeRpatho Plan N-22B Survey Calculation Method: Minimum Curvature Dh: Oracle Targets Map Map <--- Latitude -> <- Longitude -> Name Description ` ' TVD +N/-S +E/-W Northing:.. Ea sting Deg. Min See Deg Min Sec Dip. Dir. ft ft ft ft ft Plan Section Information MD Incl Aim TVD +N/-S +E/-W DLS Build Turn TFO 'Target ft deg deg > ft ft ft deg/100ft deg/100ft deg/100ft deg 7400.00 36.12 134.90 6483.19 -1864.88 1792.67 0.00 0.00 0.00 0.00 7420.00 36.40 138.93 6499.32 -1873.51 1800.74 12.00 1.39 20.16 85.00 7690.00 32.19 156.66 6722.90 -2000.32 1882.10 4.00 -1.56 6.57 120.00 9810.00 32.19 156.66 8516.97 -3037.41 2329.49 0.00 0.00 0.00 0.00 10057.84 61.83 124.43 8686.33 -3164.27 2450.01 15.00 11.96 -13.01 -51.10 10531.37 61.83 124.43 8909.89 -3400.25 2794.33 0.00 0.00 0.00 0.00 10707.33 88.00 128.00 8955.30 -3500.00 2930.00 15.00 14.87 2.03 8.06 N-22 6 T1 10885.99 100.49 104.17 8941.91 -3577.90 3088.41 15.00 6.99 -13.34 -61.76 11048.59 100.49 104.17 8912.31 -3617.06 3243.43 0.00 0.00 0.00 0.00 11180.11 90.00 105.00 8900.30 -3650.00 3370.00 8.00 -7.98 0.63 175.48 N-22 6 T2 11499.00 84.97 79.96 8914.52 -3663.80 3685.64 8.00 -1.58 -7.85 -101.75 12402.69 84.97 79.96 8993.75 -3506.81 4572.05 0.00 0.00 0.00 0.00 12453.44 87.00 80.00 8997.30 -3498.00 4621.91 4.00 4.00 0.09 1.22 N-22 6 T3 12548.03 88.06 83.64 9001.38 -3484.56 4715.43 4.00 1.12 3.84 73.88 13194.02 88.06 83.64 9023.30 -3413.00 5357.07 0.00 0.00 0.00 0.00 N-22 6 T4 Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN ' MapE TooUCo ft deg deg ft ft ft ft ft deg/100ft ft ft 7400.00 36.12 134.90 6483.19 6402.89 2513.93 -1864.88 1792.67 0.00 5964777.66 636232.62 Stag Dir 1 7420.00 36.40 138.93 6499.32 6419.02 2525.38 -1873.51 1800.74 12.00 5964769.17 636240.85 Start Dir 4/ 7500.00 34.89 143.78 6564.35 6484.05 2569.48 -1909.88 1829.86 4.00 5964733.34 636270.61 MWD+IFR 7600.00 33.30 150.33 6647.18 6566.88 2620.43 -1956.83 1860.37 4.00 5964686.95 636301.95 MWD+IFR 7690.00 32.19 156.66 6722.90 6642.60 2662.14 -2000.32 1882.10 4.00 5964643.85 636324.46 End Dir 7700.00 32.19 156.66 6731.36 6651.06 2666.54 -2005.22 1884.21 0.00 5964639.00 636326.66 MWD+IFR 7800.00 32.19 156.66 6815.98 6735.68 2710.63 -2054.14 1905.31 0.00 5964590.47 636348.63 MWD+IFR 7900.00 32.19 156.66 6900.61 6820.31 2754.71 -2103.05 1926.42 0.00 5964541.94 636370.60 MWD+IFR 8000.00 32.19 156.66 6985.24 6904.94 2798.79 -2151.97 1947.52 0.00 5964493.41 636392.58 MWD+IFR 8100.00 32.19 156.66 7069.86 6989.56 2842.88 -2200.89 1968.62 0.00 5964444.88 636414.55 MWD+IFR 8200.00 32.19 156.66 7154.49 7074.19 2886.96 -2249.81 1989.73 0.00 5964396.35 636436.53 MWD+IFR 8300.00 32.19 156.66 7239.12 7158.82 2931.04 -2298.73 2010.83 0.00 5964347.82 636458.50 MWD+IFR 8341.58 32.19 156.66 7274.30 7194.00 2949.37 -2319.07 2019.60 0.00 5964327.64 636467.64 LCU/TJG 8400.00 32.19 156.66 7323.74 7243.44 2975.13 -2347.65 2031.93 0.00 5964299.29 636480.47 MWD+IFR 8500.00 32.19 156.66 7408.37 7328.07 3019.21 -2396.57 2053.04 0.00 5964250.76 636502.45 MWD+IFR 8600.00 32.19 156.66 7492.99 7412.69 3063.29 -2445.49 2074.14 0.00 5964202.23 636524.42 MWD+IFR 8688.99 32.19 156.66 7568.30 7488.00 3102.52 -2489.02 2092.92 0.00 5964159.04 636543.98 TJF 8700.00 32.19 156.66 7577.62 7497.32 3107.38 -2494.41 2095.24 0.00 5964153.70 636546.40 MWD+IFR 8800.00 32.19 156.66 7662.25 7581.95 3151.46 -2543.33 2116.35 0.00 5964105.17 636568.37 MWD+IFR 8900.00 32.19 156.66 7746.87 7666.57 3195.54 -2592.25 2137.45 0.00 5964056.64 636590.34 MWD+IFR 8926.50 32.19 156.66 7769.30 7689.00 3207.23 -2605.21 2143.04 0.00 5964043.78 636596.17 TJE 9000.00 32.19 156.66 7831.50 7751.20 3239.63 -2641.16 2158.55 0.00 5964008.11 636612.32 MWD+IFR 9100.00 32.19 156.66 7916.12 7835.82 3283.71 -2690.08 2179.66 0.00 5963959.58 636634.29 MWD+IFR 9178.20 32.19 156.66 7982.30 7902.00 3318.18 -2728.34 2196.16 0.00 5963921.63 636651.47 TJD 9200.00 32.19 156.66 8000.75 7920.45 3327.79 -2739.00 2200.76 0.00 5963911.05 636656.27 MWD+IFR 9300.00 32.19 156.66 8085.38 8005.08 3371.88 -2787.92 2221.86 0.00 5963862.52 636678.24 MWD+IFR 9400.00 32.19 156.66 8170.00 8089.70 3415.96 -2836.84 2242.97 0.00 5963813.99 636700.21 MWD+IFR 9486.61 32.19 156.66 8243.30 8163.00 3454.14 -2879.21 2261.24 0.00 5963771.96 636719.25 TJC 9500.00 32.19 156.66 8254.63 8174.33 3460.04 -2885.76 2264.07 0.00 5963765.46 636722.19 MWD+IFR 9600.00 32.19 156.66 8339.25 8258.95 3504.13 -2934.68 2285.17 0.00 5963716.93 636744.16 MWD+IFR 9604.78 32.19 156.66 8343.30 8263.00 3506.23 -2937.02 2286.18 0.00 5963714.61 636745.21 TJB vent 1S 7S Sperry-Sun BP Planning Report Companyt 8P Amoco Date: 7/10/2006 Time; 16:32:56 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference:: Well: N-22, True North Site: PB N` Pad Vertical (TVD) Reference: 33 :22 5/27/198500 :00 80.3 Well: N-22 Section (VS) Reference: Well (O.UON,O.OOE,122.50Azi) Wellpatht Plan N-22B Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inel Azim TVD Sys TVI) V5 N/S E/W DLS iVlapN MapE TooUCo ft deg deg ft ft ft ft ft deg/100ft ft ft 9700.00 32.19 156.66 8423.88 8343.58 3548.21 -2983.60 2306.28 0.00 5963668.40 636766.14 MWD+IFR 9790.30 32.19 156.66 8500.30 8420.00 3588.02 -3027.77 2325.33 0.00 5963624.58 636785.98 7" 9800.00 32.19 156.66 8508.51 8428.21 3592.29 -3032.52 2327.38 0.00 5963619.88 636788.11 MWD+IFR 9810.00 32.19 156.66 8516.97 8436.67 3596.70 -3037.41 2329.49 0.00 5963615.02 636790.31 Start Dir 1 9838.00 34.97 150.96 8540.30 8460.00 3609.93 -3051.28 2336.34 15.00 5963601.28 636797.41 Shublik 9900.00 41.86 140.87 8588.90 8508.60 3645.26 -3082.93 2358.07 15.00 5963570.03 636819.70 MWD+IFR 9951.46 48.10 134.43 8625.30 8545.00 3680.35 -3109.69 2382.62 15.00 5963543.71 636844.72 TSAD / TZ 10000.00 54.26 129.44 8655.72 8575.42 3717.63 -3134.89 2410.77 15.00 5963519.02 636873.32 MWD+IFR 10057.84 61.83 124.43 8686.33 8606.03 3766.51 -3164.27 2450.01 15.00 5963490.35 636913.07 End Dir : 1 10100.00 61.83 124.43 8706.23 8625.93 3803.65 -3185.28 2480.66 0.00 5963469.89 636944.09 MWD+IFR 10200.00 61.83 124.43 8753.44 8673.14 3891.76 -3235.11 2553.38 0.00 5963421.37 637017.68 MWD+IFR 10214.52 61.83 124.43 8760.30 8680.00 3904.55 -3242.35 2563.94 0.00 5963414.32 637028.37 TZ4A/42N 10300.00 61.83 124.43 8800.65 8720.35 3979.86 -3284.95 2626.09 0.00 5963372.85 637091.27 MWD+IFR 10328.90 61.83 124.43 8814.30 8734.00 4005.32 -3299.35 2647.11 0.00 5963358.83 637112.54 PGOC 10400.00 61.83 124.43 8847.87 8767.57 4067.96 -3334.79 2698.81 0.00 5963324.33 637164.86 MWD+IFR 10432.69 61.83 124.43 8863.30 8783.00 4096.76 -3351.08 2722.58 0.00 5963308.47 637188.92 POWC 10500.00 61.83 124.43 8895.08 8814.78 4156.07 -3384.62 2771.52 0.00 5963275.81 637238.45 MWD+IFR 10513.18 61.83 124.43 8901.30 8821.00 4167.68 -3391.19 2781.11 0.00 5963269.41 637248.15 BCGL 10531.37 61.83 124.43 8909.89 8829.59 4183.70 -3400.25 2794.33 0.00 5963260.59 637261.53 Start Dir 1 10600.00 72.03 125.93 8936.75 8856.45 4246.69 -3436.61 2845.85 15.00 5963225.16 637313.69 MWD+IFR 10700.00 86.91 127.86 8954.97 8874.67 4344.43 -3495.50 2924.23 15.00 5963167.69 637393.10 MWD+IFR 10707.33 88.00 128.00 8955.30 8875.00 4351.72 -3500.00 2930.00 15.00 5963163.29 637398.95 N-226 T1 10800.00 94.57 115.74 8953.21 8872.91 4444.14 -3548.81 3008.48 15.00 5963115.90 637478.29 MWD+IFR 10885.99 100.49 104.17 8941.91 8861.61 4527.18 -3577.90 3088.41 15.00 5963088.25 637558.72 End Dir : 1 10900.00 100.49 104.17 8939.36 8859.06 4540.26 -3581.28 3101.77 0.00 5963085.11 637572.14 MWD+IFR 11000.00 100.49 104.17 8921.15 8840.85 4633.60 -3605.35 3197.11 0.00 5963062.75 637667.88 MWD+IFR 11048.59 100.49 104.17 8912.31 8832.01 4678.96 -3617.06 3243.43 0.00 5963051.88 637714.41 Start Dir 8/ 11100.00 96.39 104.50 8904.76 8824.46 4727.26 -3629.65 3292.69 .8.00 5963040.17 637763.88 MWD+IFR 11180.11 90.00 105.00 8900.30 8820.00 4803.40 -3650.00 3370.00 8.00 5963021.20 637841.53 N-22B T2 11200.00 89.68 103.44 8900.36 8820.06 4822.29 -3654.89 3389.28 8.00 5963016.66 637860.89 MWD+IFR 11300.00 88.06 95.61 8902.34 8822.04 4914.26 -3671.42 3487.80 8.00 5963001.90 637959.69 MWD+IFR 11400.00 86.47 87.76 8907.12 8826.82 4999.97 -3674.35 3587.56 8.00 5963000.76 638059.48 MWD+-FR 11499.00 84.97 79.96 8914.51 8834.21 5077.02 -3663.80 3685.64 8.00 5963013.06 638157.34 End Dir : 1 1 11500.00 84.97 79.96 8914.60 8834.30 5077.75 -3663.63 3686.62 0.04 5963013.25 638158.32 MWD+IFR 11600.00 84.97 79.96 8923.37 8843.07 5151.15 -3646.25 3784.71 0.00 5963032.37 638256.08 MWD+IFR 11700.00 84.97 79.96 8932.14 8851.84 5224.54 -3628.88 3882.80 0.00 5963051.50 638353.83 MWD+IFR 11800.00 84.97 79.96 8940.91 8860.61 5297.93 -3611.51 3980.88 0.00 5963070.62 638451.58 MWD+IFR 11900.00 84.97 79.96 8949.67 8869.37 5371.32 -3594.14 4078.97 0.00 5963089.75 638549.34 MWD+IFR 12000.00 84.97 79.96 8958.44 8878.14 5444.71 -3576.77 4177.06 0.00 5963108.87 638647.09 MWD+IFR 12100.00 84.97 79.96 8967.21 8886.91 5518.10 -3559.40 4275.15 0.00 5963127.99 638744.85 MWD+IFR 12200.00 84.97 79.96 8975.98 8895.68 5591.49 -3542.02 4373.24 0.00 5963147.12 638842.60 MWD+IFR 12300.00 84.97 79.96 8984.74 8904.44 5664.89 -3524.65 4471.33 0.00 5963166.24 638940.35 MWD+IFR 12317.76 84.97 79.96 8986.30 8906.00 5677.92 -3521.57 4488.74 0.00 5963169.64 638957.71 25N ! T26 12400.00 84.97 79.96 8993.51 8913.21 5738.28 -3507.28 4569.42 0.00 5963185.36 639038.11 MWD+IFR 12402.69 84.97 79.96 8993.75 8913.45 5740.25 -3506.81 4572.05 0.00 5963185.88 639040.73 Stag Dir 4/ 12453.44 87.00 80.00 8997.30 8917.00 5777.56 -3498.00 4621.91 4.00 5963195.58 639090.42 N-22B T3 12500.00 87.52 81.79 8999.53 8919.23 5812.33 -3490.64 4667.82 4.00 5963203.76 639136.19 MWD+IFR 12548.03 88.06 83.64 9001.38 8921.08 5849.21 -3484.56 4715.43 4.00 5963210.69 639183.68 End Dir : 1 12600.00 88.06 83.64 9003.14 8922.84 5889.65 -3478.80 4767.05 0.00 5963217.37 639235.18 MWD+IFR 12700.00 88.06 83.64 9006.54 8926.24 5967.47 -3467.72 4866.37 0.00 5963230.23 639334.29 MWD+IFR 12800.00 88.06 83.64 9009.93 8929.63 6045.29 -3456.65 4965.70 0.00 5963243.08 639433.39 MWD+IFR 12900.00 88.06 83.64 9013.32 8933.02 6123.11 -3445.57 5065.03 0.00 5963255.93 639532.50 MWD+IFR 13000.00 88.06 83.64 9016.72 8936.42 6200.93 -3434.49 5164.35 0.00 5963268.78 639631.60 MWD+IFR Went 7S 1S 1S 4S 38 4S 4S 0 ~S ~S 4S AS 19 QS ~S ~S ~S ~S AS AS AS AS AS 0 ~S i4 flS AS AS AS AS Sperry-Sun BP Planning Report Company; BP Amoco ' Date: 7/10/2006 Time: 16:32:56 t agc: 4 Field: Prudhoe Bay " Co-ordinate(NE) Reference: Well: N-22, True. North Site: PB N Pad Vertical (TVD) Reference: 33:22 5127!1985 00:00 80.3 Well: N-22 Section (VS) Reference: WeN (4.OON,O.OOE,122.50Azi) Wellpath: Plan N-226: Survey Calculation Method: Minimum Curvature Db: Oracfe Survey MD Inc! Azim TVD Sys TVD VS N/5 E/W DLS MapN MapE Tool/Co ft deg deg ft ft ft ft ft deg/100ft #t ft 13100.00 88.06 83.64 9020.11 8939.81 6278.75 -3423.42 5263.68 0.00 5963281.64 639730.71 MWD+IFR 13105.60 88.06 83.64 9020.30 8940.00 6283.11 -3422.80 5269.25 0.00 5963282.36 639736.26 MHO/HOT 13194.00 88.06 83.64 9023.30 8943.00 6351.89 -3413.00 5357.05 0.00 5963293.72 639823.86 41 /2" 13194.02 88.06 83.64 9023.30 8943.00 6351.91 -3413.00 5357.07 0.00 5963293.72 639823.88 N-226 T4 -ent • Sperry-Sun Anticollision Report • Company: BP Amoco Date: 7/10/2006 Time: 16:39:36 Page: 1 Fietd: Prudhoe Bay Reference $ite: PB N Pad Go-ordieati:(NE) Reference: Welf: N-22, True North Reference WeB: N-22 Vertical (TVD) Reference: 33:22 5/27/1985:00:00 80.3 Reference Wellpath: Plan N-22B Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are Tlroid~nadis in this fRhTlcipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval; 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 7400.00 to 13194.02 ft Scan Method: Trav Cylinder North Maximum Radius: 1515.22 ft Erro r Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 5/2/2006 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 100.00 7400.00 1 : Sperry-Sun BOSS gyro multi (100.00-109~$(GYRO Sperry-Sun BOSS gyro multishot 7400.00 13194.02 Planned: N-22B wp03 V28 MWD+IFR+MS MWD +IFR + M ulti Station Casing Points MD' TVD Diameter Hole Size Name ft ft in in 9790.30 8500.30 7.000 8.500 7" 13194.00 9023.30 4.500 6.125 41/2" Summary <----- Offset Wellpath ---> Reference Offset Ctr-Ctr No-Go Albwable Site WeB Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft N-22,PIan N-226,N-226 9950.00 9950.00 0.00 410.73 -410.73 FAIL: Major Risk PB H Pad H-05 H-05 V4 12913.03 11125.00 757.08 779.37 -22.29 FAIL: Major Risk PB H Pad H-05 H-05A V12 12970.24 11025.00 840.11 616.62 223.49 Pass: Major Risk PB H Pad H-15 H-15 V1 11174.79 11800.00 1090.71 1380.72 -290.01 FAIL: Major Risk PB H Pad H-16 H-16 V3 Out of range PB H Pad H-25 H-25 V1 12260.65 10775.00 664.90 747.80 -82.89 FAIL: Major Risk PB H Pad H-26 H-26 V1 Out of range PB H Pad H-30 H-30 V1 Out of range PB N Pad N-02 N-02 V1 9378.82 9950.00 1006.77 783.12 223.65 Pass: Major Risk PB N Pad N-02 Plan N-02A KOP H igh V1 9899.75 10650.00 360.31 719.56 -359.24 FAIL: Major Risk PB N Pad N-02 Plan N-02A KOP Sag V1 9834.29 11375.00 157.41 980:89 -823.48 FAIL: Major Risk PB N Pad N-03 N-03 V1 Out of range PB N Pad N-09 N-09 V1 Out of range PB N Pad N-10 N-10 V1 Out of range PB N Pad N-10 N-10A V1 Out of range PB N Pad N-11A N-11A V1 Out of range PB N Pad N-11A N-11 B V7 Out of range PB N Pad N-11A N-11 BP61 V5 Out of range PB N Pad N-11A N-11 BP62 V5 Out of range PB N Pad N-11A N-11C V7 Out of range PB N Pad N-11 N-11 V1 Out of range PB N Pad N-12 N-12 V1 Out of range PB N Pad N-22A N-22A V7 7474.85 7475.00 3.36 768.10 -764.73 FAfL: Major Risk PB N Pad N-22 N-22 V1 7474.85 7475.00 3.36 768.14 -764.78 FAIL: Major Risk PB N Pad N-24 N-24 V1 7484.91 7725.00 993.39 353.68 639.71 Pass: Major Risk PB N Pad N-25 N-25 V1 Out of range Site: Well: Rule Assigned: Major Risk Wellpath: N-22,PIa n N-226,N-22B wp03 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Antis Ctr-Ctr No-Go Albwable MD TVD MD TVD Ref Offset. TFO+AZI TFO-I3S Casing/HSDistance Area" Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 7400.00 6483.19 7400.00 6483.19 121.28 0.00 134.90 0.00 8.500 0.00 397.34 -397.34 FAIL 7425.00 6503.35 7425.00 6503.35 121.55 0.12 139.22 0.00 8.500 0.00 398.24 -398.24 FAIL 7450.00 6523.56 7450.00 6523.56 121.46 0.25 140.71 0.00 8.500 0.00 398.11 -398.11 FAIL 7475.00 6543.90 7475.00 6543.90 121.37 0.34 142.23 0.00 8.500 0.00 397:93 -397.93 FAIL 7500.00 6564.35 7500.00 6564.35 121.28 0.41 143.78 0.00 8.500 0.00 397.74 -397.74 FAIL 7525.00 6584.91 7525.00 6584.91 121.10 0.54 145.37 0.00 8.500 0.00 397.30 -397.30 FAIL 7550.00 6605.57 7550.00 6605.57 120.92 0.65 146.99 0.00 8.500 0.00 396.86 -396.86 FAIL 7575.00 6626.33 7575.00 6626.33 120.74 0.74 148.64 0.00 8.500 0.00 396.42 -396.42 FAIL • • ~'~~~51~~1~'~f11, 1~~~~~~ ~~~~~~~~~ ~~ELL ~i A.mIE -~' ®evel®pment Ser~~ice Expt®rat®ry~ Strati ra hic Vest g P lion-C®nventional Well Circle Appr®priate Letter /Paragraphs t® be Included in `Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER '~ 4~`HAT (OPTIONS) APPLIES !` MULTI LATERAL !~ The permit is for a new we(lbore segment of existing i well (If fast two digits in ;Permit No. .:API No. ~0- ; API number are ' ~ - - ~ ; between 60-69) ,Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 .A.AC 25.00~(fj, all records, data and logs '~ acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number i (~0- - -) from records. data and logs acquired for well SPACNG The permit is approved subject to full compliance with 20 AAC EXCEPTION ?3.0>j. Approval to perforate and produce !inject is contingent ! 'upon issuance of a conservation order approving a spacing exception. assumes the I liability of any protest to the spacing exception that may occur. i DRY DITCH Al( dry ditch sample sets submitted to the Commission must be in :SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10~ sample intervals I through target zones. ;Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed ': well for (name of well] until after (Com a~nv Name) has designed and implemented a water well testing program to provide baseline data I ion water quality and quantity. (Comganv Name) must contact the Commission to obtain advance approval of such water well testing grogram. Rev- f 25:06 C jody`transmittaf checklist ~~ Terri Hubble BP Exploration AK Inc. PO Box 1966:12 MB 7-5 Anchorage, AK 99519 PAY TO THE ORDER OF ~nn ~ e~ nn ss-sn zsz 31.2 "Mastercard Check" First National Barik Alaska _ Anchorag~e,)AK 9950f MEMO - v ~: ~ 25 200060:99146 2 27 L556~I' DATE I L~/V.J'- / $ ~~ ~ y~. DOLLARS i 03L2_ s • ~ j ~ o I o a I N N I ' a~ o `o ~ ~ i c Q ~ ~ ~ ~ I' I c~: III I~ I OI I ~ ~ ~ I p' ~ I II c O ', C O ~ III O ~ ''~, ~ I O ~i i ~ ~ _ , m = ~. ~. I NI, ''. zl i ~ II Z ~ I ' I a •`~ a m: ° w~ co 0': N: I , p O, a, ', ~' ~I W ~~ ~ j ~~I ~ ~ I O_ y N I U• ~ ~ O a Q. III i~', N V' N' N. O U. ~ ~ ~ 2. Z _ I ~: N N ~~ O C, W'I I ~ p ~ ~ ~~ ~ Uj, N~ N~ N~ O~ Vj. fA' t~'. fq: N: y: y. y: ~ ~ tlJ, N~ y: N, N ~ N. N~ N• Un N~ m. a~ m. a~ a~ a~: a~ m. a~: a~ m. a~, a~, Q Q. Q. Q Q. Q. Q Q a~ m. a~: a~, a~. Q, m. m. a~ m. a~ o, Q. o. Q. Q. Q Q Q ~ }, ~ } } } } } } } } } } Z, Z Z, Z, Z Z, Z, Z, ~, ~, >-, ~, ~, Z, ~, ~, )-, >-, ~, Z, Z, z, Z; Z, Z, Z, ~ 'a I~ N o N ~ ~ ~ ~ V, T N ' ~ ~ ~ G ~ ~ ~ i N ~ ~ N, y. 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N ~ C' C O O O O O Y" O O N' O O O N (6 f0 Q N. ~ N• T O, O1 `~ Y a ~ Q o ~: m m~ i~, m g t L, n m, m ~, -a, m c m N' m ._ t m o N' o a 3 0 ~ 0 3. `-° ° a~i' ui u~ f0 a a ~ 3 3 m: ~ a~, -° E. ~ v w' ~ ..°-~ 3, `°' ~. o. o. m uoi: `~' a °~ ~ ~ o. 3 m t a~'i o °o pl •o ~ ~ v =o > ~' a-°i .Q -a a 'o' m' ~ o c a ~: o $ oc, a ~ N vO° a~ ~ °- o. rn c. a. Q w ~ d. a I~ m m: m o' o a~ a~ E Y o° o E' a~ E s o, a~ ~~- w c, a~ a xs °~ o m ~ m: ~ ~ °- 5' ~ aoi $ a o' a> ~ - ~° a~ a~ -o f6' E, ~ c°~ N I v'i o o c ~' ots ~i r,. a m., a a fl. ~~ ti a z' r ~ m' rn m ~- ~ 3~ v' rn -o v o ~: ~ o, o ~ 3, ~, ~ !~ .N m. •c. ~ ~ ~ ~ ~ m N Y, N ~o o ~ ~~ -p 2 c, u~. ~ ~N o a a~ OI ~: ~ ~ .~~ a a ~ ~ >; ~ ar a~ o~ 3. c ~: m ~ c ar o* y c c m a a ~" ° c~i~ o- c°~' m :3' >, ~' m' ii ~' m' s a ~: a. v c ~ ~, s ~ a, w c' i ,~ w: v v o vo?i ~ ~ 3 m v o; ~ ~ o: ~. ~ c: ~ c ~, d m E ar m m~ m v' o ~: c c m. c°i: m. - o: m c N, o. m.. X ~ ~ 3 m. m. m. ~: m, m m E. m. 3 ~: ~: o; v, o', m; ~ ~; ~, = °? ~: ? -° °~ ~ - c ~: i ~ ~: ~ o. c ~ w c o' o' °' ° ~ •; m' m, ~ v a o' ~ a ~ a ~' > >' 3 ~ v ~ v a~i. ~ w w Y' y, ~: ~ I °- .~ Q: m: J ml E' ~ a - a>: a~: a~ ~ ~ c - 3 c c 't I- F F- ~,~, m. m > _ a o. o. o: v ~, ~ .~ m. c. m 'c, ~' m' o; ~ ~ a a o o m °~ - ~, o; ~ o: o; ~, ~' ~ m, v. m a ~: = O, O ~, o ~ a~: m, a~ a~, o. Y ~, m a~ U ~ a ~, ~, s ~': ~ cn ~ O, O a, a v ~': ¢ a z, v, cn, U, c.~, U, v, ¢; w ¢, =: p, m m, U, ~' `~': ~' a. p, cn, v~, U, W a O r N M~ to (D f~ co O O r N M d' tC) O~ 00 O O r N M V l u'~ f0 I~ ~ O T. ~ r N M V~ (O I~ W O r r r r r r r r ____ __-_ ._ _.__ _._ M M M M_ _ _ _ _ ..- _ _ __- _ __ a+ N _._ ___ _ ._~__`- N N_ N N N N N N N +N OM M M M M M i __ V U _- - -___ _ O (O F- ~ °o y N O C f6 ~ R r f6 O p N ~~ p N p N ~ O ~ C r ~ O N r I N r ~ r d O w r ~ r T N •C ~ '' C ~ ¢ '~ ~ L V ~ as a ~ w` a~ ~~ a~ ~N ~~ p a ._ O U I w ~ I~ m ~ p `~ i rn c ~ O .~ o C .N .~ ~ wv ~~I w m p N U C O O N 0 U • Well History File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Wetl History file and to sirn.plify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ,~ n-22b.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed Apr 30 13:42:42 2008 Reel Header Service name .............LISTPE Date . ...................08/04/30 Ori 9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ...................08/04/30 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Physical EOF Comment Record TAPE HEADER Prudhoe Bay unit MWD/MAD LOGS WELL NAME: N-22B API NUMBER: 500292134902 OPERATOR: BP Exploration (Alaska) Inc LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 30-APR-08 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 Job NUMBER: w-0004872790 w-0004872790 w-0004872790 LOGGING ENGINEER: M. BUCKLEY M. BUCKLEY M. BUCKLEY OPERATOR WITNESS: D. MASKELL D. MASKELL B. DECKER MWD RUN 4 MAD RUN 4 JOB NUMBER: w-0004872790 w-0004872790 LOGGING ENGINEER: M. BUCKLEY M. BUCKLEY OPERATOR WITNESS: B. DECKER B. DECKER SURFACE LOCATION SECTION: 8 TOWNSHIP: 11N RANGE: 13E FNL: FSL: 706 FEL: FwL: 531 Page 1 ~oC~ -~~ l ~ l ~a~~ C ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 8.500 2ND STRING 6.125 3RD STRING PRODUCTION STRING REMARKS: n-22b.tapx 72.58 44.50 CASING DRILLERS SIZE (IN) DEPTH (FT) 9.625 7240.0 7.000 9906.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 7240'MD/6349'TVD IN THE N-22 WELLBORE. ONLY SROP DATA ARE INCLUDED FOR THIS RUN. 4. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC RESISTIVITY - PHASE 4 (EWR4). RUN 2 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). RUNS 3,4 ALSO INCLUDED AT-BIT INCLINATION (ABI). RUN 4 ALSO INCLUDED AZIMUTHAL LITHO-DENSITY (ALD) AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). UPHOLE SGRC TIE-IN DATA ACQUIRED WHILE POOH AFTER COMPLETING MWD RUN 2 WERE MERGED WITH RUN 2 MWD DATA. MAD PASS DATA ACQUIRED WHILE POOH AFTER REACHING FINAL TD ARE PRESENTED SEPARATELY. 5. DEPTH SHIFTING WAS WAIVED PER E-MAIL FROM D.DORTCH (SAIC/BP) DATED 21 APRIL 2008, AS AUTHORIZED BY ROGER SELS (BP). THIS MWD LOG IS THE PDCL FOR N-22B. 6. MWD RUNS 1-4 REPRESENT WELL N-22B WITH API# 50-029-21349-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13155'MD/8955'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP Page 2 n-22b.tapx SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. DENSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.4-8.5 PPG MUD SALINITY: 3700-4700 PPM CHLORIDES FORMATION WATER SALINITY: 11500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 7032.0 13090.0 ROP 7240.0 13155.0 RPD 7240.5 13097.0 FET 7240.5 13097.0 RPM 7240.5 13097.0 RPX 7240.5 13097.0 RPS 7240.5 13097.0 NPHI 10707.0 13061.5 NCNT 10707.0 13061.5 FONT 10707.0 13061.5 RHOB 10721.5 13077.5 DRHO 10721.5 13077.5 PEF 10721.5 13077.5 Page 3 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED BASELINE DEPTH n-22b.tapx DEPTH) --- EQUIVALENT UNSHIFTED DEPTH --------- MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 MWD 3 MWD 4 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 7240.0 7270.0 7270.0 9908.0 9908.0 10799.0 10799.0 13155.0 Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 NPHI MWD Pu-S 4 1 68 52 14 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 7032 13155 10093.5 12247 7032 13155 FCNT MWD CP30 498.42 1103.8 735.721 4710 10707 13061.5 NCNT MWD CP30 25615.7 38289.1 31480.1 4710 10707 13061.5 RHOB MWD G/CC 2.151 3.37 2.32223 4713 10721.5 13077.5 DRHO MWD G/CC -0.264 0.4 0.0702151 4713 10721.5 13077.5 RPD MWD OHMM 0.79 2000 23.1388 11714 7240.5 13097 RPM MWD OHMM 0.72 1813.33 13.6738 11714 7240.5 13097 RPS MWD OHMM 0.74 1531.46 7.03836 11714 7240.5 13097 RPX MWD OHMM 0.76 1560.37 6.38829 11714 7240.5 13097 FET MWD HR 0.35 82 3.00338 11714 7240.5 13097 GR MWD API 12.69 586.83 76.8596 12117 7032 13090 PEF MwD B/E 1.09 9.75 1.93009 4713 10721.5 13077.5 ROP MWD FPH 0.04 633.84 77.3043 11831 7240 13155 Page 4 n-22b.tapx NPHI MWD PU-S 16.89 28.08 22.1552 4710 First Reading For Entire File..........7032 Last Reading For Entire File...........13155 File Trailer Service name... .......STSLIB.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/30 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLI6.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH NPHI 9857.5 FCNT 9857.5 NCNT 9857.5 PEF 9871.5 RHOB 9871.5 DRHO 9871.5 GR 9884.0 RPS 9892.0 RPD 9892.0 FET 9892.0 RPM 9892.0 RPX 9892.0 RAT 9949.5 MERGED DATA SOURCE PBU TOOL CODE MWD REMARKS: MERGED MAD PASS. Data Format specification Record Data Record Type ..................0 10707 13061.5 all MAD runs merged using earliest passes. STOP DEPTH 10705.5 10705.5 10705.5 10721.0 10721.0 10721.0 10734.0 10741.0 10741.0 10741.0 10741.0 10741.0 10799.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 4 1 9857.5 10799.0 Page 5 n-22b.tapx Data Specification Block Type.....0 Loggin Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FONT MAD CP30 4 1 68 4 2 NCNT MAD cP30 4 1 68 8 3 RHOB MAD G/CC 4 1 68 12 4 DRHO MAD G/CC 4 1 68 16 5 RPD MAD OHMM 4 1 68 20 6 RPM MAD OHMM 4 1 68 24 7 RPS MAD OHMM 4 1 68 28 8 RPX MAD OHMM 4 1 68 32 9 FET MAD HR 4 1 68 36 10 GR MAD API 4 1 68 40 11 PEF MAD B/E 4 1 68 44 12 RAT MAD FPH 4 1 68 48 13 NPHI MAD PU-5 4 1 68 52 14 First Last Name servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 9857.5 10799 10328.3 1884 9857.5 10799 FCNT MAD CP30 141.29 3225.41 819.405 1697 9857.5 10705.5 NCNT MAD cP30 16088 49006.6 31132.3 1697 9857.5 10705.5 RHOB MAD G/CC 1.785 3.315 2.39868 1700 9871.5 10721 DRHO MAD G/CC -0.956 0.972 0.0590324 1700 9871.5 10721 RPD MAD OHMM 2.27 2000 44.4971 1699 9892 10741 RPM MAD OHMM 0.78 1120.96 25.5427 1699 9892 10741 RPS MAD OHMM 0.66 1116.42 18.5645 1699 9892 10741 RPX MAD OHMM 0.5 1116.29 16.6549 1699 9892 10741 FET MAD HR 22.89 158.52 54.5364 1699 9892 10741 GR MAD API 13.01 589.08 48.936 1701 9884 10734 PEF MAD B/E 1.23 12.37 2.85245 1700 9871.5 10721 RAT MAD FPH 1 812 116.839 1700 9949.5 10799 NPHI MAD Pu-5 5.53 54.84 22.0873 1697 9857.5 10705.5 First Reading For Entire File..........9857.5 Last Reading For Entire File...........10799 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/30 Maximum Physical Record..65535 File TyL~e ................LO Next File Name..........,STSLIB.003 Physical EoF Page 6 n-22b.tapx File Header Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH $OP 7240.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): STOP DEPTH 7270.0 19-FEB-07 Insite 74.11 Memory 7270.0 7240.0 7270.0 .0 .0 TOOL NUMBER 8.500 .0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): Page 7 Lignosulfanate 10.50 60.0 9.2 1400 4.8 .000 .0 .000 131.0 .000 .0 .000 .0 • w n-22b.tapx EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWDO10 FPH 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7240 7270 7255 61 7240 7270 ROP MWDO10 FPH 0.04 8.74 4.27279 61 7240 7270 First Reading For Entire File..........7240 Last Reading For Entire File...........7270 File Trailer Service name... .......STSLIB.003 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/30 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.004 Physical EoF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 Page 8 • n-22b.tapx FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPT H GR 7032.0 9861.5 RPx 7240.5 9853.5 FET 7240.5 9853.5 RPS 7240.5 9853.5 RPM 7240.5 9853.5 RPD 7240.5 9853.5 RoP 7270.5 9908.0 LOG HEADER DATA DATE LOGGED: 23-FEB-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9908.0 TOP LOG INTERVAL (FT): 7270.0 BOTTOM LOG INTERVAL (FT): 9908.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 34.3 MAXIMUM ANGLE: 38.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 145654 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): .O BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G): 10.70 MUD VISCOSITY (S): 53.0 MUD PH: 9.8 MUD CHLORIDES (PPM): 1200 FLUID LOSS (C3): 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.900 64.0 MUD AT MAX CIRCULATING TERM PERATURE: .740 176.0 MUD FILTRATE AT MT: 1.500 64.0 MUD CAKE AT MT: 2.200 64.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format specification Record Data Record Type... ......... .0 Data specification Block Type.... .0 Logging Direction ................ .DOwn Page 9 • n-22b.tapx Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 7032 9908 8470 5753 7032 9908 RPD MWD020 OHMM 0.79 1857.53 3.15726 5227 7240.5 9853.5 RPM MWD020 OHMM 0.72 1778.11 2.79538 5227 7240.5 9853.5 RPS MWD020 OHMM 0.74 1531.46 2.57196 5227 7240.5 9853.5 RPX MWD020 OHMM 0.76 1560.37 2.69381 5227 7240.5 9853.5 FET MWD020 HR 0.35 32.16 1.81532 5227 7240.5 9853.5 GR MWD020 API 48.37 360.15 131.022 5660 7032 9861.5 ROP MWD020 FPH 0.34 195.58 83.6294 5276 7270.5 9908 First Reading For Entire File..........7032 Last Reading For Entire File...........9908 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/04/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL2B.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD curves and log header data for each bit run in separate files. Page 10 • n-22b.tapx BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPT H RPD 9854.0 10741.5 RPS 9854.0 10741.5 RPM 9854.0 10741.5 RPx 9854.0 10741.5 FET 9854.0 10741.5 GR 9862.0 10734.5 ROP 9908.5 10799.0 LOG HEADER DATA DATE LOGGED: 25-FEB-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10799.0 TOP LOG INTERVAL (FT): 9908.0 BOTTOM LOG INTERVAL (FT); 10799.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 34.3 MAXIMUM ANGLE: 97.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156435 EWR4 Electromag Resis. 4 153663 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 7240.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 50.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 3700 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATUR E (MT): 1.400 55.0 MUD AT MAX CIRCULATING TER MPERATURE: .430 194.0 MUD FILTRATE AT MT: 1.910 55.0 MUD CAKE AT MT: 1.800 55.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Page 11 • • n-22b.tapx Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name Service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 9854 10799 10326.5 1891 9854 10799 RPD MWD030 OHMM 2.41 2000 119.485 1776 9854 10741.5 RPM MWD030 OHMM 2.46 1813.33 59.5801 1776 9854 10741.5 RPS MWD030 OHMM 2.04 838.67 18.4405 1776 9854 10741.5 RPX MWD030 OHMM 1.28 793.61 15.4236 1776 9854 10741.5 FET MWD030 HR 1.51 82 8.06305 1776 9854 10741.5 GR MWD030 API 15.97 586.83 48.38 1746 9862 10734.5 ROP MWD030 FPH 0.14 110 31.9458 1782 9908.5 10799 First Reading For Entire File..........9854 Last Reading For Entire File...........10799 File Trailer Service name... .......STSLI6.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/30 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 Comment Record FILE HEADER Page 12 FILE NUMBER: RAW MWD curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY n-22b.tapx 6 • header data for each bit run in separate files. 4 .5000 VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 10707.0 13061.5 NPHI 10707.0 13061.5 FONT 10707.0 13061.5 DRHO 10721.5 13077.5 PEF 10721.5 13077.5 RHOB 10721.5 13077.5 GR 10735.0 13090.0 RP5 10742.0 13097.0 RPD 10742.0 13097.0 RPX 10742.0 13097.0 RPM 10742.0 13097.0 FET 10742.0 13097.0 ROP 10799.5 13155.0 LOG HEADER DATA DATE LOGGED: 04-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13155.0 TOP LOG INTERVAL (FT): 10799.0 BOTTOM LOG INTERVAL (FT): 13155.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.4 MAXIMUM ANGLE: 102.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156435 CTN COMP THERMAL NEUTRON 1844674407370955 EWR4 Electromag Resis. 4 153663 ALD Azimuthal Litho-Dens 231388 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 7240.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 46.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 4700 FLUID LO55 (C3): 8.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .900 74.0 MUD AT MAX CIRCULATING TERMPERATURE: .360 194.0 MUD FILTRATE AT MT: .780 74.0 MUD CAKE AT MT: .920 74.0 NEUTRON TOOL Page 13 • i n-22b.tapx MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD040 CP30 4 1 68 4 2 NCNT MwD040 CP30 4 1 68 8 3 RHOB MWD040 G/CC 4 1 68 12 4 DRHO MWD040 G/CC 4 1 68 16 5 RPD MWD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MwD040 OHMM 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 FET MWD040 HR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MWD040 B/E 4 1 68 44 12 ROP MWD040 FPH 4 1 68 48 13 NPHI MWD040 PU-S 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 10707 13155 11931 4897 10707 13155 FCNT MWD040 CP30 498.42 1103.8 735.721 4710 10707 13061.5 NCNT MWD040 CP30 25615.7 38289.1 31480.1 4710 10707 13061.5 RHOB MWD040 G/CC 2.151 3.37 2.32223 4713 10721.5 13077.5 DRHO MWD040 G/CC -0.264 0.4 0.0702151 4713 10721.5 13077.5 RPD MWD040 OHMM 2.42 35.58 8.9874 4711 10742 13097 RPM MWD040 OHMM 2.02 37.59 8.43739 4711 10742 13097 RPS MWD040 OHMM 2.18 34.12 7.6955 4711 10742 13097 RPX MWD040 OHMM 2.22 28.5 7.0812 4711 10742 13097 FET MWD040 HR 0.49 35.7 2.41413 4711 10742 13097 GR MwD040 API 12.69 61.08 22.3422 4711 10735 13090 PEF MwD040 B/E 1.09 9.75 1.93009 4713 10721.5 13077.5 ROP MWD040 FPH 0.26 633.84 88.3214 4712 10799.5 13155 NPHI MWD040 PU-S 16.89 28.08 22.1552 4710 10707 13061.5 First Reading For Entire File..........10707 Last Reading For Entire File...........13155 File Trailer Page 14 n-22b.tapx Service name... .......STSLI6.006 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/30 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.007 Physical EOF File Header Service name... .......STSLIB.007 Service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/04/30 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 9857.5 10705.5 FCNT 9857.5 10705.5 NCNT 9857.5 10705.5 PEF 9871.5 10721.0 DRHO 9871.5 10721.0 RHOB 9871.5 10721.0 GR 9884.0 10734.0 FET 9892.0 10741.0 RPX 9892.0 10741.0 RPS 9892.0 10741.0 RPM 9892.0 10741.0 RPD 9892.0 10741.0 RAT 9949.5 10799.0 LOG HEADER DATA DATE LOGGED: 04-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10799.0 TOP LOG INTERVAL (FT): 9857.5 BOTTOM LOG INTERVAL (FT): 10799.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.4 MAXIMUM ANGLE: 102.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER Page 15 n-22b.tapx DGR DUAL GAMMA RAY CTN COMP THERMAL NEUTRON EwR4 Electromag Resis. 4 ALD Azimuthal Litho-Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 156435 1844674407370955 153663 231388 6.125 7240.0 Polymer 8.40 46.0 9.1 4700 8.8 .900 74.0 .360 194.0 .780 74.0 .920 74.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MAD041 CP30 4 1 68 4 2 NCNT MAD041 CP30 4 1 68 8 3 RHOB MAD041 G/CC 4 1 68 12 4 DRHO MAD041 G/CC 4 1 68 16 5 RPD MAD041 OHMM 4 1 68 20 6 RPM MAD041 OHMM 4 1 68 24 7 RPS MAD041 OHMM 4 1 68 28 8 RPX MAD041 OHMM 4 1 68 32 9 FET MAD041 HR 4 1 68 36 10 GR MAD041 API 4 1 68 40 11 PEF MAD041 B/E 4 1 68 44 12 RAT MAD041 FPH 4 1 68 48 13 NPHI MAD041 PU-S 4 1 68 52 14 Page 16 • n-22b.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9857.5 10799 10328.3 1884 9857.5 10799 FONT MAD041 CP30 141.29 3225.41 819.405 1697 9857.5 10705.5 NCNT MAD041 CP30 16088 49006.6 31132.3 1697 9857.5 10705.5 RHOB MAD041 G/CC 1.785 3.315 2.39868 1700 9871.5 10721 DRHO MAD041 G/CC -0.956 0.972 0.0590324 1700 9871.5 10721 RPD MAD041 OHMM 2.27 2000 44.4971 1699 9892 10741 RPM MAD041 OHMM 0.78 1120.96 25.5427 1699 9892 10741 RPS MAD041 OHMM 0.66 1116.42 18.5645 1699 9892 10741 RPX MAD041 OHMM 0.5 1116.29 16.6549 1699 9892 10741 FET MAD041 HR 22.89 158.52 54.5364 1699 9892 10741 GR MAD041 API 13.01 589.08 48.936 1701 9884 10734 PEF MAD041 B/E 1.23 12.37 2.85245 1700 9871.5 10721 RAT MAD041 FPH 1 812 116.839 1700 9949.5 10799 NPHI MAD041 PU-S 5.53 54.84 22.0873 1697 9857.5 10705.5 First Reading For Entire File..........9857.5 Last Reading For Entire File...........10799 File Trailer Service name... .......sTSL26.007 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/30 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date . ................... 08/04/30 Origin ................... STS Tape Name. .... ........ UNKNOWN continuation Number...... 01 Next Tape Name........... UNKNOWN Comments ................. STS LIS Reel Trailer Service name .............LISTPE Date . ...................08/04/30 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF writing Library. scientific Technical services writing Library. scientific Technical services Physical EOF Page 17 End Of LIS File n-22b.tapx Page 18 •
