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Home My WebLink About204-1421 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Tuesday, February 6, 2024 2:49 PM To:Regg, James B (OGC) Subject:FW: [EXTERNAL] FW: CDR2 N-11 Initial BOP Test Attachments:Nabors CDR2-AC 01-12-2024.xlsx; N-11 Nabors CDR2-AC 2 Initial Test 1-12-2024 Closure Times.jpg Phoebe Brooks Research Analyst Alaska Oil and Gas ConservaƟon Commission Phone: 907‐793‐1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Mark Igtanloc <Mark.Igtanloc@hilcorp.com> Sent: Tuesday, February 6, 2024 1:39 PM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Subject: RE: [EXTERNAL] FW: CDR2 N‐11 Initial BOP Test Phoebe, Here is the form with the recorded closure times, sorry for my mistake. Mark Igtanloc Sr. Drilling Foreman – CTD Rig (907) 670‐3097 Cell (907) 268‐9140 Positional Email AlaskaNS‐CTD‐DSM@hilcorp.com Alternate: John Perl Hilcorp Alaska, LLC From: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Sent: Monday, February 5, 2024 14:09 To: Mark Igtanloc <Mark.Igtanloc@hilcorp.com> Subject: [EXTERNAL] FW: CDR2 N‐11 Initial BOP Test Mark, The Control System Response Times were left blank on this 1/12/24 report; please advise. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. PBU N-11CPTD 2041420 2 Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas ConservaƟon Commission Phone: 907‐793‐1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Mark Igtanloc <Mark.Igtanloc@hilcorp.com> Sent: Saturday, January 13, 2024 3:50 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Alaska NS ‐ CTD DSM <AlaskaNS‐CTD‐DSM@hilcorp.com> Subject: CDR2 N‐11 Initial BOP Test Mark Igtanloc Sr. Drilling Foreman – CTD Rig (907) 670‐3097 Cell (907) 268‐9140 Positional Email AlaskaNS‐CTD‐DSM@hilcorp.com Alternate: John Perl 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, 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. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:CDR2AC DATE:1/12/24 Rig Rep.:Wheeler/Williams Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2041420 Sundry #323-507 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2996 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0 NA Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 0 NA FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 2-3/8"P Trip Tank P P Annular Preventer 1 7 1/16" 5K P Pit Level Indicators P P #1 Rams 1 Blind/Shear P Flow Indicator P P #2 Rams 1 2-3/8" Pipe/Slips P Meth Gas Detector P P #3 Rams 1 3" Pipe/Slips P H2S Gas Detector P P #4 Rams 1 2-3/8" Pipe/Slips P MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR 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"P Pressure After Closure (psi)2150 P Check Valve 0 NA 200 psi Attained (sec)17 P BOP Misc 2 2.0" Piper P Full Pressure Attained (sec)65 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:1038 P Quantity Test Result Nitgn. Bottles # & psi (Avg.):10@1970 P No. Valves 12 FP ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 3 P #1 Rams 3 P Coiled Tubing Only:#2 Rams 2 P Inside Reel valves 1 P #3 Rams 2 P #4 Rams 2 P Test Results #5 Rams NA #6 Rams NA Number of Failures:1 Test Time:6.0 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 1/10/2024 15:27 Waived By Test Start Date/Time:1/12/2024 10:00 (date)(time)Witness Test Finish Date/Time:1/12/2024 16:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Nabors B4 Fail/Grease/Pass Igtanloc/Burnett Hilcorp Alaska, LLC PBU N-11C Test Pressure (psi): nathan.wheeler@nabors.com alaskans-ctd-dsm@hilcorp.com Form 10-424 (Revised 08/2022)2024-0112_BOP_Nabors_CDR2AC_PBU_N-11C         J. Regg; 4/5/2024 BOPE – Nabors CDR2AC Control System Performance Test PBU N-11C (PTD 2041420) 1/12/2024 By Kayla Junke at 10:48 am, Feb 02, 2024 Abandoned 1/14/2024 JSB RBDMS JSB 020824 xG DSR-3/14/24 Drilling Manager 02/01/24 Monty M Myers Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.02.02 06:55:21 -09'00' Torin Roschinger (4662) ACTIVITYDATE SUMMARY 11/17/2023 CTU #9 1.75" CT Job Objective: Pre CTD, Mill XN, Mill Scale MIRU CTU 9. MU BOT LH 3.80" milling assembly. Pop on WH. Test Motor and CTP increase and not indication motor work. Pop off. Motor locked up. BD Motor. Take BOT Shop. Tested Good (think cold diesel). Well Control Drill. MU LH Motor. RIH pumping Hot slick 1% kcl w/ SL down backside. Pump down CT indications CTP motor turning. Tag XN nipple at 9747' ctm (9745 md) and time mill through taking returns. Dry drift across nipple and continue down to target depth of 10170'. See a bobble at 9959' and hard tag at 9972'. This is the same spot as prevous slickline tags. POOH to pick up conventional milling BHA. ***Continued on 11/18/23*** 11/18/2023 CTU #9 1.75" CT Job Objective: Pre CTD, Mill XN, Mill Scale Lay down BOT LH milling BHA. Trim 100' of pipe. Make up BOT Conventional Milling BHA with 3.80' turbo scale mill and RIH. Dry tag at 9980'. FCO down to 10.190' ctm. Pump 3 sweeps. Finish Pumping 3rd sweep. PUH Casing OOH 3 sweeps. RIH dry drift to 10,190' - Clean. POOH. Washed thru mandrels. FP Well to 2500' w/ 38 bbls diesel. BD BOT milling Assembly. RDMO CTU 9. ***Job Complete*** 11/19/2023 ***WELL S/I ON ARRIVAL*** DRIFT 20' X 3.70" DUMMY WHIPSTOCK TO 10,053' SAT DOWN SEVERAL SPOTS FROM 9987' TO 10,053' ***WELL S/I UPON DEPARTURE*** 11/21/2023 T/I/O= 0/198/0 TFS Unit 4 Assist E-Line (Pressure Test Plug) Pumped 34 BBLS Crude Plug not holding, LLR of .25 BPM at 1100 PSI 11/21/2023 **** WELL SI ON ARRIVAL **** INITIAL T/I/O = 0/200/0 PSI RIG UP WHIPSTOCK ON ORIENTATION TOOL. RIH TO SET AT 9980FT TOP OF WHIPSTOCK: -4.5 DEG ROHS CCL TO TOP OF WHIPSTOCK: 166" = 13.8FT. CCL STOP DEPTH: 9966.2 FT FINAL T/I/O = 0/200/0 RDMO *** JOB COMPLETED*** 11/22/2023 ****WELL S/I ON ARRIVAL*** (CTD) SET 4-1/2" PX PLUG AT 9,724' MD T-BIRD PERFORMED MULTIPLE FAILING MIT-T's (see log) ***CONTINUE ON 11/23/23 WSR*** 11/22/2023 TFS Unit 4 Assist Slick Line, Perform MIT-T MAP of 3300 PSI Target of 3000 PSI multiple attempts failed, JOB CONTINUES on 11-23-23 11/23/2023 TFS Unit 4 JOB CONTINUES FROM 11-22-23 Assist SL with MIT T, *****MIT-T PASSED***** Pumped 2.5 BBLS crude to achieve test PSI, 3308/209/0, 15 min loss of 95 PSI, 30 min loss of 43 PSI Bled back 2.5 BBLS of crude to starting PSI 11/23/2023 ***CONTINUED FROM 11/22/23 WSR*** (CTD) PERFORMED MAN DOWN/ H2S/ WELL CONTROL DRILL T-BIRD PERFORMED PASSING MIT-T TO 3,170 psi PULLED 4-1/2" PX PLUG AT 9,724' MD ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU N-11C Daily Report of Well Operations PBU N-11C 12/16/2023 ***WELL S/I ON ARRIVAL*** TAGGED TOP OF WHIPSTOCK w/ 3.70" LIB @ 10,151' SLM / 10,172' MD (192' deeper than set depth) RAN 4-1/2" X-CATCHER TO X-NIPPLE @ 9,703' SLM / 9,724' MD (+21' CORRECTION) ***WELL S/I ON DEPARTURE*** 12/18/2023 ***WELL S/I ON ARRIVAL*** HES 759 R/U ***CONT WSR ON 12/19/2023*** 12/19/2023 ***CONT WSR FROM 12/18/2023*** CALIPER TBG FROM 10,194' SLM TO 9,178' SLM WITH HES CALIPER ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** 12/21/2023 ***WELL SHUT IN ON ARRIVAL*** PT PCE 200LP - 3000HP RIH WITH 1 7/16" CABLE HEAD, 1 11/16" SWIVEL, TITAN ROLLER CENTRALIZER (2X), 1 11/16" DC MOT, BAKER 10 SETTING TOOL, WHIPSTOCK (MAX OD = 3.68' , MAX LENTH = 38') WHIPSTOCK SET DEPTH = 9,980' , CCL OFFSET = 13.5' , CCL STOP DEPTH = 9,966.5' , WHIPSTOCK SET ORIENTATION = -2.1 DEG ROHS RIG DOWN/MOVE OFF ***WELL SHUT IN ON DEPARTURE*** 12/29/2023 T/I/O = 825/190/400. Pre CDR2. Removed Chem Jewelry flange from front of Flow Cross. Installed Target 90. Installed Slip Blind in between WV and FL.. Installed 4x7 x- over on Tree Cap. Torqued to spec. Installed CDR Platform. FWP = 0/500/250 12/30/2023 T/I/O=0/0/0. Pre CDR2. Removed tree cap bonnet and installed 4"x7" crossover with tapped blind and jewelry at 90. Torqued to specs. Removed chem. injection blind from flow cross and installed target 90 with kill line. torqued to specs. Installed rig platform on wing. PT'd though kill line for shell PT. PT'd top and bottom of Swab... pass. job complete. FWP's 0/0/0 Drilling Manager 09/07/23 Monty M Myers By Grace Christianson at 11:22 am, Sep 07, 2023 323-507 DSR-9/11/23SFD 9/14/2023MGR22SEP23 * BOPE test to 3500 psi. * Variance to 20 AAC 25.112(i) Approved for alternate plug placement with fully cemented liner on upcoming CTD sidetrack. 10-407 *&:JLC 9/22/2023 09/22/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.09.22 13:02:28 -08'00' RBDMS JSB 092223 Sundry Application PBU N-11C (204-142; Sundry 323-507) Plug for Re-drill Wells Work Flow 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 9/14/2023 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 9/14/2023 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 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: September 6, 2023 Re: PBU N-11C Sundry Request Sundry approval is requested to prepare N-11C for a CTD sidetrack. Proposed plan for N-11D Producer: Prior to drilling activities, screening will be conducted to perform a cleanout run, drift for whipstock, and MIT-IA. E-line or coil will mill the XN-nipple. E-line will set a 4-1/2" packer whipstock. Coil will mill window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 4-1/2" packer whipstock. A single string 3.80" window + 10' of formation will be milled. The well will kick off drilling in the Sag, land in Ivishak Zone 3, and invert back into Zone 4. The lateral will continue in Zone 4 TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Ivishak perfs. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in October 1st 2023) x Reference N-11D Sundry submitted in concert with this request for full details. x General work scope of Pre-Rig work: 1. Fullbore: MIT-IA to 3000 psi 2. Service Coil: Mill XN nipple, clean out ~60' of sand/scale for WS (SL tag at 9,950') 3. Slickline: Dummy WS drift to 10,000' MD. Set DMY GLV. 4. E-line: Set Whipstock at 9980' MD (0 deg ROHS) 5. Service Coil: Mill 3.80" Window 6. Valve Shop: Pre-CTD tree work (install sarber spool, PT swab, leak-tight master) 7. Valve Shop: Bleed production, flow and GL lines down to zero and blind flange. Bleed wellhead pressures down to zero. 8. Opearations: Remove wellhouse and level pad. Rig Work: (Estimated to start in December 04, 2023) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2996 psi). a. Give AOGCC 24hr notice prior to BOPE test b. Test against swab and master valves (No TWC) c. Load pits with drilling fluid d. Open well and ensure zero pressure. Kill well. 2. Mill 3.80” Window. (If not done pre-rig) a. Top of whipstock at 9980' MD oriented at 0° ROHS. b. Single string exit (out of the 4.5" Liner) plus 10’ of rathole. 3. Drill build section: 4.25" OH, ~1113' (22 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~1366' (12 deg DLS planned) to a TD of 12,459' MD. 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr liner to 12,459’ MD p This completion willyp p g( p g completely isolate and abandon the parent Ivishak perfs. PTD 223-083 Sundry 323-507 Note! 8.5 ppg BHPE higher than typical PBU well! - mgr a. Drill with a constant bottom hole pressure for entire sidetrack b. Pressure deployment will be utilized c. After TD and on the last trip out of hole lay in completion/kill weight fluid in preparation for liner run d. No flow test prior to laying down drilling BHA. Assure well is dead prior to picking up liner. e. Have 2-3/8” safety joint with TIW valve ready to be picked up while running liner 6. Pump primary cement job a. Swap well over to KCl b. Cement Liner with 33 bbls - 15.3 ppg Class G cement (TOC to TOL)* 7. Freeze protect well to a min 2,200’ TVDss 8. RDMO * Approved alternate plug placement per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop: Valve & tree work 2. Slickline: SBHPS, set LTP* (if necessary). Set live GLVs. 3. Service Coil: Post rig perforate (~600’) and RPM. 4. Testing: Portable test separator flowback. The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: x A min EMW of 8.4 ppg KCL. KCl will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. x The well will be freeze protected with a non-freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil’s departure. x Additionally, all BHA’s will be lubricated and there is no plan to “open hole” a BHA. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. x Fluids >1% hydrocarbons or flammables must go to GNI. x Fluids >15% solids by volume must go to GNI. Hole Size: x The window and 10’ of formation will be milled/drilled with a 3.80” OD mill. Well Control: x BOP diagram is attached. x AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. x Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and at least 3,500 psi. x BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. x BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. x 10 AAC 25.036 c.4.C requires that a BOPE assembly must include “a firewall to shield accumulators and primary controls”. A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. NOTE! 8.4 ppg KCL will not be overbalance to 8.5 BHPE. Pressure deploy or displace to KWF prior to POOH. -mgr Hazards: x N-pad is not an H2S pad. H2S reading on N-11C: 15 ppm on 01/13/2022. x Max H2S recorded on N-pad: 96 ppm. x 1 fault crossings expected at 11,222’ MD. x Medium lost circulation risk. Reservoir Pressure: x The reservoir pressure is expected to be 3876 psi at 8800 TVD. (8.5 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2996 psi. x A min EMW of 8.6 for this well will be 60 psi Overbalanced to the reservoir. Ryan Ciolkosz CC: Well File Drilling Engineer Joseph Lastufka 907-244-4357 ppg Max H2S recorded on N-pad: 96 ppm. 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 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU N-11C Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-142 50-029-21375-02-00 10400 Conductor Surface Intermediate Liner Liner 9006 80 2661 8277 1774 645 10239 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 8853 34 - 114 33 - 2694 31 - 8308 8144 - 9918 9753 - 10398 34 - 114 33 - 2694 31 - 7366 7426 - 8576 8455 - 9004 10246 2670 4760 5410 7500 None 5380 6870 7240 8430 9935 - 10159 4-1/2" 12.6# 13Cr80 28 - 9757 8589 - 8778 Structural 4-1/2" Baker S-3 Perm Packer 9701 9701 8417 Stan Golis Sr. Area Operations Manager Wyatt Rivard wrivard@hilcorp.com 907.777.8547 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final 13.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028283 No SSSV Installed 28 - 8459 8417 N/A N/A 218 381 2176 5905 2489 2392 939 1060 232 297 N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: By Samantha Carlisle at 12:55 pm, Oct 19, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.10.19 12:23:09 -08'00' Stan Golis (880) SFD 10/20/2021 RBDMS HEW 10/19/2021 MGR19OCT2021 DSR-10/19/21 ACTIVITY DATE SUMMARY 10/10/2021 ***WELL S/I ON ARRIVAL***(drift for eline) DRIFTED 30' 2 7/8" DUMMY GUNS TO 10216' MD(10172' SLM) ***WELL LEFT S/I ON DEPARTURE*** 10/12/2021 ***WELL S/I ON ARRIVAL *** JOB SCOPE: ADPERF RIH W/ 2-7/8" X 30' GEO RAZOR PERF GUN. 6-SPF, 60 Deg PHASE. TAG TD @ 10208'. PERFORATE INTERVALS: 10132' - 10141' & 10149' - 10159'. CCL TO TOP SHOT=11.6'. CCL STOP DEPTH=10120.4' DEPTHS CORRELATED TO SLB RST LOG 21-APRIL-2011. WINDS GUSTING OVER 40 mph. GO ON WEATHER HOLD. ***CONTINUE JOB ON 10/13/21*** 10/13/2021 ***JOB CONTINUED FROM 12-OCT-2021*** RIH W/ 2-7/8" X 29' GEO RAZOR PERF GUN. PERFORATED INTERVAL 9935' - 9964', CCL TO TOP SHOT = 9.7', CCL STOP DEPTH = 9925.3' ***JOB COMPLETE / TURN OVER TO POP*** Daily Report of Well Operations PBU N-11C Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:204-142 6.50-029-21375-02-00 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 10400 10239 8853 9701 10246 None 8417 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 34 - 114 34 - 114 Surface 2661 13-3/8" 33 - 2694 33 - 2694 5380 2670 Intermediate 8277 9-5/8" 31 - 8308 31 - 7366 6870 4760 Liner 1774 7" 8144 - 9918 7426 - 8576 7240 5410 Perforation Depth: Measured depth: 10081 - 10132 feet True vertical depth:8706 - 8753 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 28 - 9757 28 - 8459 9701 8417Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer Liner 645 4-1/2" 9753 - 10398 8455 - 9004 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 31913027575307 154269 1124 5205 63 170 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: Brian Glasheen brian.glasheen@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:(907)564-5277 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 measured9006 Sundry Number or N/A if C.O. Exempt: N/A Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program n/a Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate 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 PBU N-11C 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 1:40 pm, Sep 14, 2020 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.09.14 11:45:43 - 08'00' Stan Golis DSR-9/15/2020MGR18SEP2020 RBDMS HEW 9/14/2020 ACTIVITY DATE SUMMARY 9/3/2020 ***WELL S/I ON ARRIVAL*** S/D IN HYDRATES @ 1136' SLM & 1176' SLM. PUMPED 7 BBLS OF METHANOL DOWN TBG. ***LAY DOWN FOR NIGHT, LRS IN CONTROL OF WELL*** 9/3/2020 T/I/O= 1880/1300/180. LRS unit 72 Assist Slickline TBG hydrates. (PERFORATING). Pumped 3.3 bbls of heated crude into the TBG. Pressured up to 2500 psi. Pumped 258 bbls of 180* F crude into the IA. to clearTBG obstruction. Pumped 16 bbls of 60/40 meoh down TBG for a freeze protect. remaining volume pumped on the folloing day. *** WSR Continued on 09/04/20*** 9/4/2020 *** WSR continued from 09/03/20***LRS unit 72 Assist Slickline TBG hydrates. (PERFORATING) Pumped 22 bbls 60/40 meoh down TBG for a combined 2 day total of 38 bbls for a freeze protect, Tags hung on IA casing valve and WV. SV/SSV= C MV=O CV's=OTG. FWHP's=2145/1688/313 9/4/2020 ***CONT JOB FROM 9/3/20 WSR*** DRIFT W/ 30' x 2-7/8" DUMMY GUNS TO 10,202' SLM DRIFT W/ 24' x 2" DUMMY GUNS TO 10,197' SLM ***WELL S/I ON DEPARTURE, PAD OP NOTIFIED*** 9/5/2020 ...Well shut in on arrival (Adperf post cement squeeze) PERFORATE FROM 10,081' - 10,132' WITH 2" 6SPF 60PHASE HSC MAXFORCE CHARGES. CORRELATED TO SLB RST 28-AUG-2004. REFERENCE LOG DEPTHS 10,081' - 10,132'. ***Job Complete, well shut in on departure, hand over to WPO to POP*** 9/5/2020 T/I/O = 1990/1000/170. Temp = SI. TBG FL (EL request). ALP = 1960 psi, SI @ CV. TBG FL @ 6770' (993' below #4 SO, 103 bbls). SV, WV = C. SSV, MV = O. IA, OA = OTG. 09:00 Daily Report of Well Operations PBU N-11C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED Nov 9 n mmo 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Opera9pnp'�yksvjnl ❑❑ Suspend ❑ Perforate EI Other Stimulate ❑ AfterCasing ❑ Chan a /v\�7+Jre9xrl3nf• g Q Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Mill CIBP - Cement Sqz El 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development IZ Exploratory ❑ 5. Permit to Drill Number: 204-142 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratignaphic ❑ Service ❑ 6. API Number: 50-029-21375-02-00 7 Property Designation (Lease Number): ADL 028282 & 028283 8. Well Name and Number: PBU N -11C 9, Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present WeII Condition Summary: Total Depth: measured 10400 feet Plugs measured None feet true vertical 9006 feet Junk measured 10246 feet Effective Depth: measured 10239 feet Packer measured 9701 feet true vertical 8853 feet Packer true vertical 8417 feet Casing: Length: Size: MD: TVD: Buret: Collapse: Structural Conductor 80 20" x 30" 34-114 34-114 Surface 2661 13-3/8" 33-2694 33-2694 5380 2670 Intermediate 8277 9-5/8" 31-8308 31-7366 6870 4760 Liner 1774 7" 8144-9918 7246-8576 7240 5410 Liner 645 4-1/2" 9753-10398 8455-9004 8430 7500 Perforation Depth: Measured depth: 10099 - 10132 feet True vertical depth: 8723-8753 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 28-9757 28-8458 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 9701 8417 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9854'-10248' Treatment descriptions including volumes used and final pressure: Tag TO at 10244' and paint blue/white TD Rag at 10239' CTMD. Batch cement and pump 20 bbls of 14.0 ppg squeezecrete and 24 bbls of 15.8 pg Class G cement. Lay in to 100' above the top pert. With 15 bble left in coil only an 880 psi bump over baseline injectivity was achieved so the remainder was laid in. Begin hesistation squeeze but after multiple breakdowns we were only able to achieve 1600 psi over baseline WHP. Slowly bleed whp to-440psi. Cleanout from WCTOC to flag at 10239 CTMD. Final Pressures: OA = 250 psi, IA = 1500 psi, TBG = 140 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water-Bbi Casing Pressure Tubing Pressure Prior to well operation: 164 1681 3772 885 193 Subsequent to operation: No Test Available 1500 140 14. Attachments: (mquiredper20MC25.mo.25.071,&25253) 15. Well Class after work: Daily Report of Well Operations IZ Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ I GSTOR ❑ 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: N/A Authorized Name: Stechauner, Bernhard Contact Name: Stechauner, Bernhard Authorized Title: G Lead P Contact Email: Bernhard.Stechaunerobp.com Authorized Signature: Date: 11115119 ' 19 i9 Contact Phone: +1 907 564 4594 Form 10-404 Revised 04/2917(//(41, (II�,Q.QL•�g�D�� /jam// Submit Original Only ' -) ✓ NOV 9 mmo Daily Report of Well Operations PBU N -11C ecTiviTvne TG ... .......... ***WELL S/I UPON ARRIVAL*** (cement squeeze) RAN 10'x 1.75" DRIVE DOWN BAILER TO 10,127' SLM (hard, no sample) RAN 10'x 2 1/2" DUMMY GUN (2.78" max od) DOWN TO 10,127' SLM (hard) RAN PDS 40 ARM CALIPER AS PER PROGRAM (good data) 12/10/2018 ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** CTU #9 - 2.0" Coil, 0.156" wt Job Objective: Mill CIBP, Cement Squeeze MIRU CTU. MU/RIH with BOT 3.70" 5 bladed, flat junk mill. (3.71go/3.70 no go). Tag CIBP 10146', milled/pushed to 10253' CTM, weight broke over 10246'. Town good with depth, POOH. Make up 2.5" BDJSN cementing BHA and RIH. 6/28/2019 ...Continued on WSR 6-29-19... CTU #9 - 2.0" Coil, 0.156" wt. ***Cont. from WSR 6-28-19*** Job Objective: Mill CIBP, Cement Squeeze Load well with 1% KCI and Diesel to underbalance. Tag TO at 10244' and paint blue/white TD flag at 10239' CTMD. Batch cement and pump 20 bbis of 14.0 ppg squeezecrete and 24 bbis of 15.8 pg Class G cement. Lay in to 100' above the top pert. With 15 bbis left in coil only an 880 psi bump over baseline injectivity was achieved so the remainder was laid in. Begin hesistation squeeze but after multiple breakdowns we were only able to achieve 1600 psi over baseline WHIP. Slowly bleed whp to-440psi. Cleanout from WCTOC to flag at 10239 CTMD, down, up, down. chase OOH at 80%. Jet all jewelry while pooh. FP well to 2800'. Jet bops/tree. Trap 300psi on the well. RDMO. 6/29/2019 ...Job complete... ***WELL S/I ON ARRIVAL***(cement squeeze) DRIFTED W/ 33'x 2-7/8" DUMMY GUN (max od = 3.15), 2-1/2" SAMPLE BAILER, TAG TD @ 10,219' SLM 10/7/2019 ***WELL S/O ON DEPARTURE*** ***WELL SHUT IN ON ARRIVAL*** PERFORATE 10,099'-10,132' ELMD WITH 2.875" MAXFORCE, 6 SPF, 60 DEG PHASED. RIH WITH 2ND PERF GUN, HANG UP AT 10,092' ELMD WHILE CORRELATING. LRS PUMPED 116 BBLS CRUDE TO FREE TOOLSTRING, POOH. 10/26/2019 ***JOB COMPLETE, HAND WELL TO PAD OP*** - 4"CMV \ogle = 44" 0 8431' n MD = HEAD= McEVOY 8800'SS 6 2-718" ATO'= AXELSON N -11C 40191 0629/19 1EV= 78.70' 0629/19 2-7/8' 40248 - 4ZUU' \ogle = 44" 0 8431' n MD = 10236' n TVD= 8800'SS 6 2-718" 3-3/8' CSG_ 72#. 1 -80. D = Minimum ID = 3.725" @ 9745' 4-1/2" HES XN NIPPLE WHIPSTOCK (08/08/04) 8307' 9-5/8'IZSVBP(Oa/08/04) 8323' 9-5/8' EZSV BP (08/08/04)9194' )P OF 7" LNR, 26#, L-80 (N-11 B)�- 9599' { TOP OF 2-7/8' LNR 9580' 4-1/2° TBG, 12.6#, L-80 9641' 9-5/8" CSG, 47#, L-80, D = 8.681° 985T PERFORATION SUMMARY REF LOG: RST ON 0828/04 ANGLE ATTOP PERF: 24" @ 10099' Node: Referto Production DB forhistorical oerfdata 2-7/8" 6L10213-10248 121 2-7/B' 60132 0629/19 2-7/8" 60141 6 2-718" 60141 0629/19 2-7/8' 40191 0629/19 2-7/8" 60191 0629/19 2-7/8' 40248 0629/19 DMY S 06/15/15 0629/19 S 04/18/06 0629/19 O 1026/19 6 S 0826/04 0629/19 S 01/16/06 0629/19 S 0828/04 0629/19 S 01/16/06 0629/19 SAFETY NOTES: PARENT WELL (N-11) NOT SHOW M•`4-112" CHROME TBG &LNR••• 2 -HES X NP, D=3.81' GAS LFT MANORS S ST MD TVD DEV I TYPE VLV LATCH I PORI DATE 6 3136 3136 0 MG DOME RK16 02/01/14 5 4505 4494 18 MdG DMY RK 0 08/16/041 4 5777 5504 47 M11G SO RK 20 02/01/141 3 7091 6443 41 M�1G OMY RK 0 08/16/04 2 8271 7339 43 KGB2 OMY BK 0 1226/12, 1 9486 8256 41 KGB2 DMY BK 0 02/01/14 19-5/8"X 7' BKR ZXP LNR HGR/TOP PKR. D = 6 281' 141V -t LNR CMTD 9-5/8" CSG MILLOUT WINDOW: 8308'-8324' 9980' 4-1/2' HES X NIP -15 —=3-8-1-3--1 4 S-3 PKR, D = NP, D=3.813' _�—� ELMD TT NOT LOGGED? 9753' 7' X 4-1/2' BKR ZXP LNR IT OP PKR, D = 5.010' 9773' RS PACKOFF SEAL NP, D = 4.25' 9775' 7" X 5- LNR HGR, D = 4.390 9785' 5' X 4-12" XO, D = 3.96' 01TBG, 9757' I \ 015252 D = bpf, = 3 3.99 58"8- LNR 26#, L-80,.0383 bpf, D = 6276' 991 g' 7oc (as2s/1s) 10239' CTM FISH: MILLED 4-12' BKR CIBP (628/19)10245' CTM 12.6#, r=C=7 PRUDHOE BAY UNIT WELL: N -11C PERMIT NO: '2041420 API No: 50-029-21375-02 SEC B. T11 N, R13E, 1023' FSL & 540' FWL DATE COMMENTS DATE REV BY COMMENTS 05/13181ORIGINAL COMPLETION 02104/14 DJS/JMD PULL WRP&XXN PLUG(02M2-03/14 1121199 SIDETRACK (N-1113) 0629/15 GTW/JMD ADPERFS(06/15/15) 08115/04 SIDETRACK (N -11C) MDJSIJMD 0222117 JMD WBS CLEAN UP 1228/12 GLV C/O & SETXXN PLUGTI; 0722/19 JCF/JMD MILL CIBP, SET FISH, CMTSQZ PERFS 01/02/14 JTSETWRP 1223113 10!!0/19 BTWJMD ADPERFS 1026119 SP Exploration (Alaska) 02/04/14 GLV C/O 02/01114) 11/18/19 DDUMDADDED OKB, REF, & BF ELEV STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMM N REPORT OF SUNDRY WELL OPERATIt,rIS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate Q Other Stimulate 0 Alter Casing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5 Permit to Drill Number: 204-142 3. Address: P.O Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-21375-02-00 7. Property Designation(Lease Number): ADL 0028283 8. Well Name and Number: PBU N-11C 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY.PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 10400 feet Plugs measured 10147 feet true vertical 9006 feet Junk measured feet Effective Depth: measured 10147 feet Packer measured See Attachment feet true vertical 8767 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor Surface See Attachment RECEIVED Intermediate Jul_ 14 2015 Production Liner AOGCC Perforation Depth' Measured depth: 9954-9959 feet 10081-10121 feet 10121-10141 feet 10151-10191 feet 10213-10248 feet True vertical depth: 8603-8606 feet 8706-8743 feet 8743-8761 feet 8771-8808 feet 8829-8861 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr8 25-9757 25-8458 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure' sCANN�.D IU , 2 8 2015 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 170 984 3432 1577 199 Subsequent to operation: 226 976 4506 1577 230 / 14.Attachments:(required per 20 AAC 25 070 25 07t,&25 283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ 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. I Sundry Number or N/A if C.O.Exempt: Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ,4 C __, Phone +1 907 564 4424 Date 7/14/15 Form 10-404 Revised 5/2015 V 7I, 71 21 1 1 7 RBDMs.S Onginal Only f/21/75--- JUL172015 Packers and SSV's Attachment PBU N-11 C SW Name Type MD TVD Depscription N-11C PACKER 8143.98 7246.21 7" Baker ZXP Top Packer N-11C PACKER 9700.67 8416.34 4-1/2" BakerS-3 Perm Packer N-11C PACKER 9753.34 8455.1 5" Baker ZXP Top Packer m Q. 00000 • N- c1 '- oo cO r� v �n �n C N IO N- r- 15 N o 0 0 0 0 i M N- -cr co co • O OD N V V m V CO I� 00 CO (O (O CO NI- aD CA (D N- O 10 CO M U0 O N r` 00 co co CO U) v- O d) V UC) QC) M M N N N N- a0 4-11 (D co a0 cp r` O O M CO M 6) O N CO 0) 6) (,) p U Q M O 6) t QC) U) a) ) M M N O) N • Z w (A • co Q, pCD CD O aO 00°O 00 UU 0) _ J J c) M M C 01NkJ *k* k U) N X r- a) (D (Q ci) O U N M - - - ' up N N coo'.) 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Datum TVD= 8800 SS ST ND TVT) DEV TYPE VLV LATCH PORT DATE 6 3136 3136 0 RANG DONE RK ` 16 02/01/14 5 4505 4494 18 NMG DMY RK r 0 08/16/04 13-3/8"CSG,72#,L-80,D=12.347' - 2696' ill4 5777 5504 47 MIG SO RK r 20 02/01/14 lin 3 7091 6443 41 MIG DMY FE r 0 08/16/04 2 8271 7339 43 KGB2 DMY BK ` 0 12/26/12 1 9486 8256 41 KGB2 DMY BK r 0 02/01/14 Minimum ID =3.725" @ 9745' 8144' H 9-5/8"x 7"BKR ZXP LNR HGR/TOP PKR,D=6.261" 4-1/2" HES XN NIPPLE !4 �� 8144' —HLnFtckmD )1 44 9-5/8"CSG MILLOUT WINDOW: 8308'-8324' i'4 1 •. WHPSTOCK(08/08/04) -{ 8307' .vs;� 9680' H4-1/2"HES X NP,D=3.813" ' \ •%C` 9701' -I r X 4-1/2"BKR S-3 PKR D=3.875' �••• ` 9724' H4-1/2'HES X NP,D=3.813" .4 lik s. N. , 9746' J-14-1P2"IES XN tom,D=3J25" 44 9-5/8"EZSV BP(08/08/04) - 8323' , 9767' _-j4-1/2"wLEG RIM Ti'NOT LOGGED? 9-5/8"EZSV BP(06/08/04) -{ 9194' 9753' -7"X 4-1/2'BKR ZXP LNR TOP OF CBuEYT(PEA 07/29/04) ---13-6(-F1 --.01111111111111111.- TOP PKR,D= " 9773' yPACKOFF5.010SEAL OW reee• 1RS 4.04NP,D=4.25' ►-741.0AVAIII,. , 9775' r X 5'LNR HGR, IWAWA! r D=4.390 TOP OF r LNR,26#,L-80(N-11B) 9699' ` 9785' 15°X 4-1/2"XO, ' :`�.':' rD=3.96' TOP OF 2-7!$"LNR H 9680' • III 4-1/2"TBG. 12.6#,L-80 9641' I=_ _ 10038' MARKER 9-5/8"CSG,47#,L-80,D=8.681" H 9867' I ` I JOINT Noir 2-7/8"LW,6.16#,L-80 11204' —'ssi4 • PERFORATION SUMMARY ` RIT LOG: FIST ON 08/28/04 4-1/2"TBG, 12.6#,13CR - 9757' .0152 bpf,ID=3.958" ` ANGLE AT TOP PERF:42"@ 9954' Nate:Refer to Production DB for historical pert data 7'LNR,26#,L-80,.0383 bpf,I)=6.276" - 9918' , , SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 2-7/8" 5 9954-9959 0 06/15/15 4-1/2"BKR CEP(4/18/06) -{ 10147' 2-78" 6 10081 -10121 0 04/18/06 2-7/8" 6 10121-10141 0 01/16/06 PB-TD H 10310' 114A1A\' 2-78" 4 10151-10191 C 08/28/04 \,,. 2-78" 6 10151 -10191 C 01/16/06 4-1/2"LNR, 12.6#,13CR,.0152 bpf,D=3.958' H 10398' 2-7/8" 4 10213-10248 C 08/28/04 DATE REV BY COM ENTS DATE REV BY CONIVENTS PRLCHOE BAY UNIT 05/13/81 ORIGINAL COMPLETION 111S/A/0_02/04/1111S/A/0 PULL WF2P&XXN PLUG(02102-03/14) WELL: N-11C 11/21/99 SIDETRACK(N-11B) 06/29/15 G1W/.M) ADPBPFS(06/15/15) PERMT No: 2041420 08/15/04 JDM/TLHSIDETRACK(N-11C) AR No: 50-029-21375-02 12/28/12 RKT/JMD GLV 00&SET XXN PLUG(12/26/12) SEC 8,Ti 1 N,R13E,1023'FSL&540'RAIL 01/02/14 JTG/JMD SET WRP(12/23/13) 02/04/14 DJS/JND GLV 00(02/01/14) BP Exploration(Alaska) PS m- ►( c Pr6 704-14-2_0 Regg, James B (DOA) From: Noble, Robert C (DOA) Sent: Monday, September 29, 2014 6:44 AM To: Regg, James B (DOA) f'7 Cc: Hill, Johnnie W (DOA); Herrera, Matthew F (DOA) Subject: FW:AOGCC Test Witness Notification Request: MIT, N-11 Attachments: IMG_0069 N-Pad 1.JPG;IMG_0070 N-Pad 3.JPG;IMG_0071 N-Pad 2.JPG;IMG_1215.JPG; IMG_1216.J PG Jim Matt sent this email with pictures of this AL line on PBU N-11 when he saw that we had a MIT out there. When I was out there I had Ryan Hayes call the DSO and I talked to him about the condition of the AL line. He said BP was well aware of the condition of the line. He also said that the line was de-pressured with both ends were blinded and locked. I confirmed that the well side was. I told him that line was not to be put in service without being repaired. I also added a couple more pictures to Matts. Bob Noble AOGCC 333 W. 7th Ave. Ste. 100 Anch AK. 99501 SCANNED APR 2 8 2015 Cell 907-299-1362 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Bob Noble at 907-299-1362 or bob.noble@alaska.gov From: Herrera, Matthew F (DOA) Sent: Saturday, September 27, 2014 4:45 PM To: Noble, Robert C (DOA); Hill, Johnnie W (DOA) Subject: FW: AOGCC Test Witness Notification Request: MIT, N-11 Gentlemen if either of you go out here... I found this on the way to P-Pa• e other day From: Ryan Hayes [mailto:noreply@aformresponse.com] Sent: Saturday, September 27, 2014 4:08 PM To: DOA AOGCC Prudhoe Bay; DOA AOGCC Prudhoe ::y Subject: AOGCC Test Witness Notification Reque . MIT, N-11 1 �f/ ?P3c& N—i, C P� 2.640Z4f) Regg, James B (DOA) From: Herrera, Matthew F (DOA) Sent: Tuesday, September 23, 2014 1:33 PM To: Regg, James B (DOA) Subject: N-Pad Pics Attachments: IMG_0069 N-Pad 1.JPG;IMG_0070 N-Pad 3.JPG;IMG_0071 N-Pad 2.JPG Jim On my way to test P-Pad I noticed this on the well row. I passed on to Pad Operator testing with me but think you may have to let them know you know about this situation.The well is N-11 currently shut in but still connected.The VSM is broken behind the header and flow line is all but on the ground. Matthew Herrera Petroleum Inspector Alaska Oil and Gas Conservation Commission 623-521-0945(Cell) Matthew.Herrera@alaska.gov 1 PBU N-11C (PTD 2041420)—Unsupported Flowline Photos by AOGCC Inspectors M. Herrera and B.Noble 9/23/2014—The following photos document what was observed at PBU N-11C while AOGCC Inspector Matt Herrera was on his way to witness a mechanical integrity test at PBU P-pad. The VSM is broken behind the header. Condition of the flowline was referred to the BPXA operator at P-pad and copy forwarded to AOGCC Inspection Supervisor Jim Regg. • . • • . • • • 110 arn" • • • 2014-0929_Flowline_PBU_N-11 C.docx Page 1 of 2 9/29/2014—While at the location, AOGCC Inspector Bob Noble and BPXA representative Ryan Hayes contacted the Drillsite Operator for PBU N-pad and I talked to him about the condition of the AL line. He said BPXA was well aware of the condition of the line. He also said that the line was de- pressured with both ends were blinded and locked. I confirmed that the well side was. I told him that line was not to be put in service without being repaired. Photos from Mr.Noble's visit: III 4 i ..:- t _ , : I % i )1`\''\, we 2014-0929_Flowline_PBU_N-11 C.docx Page 2 of 2 C,_ Image Project Well History File Cover Page c'-" XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. aQ l} - J !:f ~ Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: to ~ (Count does include cover sheet) Page Count Matches Number in Sca~r¡ing P'eparation: V YES (Maria ") Date: II 13 Ob If NO in stage 1 page(s) discrepancies were found: Organizing (done) o Two-sided 1111111111111111111 RESCAN DI5'TAL DATA \Ø'Diskettes, No. ~ o Other, NolType: o Color Items: o Greyscale Items: o Poor Quality Originals: o Other: NOTES: , llll,"~ ob . BY: (~ Maria.) Date: Project Proofing BY: L Maria) Date: // 13 Ob ~ X 30 = to D , ' Date: t I I(.~ Db Scanning Preparation BY: ç Maria ~ BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: o Rescan Needed 1111111111111111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: rY>~ 1111 Y'YV~ 151 II -I 151 + 1 = TOTAL PAGES {¿, '1 (Count does not include cover sheet! AWl II ') 151 / 1111111111111111111 NO 151 /IV¡J NO YES 151 1111111111111111111 11/1111111111111111 151 Quality Checked 11I11111111I111111I 10/6/2005 Well History File Cover Page.doc 05106/11 ScMumberger NO. 5738 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambelf Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD P2 -16 BBSK -00061 USIT /3 - 1(93 04/04/11 / L � 1 1 1- 35/0 -25 BBKA -00101 PRODUCT/ N PROFILE _ _/ If C/ 04/04/11 1 tor-7- 1 P2 -52 BJGT -00027 CROSS FLOW CHECK { J - — 04/14/11 1 G/( ,� 1 03 -37 BJGT -00028 INJECTION PROFILE () 0,....- -i 13C) 04/16/11 1 JJJG °/ 1 7.''''') 24211 -13 BAUJ•00076 MEM LDL / °JJ' / T 04/15/11 1 [ (e/ 1 N -11C 02 -12C BH4H -00048 PRODUCTION PR 8 _ ► 04/19111 1 1 B088 -00098 MEM CBL J (�,!" ^�, 04121/11 / 1 1 S -120 P1 -09 BD88 -00100 MEM INJECTION PROFILE () _r'(t .ice ,-(�O 04/25/11 1 (�q) 1 BJOH -00024 PRODUCTION PROFILE - 05/01/11 1 , _ . 1 • P1 -09 BJOH•00024 • • :.„,,b :.„,,b : -- O5102)11 !� 1 1 P2-43 BG4H -00049 SCMT i . - - 04/28/11 r , 1 -- 1 1 16.21 BJGT -00030 PRODUCTION PROFILE / 7 04/28/11 1 Col(,..,. 1 09 -26 8088 -00104 MEM LDL / *tr._ to 04/30/11 1 1 04 -33A BLPO -00095 MEM PRODUCTION PROFILE (')Li— Ca 2w 04130/11 1 14 If I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data 8 Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambelt Street, Suite 400 900 E. Benson Blvd Anchorage, AK 99503 -2838 • a „-,~ .~, _~„` MICROFILMED 03/01/2008. x- ~~, ,t. .~~: ~.: ,_ DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm_Marker.doc 17 DJ\¡;1J)~~ DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Permit to Drill 2041420 Well Name/No. PRUDHOE BAY UNIT N-11C Operator BP EXPLORATION (ALASKA) INC )~'IO ~~V API No. 50-029-21375-02-00 MD 10400 r TVD 9006 ,., Completion Date 9/17/2004 .....-- Completion Status 1-01l Current Status 1-01l UIC N REQUIRED INFORMATION Mud log No Samples No Directional SUNey Yes _~c DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR / PWD, MWD DIR / GR / RES (data taken from logs Portion of Master Well Data Maint Well Log Information: . Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments I ED ~~_.~ I Rpt D Asc Directional SUNey 8296 10400 Open 9/14/2004 IIFR Directional SUNey 8296 1 0400 <?pen 9/14/2004 IIFR lED D Asc Directional SUNey 8296 1 0400 Open 9/14/2004 MWD I: Directional SUNey 8296 10400 Open 9/14/2004 MWD C A&.ø L' ~ 12754 ReseNoir Saturation 10296 9300 Case 10/15/2004 ~g ReseNoir Saturation Blu 9300 1 0282 Case 10/15/2004 RST SIGMA RESERVOIR I SATURATION TOOL, DSN J}-..p it/I. (.,:L-... ~J\A¡'{.Y''J 12755 ¡ L.Q~ 127Z n9ieNoir C::"tllr"tir.>n Blu 9300 10?S2 Cove 1 0/16/200"1 pesT !=;1c.:MA RFSFRVOLR I SATURATION TOØl po D Lis 12784 Induction/Resistivity 8162 10354 Open 1 0/20/2004 MWD/GR/EWR4/ROP ~ LIS Verification 8162 10354 Open 1 0/20/2004 MWD/GR/EWR4/ROP/DSN 12784 . ,Pf' C Lis 13660 Induction/Resistivity 8308 10400 Open 2/22/2006 ROP DGR EWR plus Graphics Jog Production 5 Blu 9890 10250 Case 6/23/2006 PP, GR, CCl, PRES, TEMp, Gradio, IlS, FBS 9- Aug-2005 **REVISD #1** Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Permit to Drill 2041420 MD 10400 rvD 9006 ADDITIONAL INFORMATION Well Cored? ýfb¡) Chips Received? ...:;¡ / tJ Analysis Received? ~ _c ~ --~- Comments: Compliance Reviewed By: -~- DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Well Name/No. PRUDHOE BAY UNIT N-11C Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21375-02-00 Completion Date 9/17/2004 Completion Status 1-01L Current Status 1-01L UIC N Daily History Received? Y/N (])N Formation Tops -~ --~.~- ~ Date: ~-- ~ ~~ -=-== 3~ ~~ -- . . Schlumbel'gel' Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well '07-18 C-04A N-11 C MPF-89 D·10 NGI-09 MPH-09 MPH-15 MPS-90 AGI-07A 15-20C 18-30 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 \~ Job # 9153238 10649975 10980595 11084328 10913021 11212860 11211412 11076486 11162721 11212865 11075906 11209593 RECEiVED dUN 2 3 2006 ...~ ¡]I &. C~ CD!1S· ccmmisSicn Anchcrage \t1 'ð 1.-\ / 9D Log Description LDL SBHP SURVEY PRODUCTION PROFILE SCMT MUL TI·FINGER CALIPER USIT USIT CH EDIT PDC-GR OF USIT CH EDIT PDC·GR OF US IT CH EDIT PDC·GR OF USIT MCNL MCNL c~ Date 01/31/03 06/26/03 08/09/05 11/24/05 06/02/05 OS/23/06 05/28/06 12/15/05 11/27/05 OS/28/06 08/12/05 03/25/06 NO. 3854 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL Color 1 1 1 1 1 1 1 Prints sent earlier Prints sent earlier 1 CD 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503·2838 ATTN: Beth 06/20/06 . . . STATE OF ALASKA _ ~~ ALÄ OIL AND GAS CONSERVATION COM~ON ..,~ .h C'~ REPORT OF SUNDRY WELL OPERATIONS íI'~"QQ.. ü-t~ ì'~ 1. Operations Abandon D Repair Well D Plug Perforations 0 Stimulate D Other ~ () ,;; () Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extensiorrfhl~'" ~ (?06' Change Approved Program D Operat. Shutdown D Perforate 0 Re-enter Suspended Well [J'..I'.... ~ot ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number:V# ,. Name: Development ¡;a Exploratory 204-1420 ;r.ç,~ 3. Address: P.O. Box 196612 Stratigraphic D Service D 6. API Number: ~ Anchorage, AK 99519-6612 50-029-21375-02-00 7. KB Elevation (ft): 9. Well Name and Number: .')0 75.56 KB 8. Property Designation: ADL-028283 11. Present Well Condition Summary: Total Depth measured 10400 true vertical 9005.52 Effective Depth measured 10310 true vertical 8920.01 Casing Conductor Surface Production Liner Liner Length 80 2665 8294 1774 645 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 26# L-80 4-1/2" 12.6# 13Cr80 Perforation depth: Measured depth: 10081 - 10121 Open True Vertical depth: 8706.25 - 8742.89 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 239 234 x feet feet feet feet MD 32 - 112 31 - 2696 30 - 8324 8144 - 9918 9753 - 10398 10121 -10141 Open 8742.89 - 8761.41 4-1/2" 12.6# N-11C 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Plugs (measured) J.unk (measured) TVD 32 - 112 31 - 2695.98 30 - 7377.49 7246.22 - 8575.96 8454.85 - 9003.62 10151 - 10191 Closed 8770.69 - 8807.93 13Cr80 7" Baker ZXP Top Packer 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Mech Set L T Packer Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 960 6546 140 1328 5301 80 15. Well Class after proposed work: Exploratory Development ¡;a 16. Well Status after proposed work: Oil ¡;a Gas D WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal P'oled Name Shaema'oe Vestal _ / Signat~ ~ ORiGiNAL Form 10-404 Revised 04/2004 Title Data Mgmt Engr Phone 564-4424 10147 None Burst 1490 4930 6870 7240 8430 Collapse 470 2670 4760 5410 7500 10213 - 10248 Closed 8828.51 - 8861.41 28 - 9757 8144 9701 9753 RBDMS 8Ft .tUN 2 1 2DD6 Tubing pressure 460 300 Service GINJ WINJ WDSPL SUndry Number or N/A if C.O. Exempt: N/A Date 6/13/2006 Submit Original Only -.. . . N·11 C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 1 Diesel 1 TOTAL I ACTIVITYDATE I SUMM~âY 311 4/18/2006 ***CONTINUED FROM PREVIOUS DA Y*** CORRELATION LOG IS SPERRY-SUN MWD DATED 14-AUG-04 FIRED STRING SHOT FROM 10140' - 10152' SET 4.5" BAKER CIBP AT 10147' PERFORATED 10081' - 10121' WITH 2-7/8" PJ 2906 60 DEG 6 SPF GUNS API PENETRATION = 27.7", API HOLE DlAMTER = 0.36" COOH and at approximatley 8600' the line wiper malfunctioned. Stopped and assesed the situation and appield pressure on pack-off to wipe line while COOH. Pack-Off wiped line. No drips, No Spills. TURNED WELL OVER TO DSO. LEFT WELL SHUT IN. Head back to shop to rebuild Line Wiper/Pack-Off system. . STATE OF ALASKA . ALA: Oil AND GAS CONSERVATION COM, ION REPORT OF SUNDRY WELL OPERATIONS o o o \- 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Opera!. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 75.56 KB 8. Property Designation: ADL-028283 11. Present Well Condition Summary: Total Depth measured 10400 true vertical 9005.52 Effective Depth measured 10310 true vertical 8920.01 Casing Conductor Surface Production Liner Liner Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development (;.'1 Stratigraphic 0 RECEIVED Stimulate 0 Other 0 WaiverD Time Extension[fc.1:3 2 4 2006 Re-enter Suspended Well 0 . . on 5. Permit tcMtþ(Jjdf!; Gas COli:). Commt~1 Exploratory 204-1420 Anchorage Service 6. API Number: 50-029-21375-02-00 9. Well Name and Number: N-11C 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Oil Pool feet feet Plugs (measured) Junk (measured) None None feet feet Length Size MD TVD Burst Collapse 80 20" 91.5# H-40 32 - 112 32 - 112 1490 470 2665 13-318" 72# L-80 31 - 2696 31 - 2695.98 4930 2670 8294 9-5/8" 47# L-80 30 - 8308 30 - 7365.85 6870 4760 1774 7" 26# L-80 8144 - 9918 7246.22 - 8575.96 7240 5410 645 4-112" 12.6# 13Cr80 9753 - 10398 8454.85 - 9003.62 8430 7500 Perforation depth: Measured depth: 10121 - 10141 True Vertical depth: 8742.89 - 8761.41 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 206 210 x 10151 - 10191 8770.69 - 8807.93 10213 - 10248 8828.51 - 8861.41 4-1/2" 12.6# 13Cr80 28 - 9757 7" Baker ZXP Top Packer 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Mech Set L T Packer 8144 9701 9753 RBDMS 8Ft .2 '7 2006 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 965 4426 720 900 4504 720 15. Well Class after Droposed work: Exploratory Development p¡ 16. Well Status after proposed work: Oil p¡ Gas 0 WAG Tubing pressure 340 280 Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. GINJ WINJ WDSPl 0 I Sundry Number or N/A if C.O. Exempt: N/A Printed Name Sharm~ine Vestal _ /. _ Signat~~7PøJ Contact Sharmaine Vestal Form 10-404 Revised 04/2004 Title Data Mgmt Engr Phone 564-4424 Date 2/22/2006 ORIGINAL Submit Original Only ~- . . j N-11 C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I ,swßtÌßtÌAm){ J 1/16/2006 CORRELATED TO SCHLUMBERGER RST SIGMA LOG DATED 28-AUG- 2004 PERFORATED 10121' -10141',10151'-10191' WITH 2-7/8" GUN LOADED WITH 2906 PJ OMEGA CHARGES ALL SHOTS FIRED SUCCESSFULLY FLUIDS PUMPED BBLS 1 Diesel 1 TOTAL . . WELL LOG TRANSMITTAL () 04- 14d-. To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 J3(p{PD RE: MWD Formation Evaluation Logs N-IIC, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 N-llC: LAS Data & Digital Log Images: 50-029-21375-02 1 CD Rom ~ ~J ~E1[f)(P A . STATE OF ALASKA . ALASð OIL AND GAS CONSERVATION COrJllrSSION ..",>. ~ REPORT OF SUNDRY WELL OPERATION.$ 1. Operations Performed: Abandon 0 Alter CasingD Change Approved Program D RepairWellD Pull TubingD Operation ShutdownD Plug PerforationsD Perforate New Pool 0 Perforate 0 Stimulate ŒI WaiverD OtherD Time Extension D Re-enter Suspended WellD 5. Permit to Drill Number: 204-1420 6. API Number 50-029-21375-02-00 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development [!] ExploratoryD P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 75.56 8. Property Designation: ADL-028283 11. Present Well Condition Summary: Stratigraphic 0 ServiceD 9. Well Name and Number: N-11 C 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Total Depth measured 10400 feet true vertical 9005.5 feet Effective Depth measured 10310 feet true vertical 8920.0 feet Plugs (measured) None Junk (measured) None Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 32 112 32.0 112.0 1490 470 LINER 1774 7" 26# L-80 8144 . 9918 7246.2 - 8576.0 7240 5410 LINER 645 4-1/2" 12.6# 13Cr80 9753 - 10398 8454.9 - 9003.6 8430 7500 PRODUCTION 8294 9-5/8" 47# L-80 30 - 8324 30.0 - 7377.5 6870 4760 SURFACE 2665 13-3/8" 72# L-80 31 . 2696 31.0 - 2696.0 4930 2670 Perforation depth: Measured depth: 10121 -10141,10151 -10191,10213 -10248 True vertical depth: 8742.89-8761.41,8770.69 - 8807.93, 8828.51-8861.41 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 28 9757 RBDMS 8Fl JUN 2 2 2005 Packers & SSSV (type & measured depth): 7" Baker ZXP Top Packer @ 8144 4-1/2" Baker S-3 Perm Packer @ 9701 4-1/2" Baker ZXP Mech Set L T P @ 9753 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10121-10141,10151-10191,10213-10248 Treatment descriptions including volumes used and final pressure: 537 bbls 2% KCL, 73 bbls 12% /90:10 DAD Acid. CTU Final Pressure - 3433 psi. Prior to well operation: Subsequent to operation: Oil-Bbl 330 211 Representative Daily Averaae Production or Injection Data Gas-Met Water-Bbl Casing Pressure 1151 475 0 1752 3733 0 Tubing Pressure 198 266 13 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oi/Œ] GasD Development ŒI ServiceD Signature DeWayne Schnorr DeWayne Schnorr A~ ß(J~ WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 SUndry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Petroleum Engineer Phone 564-5174 Date 6/16/05 Form 10-404 Revised 4/2004 L . . N-11 C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/03/05 CTU #5, ACID TREAT; MIRU DS CTU #5. LOAD WELL WITH 235 BBLS OF FILTERED 2% KCL. RIH WITH 3.0" JOUST SIDE JET NOZZLE. 05/04/05 CTU #5,ACID TREAT; ACID TREAT; LOAD WELL WITH 1.5 X 2% FILTERED KCL, TAG SHALLOW 9' INTO PERFS. SPOT 20 BBLS ACID AT OBSTRUCTION. BROKE THROUGH BRIDGE. CONTINUE DOWNHOLE PUMPING ACID. UNABLE TO PULL UP HOLE. PUMP DOWN BACKSIDE, PULL FREE. PULL UP HOLE ABOVE PERFS. LOAD BACKSIDE WITH 100 BBLS DEAD CRUDE. PUMP 20 BBLS ACID WHILE JETTING DOWN THROUGH PERFS, ON BOTTOM, 11 BBLS ACID OUT NOZZLE, STUCK PIPE, SWITCH TO PUMP METH DOWN BACKSIDE, WHILE WORKING PIPE. PULL FREE. PARK NOZZLE ABOVE PERFS AND PUMP REMAINING 9 BBLS ACID OUT NOZZLE AND LET SOAK FOR 15 MINUTES. DECIDED NOT TO GO INTO PERFS AND TAKE THE CHANCE OF GETTING STUCK. PARK NOZZLE ABOVE TOP PERF 10100' CTM AND PUMP REMAINING 35 BBLS ACID INTO PERFS. DISPLACE ALL ACID OUT NOZZLE AND LET SOAK FOR 15 MINUTES. OVERFLUSH ACID WITH 150 BBLS FILTERED 2% KCL WITH NOZZLE PARKED ABOVE PERFS. FREEZE PROTECT COIL WITH 35 BBLS. POOH PUMPING METH DOWN BACKSIDE. HANDED WELL OVER TO ASRC TESTERS FOR FLOWBACK. *** JOB COMPLETE *** 05/06/054 HOUR TEST. CORRECTED GROSS FLUID RATE 2936.3 STBFPD. CORRECTED OIL RATE 265.1 STBFPD. CORRECTED FORMATION GAS RATE 0.165 MMSCFPD. NET WATER RATE 2671.2 BWPD. LIFT GAS RATE 2.16 MMSCFPD. WHP 444 PSI. CHOKE 176 BEANS. AVERAGE WIC 90.4% FLUIDS PUMPED BBLS 121 60/40 Methanol Water 537 2% KCL Water 96 Crude 73 12% / 90:10 DAD Acid 827 TOTAL Page 1 I V\lE:LLHI:AD = ACTUA TOR = KB. ELEV = , SF. ELEV = KOP= Max Angle = Datum MD = Daturñ-TVD = Mc~VOY AXELSON 75.5' 46.95' 4200' -47~5800' 10,400' 8930' SS ~ 13-3/8" CSG, 72#, / L-BO, 10 = 12.347" 2696' Bottom of Whipstock _ (9-5/8" Exit Point) -8324' Top Bridge Plug -8320' - N-11.ctual Completion - S.'Cmt'd D ~L~ - t)Q.~fT· Bottom of EZSV -9220' - ... ......... Chemical Cut -9230' ~ Top Cement -9350' 9-5/8" CSG, 47#, L-80, 10 = 8.681" 9867' ~ 4-1/2" HES X-Nipple to = 3.813" -2100' 6 3136 3136 0 5 4504 4500 3 4 5777 5500 46 3 7091 6450 41 2 8270 7350 43 1 9485 8250 41 CAMeO CAMCO CAMCO CAMCO CAMCO CAMCO OCR RKP 1.5" 816/2004 DUM RK 1.5" 816/2004 DUM RK 1.5" 816/2004 DUM RK 1.5" 816/2004 DUM SK 1" 816/2004 DUM BK 1" 816/2004 4-1/2",12.6#, 13CR TBG, 10 = 3.958" ~ Top of r, 2611 LNR - 8144' ~.1/2" HES X Nipple, 10 = 3.813" - 9,680' 7" x 4-1/2" 5-3 Packer - 9,700' 4-1/2" HES X Nipple, ID = 3.813" - 9.724' 4-1/2" HES XN Nipple, ID = 3.725" - 9,745' 4-112" WLEG - 9757' 4-1/2" LNR Hanger/ZXP - -9753' 7",26# L-80 LNR -9918' 4-1/2", 12.6#, 13CR LNR, ID = 3.958" 4-1/2" Landing Collar -10,309' 4-1/2" Float Collar -10398' 4-1/2" OTIS XA SLIDING SLY, 10 = 3.813" 9446' TIW TBG Seal Assy 9508' 9-5/8" x 4-1/2" TIW HBBP PKR 9523' Tubing Punch (4 SPF) 9547'·9557' Top 7" LNR 9599' 4-1/2" TBG TAIL, 10 = 3.958" 9641' I 9647' HSKR CIBP (08/26/03) I APparent Parted liner @ 9925' and 10089' I ____ from POS long run on July 3, 2003. !Ô1 Millout Window 9902'-9906'1 /1".forAtìo'l?S - AI-/IC (Ó1-17-0~ L.88 bSfØF OPA./ /o/Z/- /o/<V/ " " "/01 S 1- 10/9/ If " II /0 :<./.53 - /o~ "18 7" LNR, 26#, I I L-80, IJ45 9902' _ PBTD -i 11168' 2-7/8"LNR, 6.16#, L-80, .00579 bpf,/D= 2.441" H 11204'1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 05/13/81 ORIGINAL COMPLETION 08/24/03 KF/KAK SAND DUMP WELL: oN-++e ,1/-// C 11/21/99 SIDETRACK (N-11B) 08/26/03 BJMlKK SET IBP; TBG PUNCH PERMIT No: ~ :¿oW1'.2 0 03/09/02 RNlTP CORRECTIONS 05/14/04 KWA Proposed Completion (N-11 C) API No: 50-029-21375-"" OZ 07/16/03 BJMcLITLH SET IBP 08/16/04 AM/SO ACTUAL COfvf'l.ETION (N-11 C) see 8. T11N, R13E, 1023' FSL & 540' F'M. 08/17103 MWffiH LNR TOP PKR & DATUM UPDATE 08/20/03 JJffiH PULL IBP I BP exploration (Alas ka) . . A "í.. /;( (;J if -/t 2 v/- WELL LOG TRANSMfITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Wannan 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 October 11, 2004 RE: MWD Formation Evaluation Logs: N-11 C, AK-MW-32 1 8334 1 LDWG formatted Disc with verification Jisting. llPI#: 50-029-21375-02 I ¡. Î ~i .-/ ..../ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Attn: Rob KaJish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP ExpJoration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Daìe/~fí qdf~ RECEIVED OCT 2 C 2004 AJæka Oil &. Gas Coos. Commi$$ion .A.n..4'Iorage RËee~Vr:b OCT 1 ~32004 & Cons. Commission 1b. Well Class:Ä¡lLhúHSY¡: a Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-142 13. API Number 50- 029-21375-02-00 14. Well Name and Number: I STATE OF ALASKA a ALASKA L AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: a Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 One Other 5. Date Comp., Susp., or Aband. 9/17/2004 6. Date Spudded 8/10/2004 21. Logs Run: MWD DIR 1 GR 1 PWD, MWD DIR 1 GR 1 RES CASING, LINER AND CEMENTING RECORD SETTINGÐ~PTHMÞ SETTINGÐEPTKWP BOTTOM BOtToM 100' Surface 100' 2697' Surface 2697' 8308' Surface 7366' 9918' 7246' 8576' 10398' 8455' 9004' o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1023' NSL, 540' EWL, SEC. 08, T11 N, R13E, UM Top of Productive Horizon: 2063' SNL, 399' WEL, SEC. 18, T11N, R13E, UM Total Depth: 2073' SNL, 508' WEL, SEC. 18, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 634409 y- 5966927 Zone- ASP4 TPI: x- 633536 y- 5963825 Zone- ASP4 Total Depth: x- 633428 y- 5963813 Zone- ASP4 18. Directional Survey a Yes 0 No No. of Completions 22. 20" x 30" WT. PER FT. Insulated 72# 47# 26# 12.6# Conductor L-80 L-80 L-80 13Cr80 Surface Surface Surface 8144' 9753' 13-3/8" 9-5/8" 7" 4-1/2" 23. Perforations open to Production (MD + TVD of TOE and Bottom Interval, Size and Number; if none, state' none"): 2.88" Gun Diameter, 6 spf MD TVD MD TVD 10121' -10141' 8743' - 8761' 10151' -10191' 8771' - 8808' 10213' - 10248' 8829' - 8861' 26. Date First Production: September 17, 2004 Date of Test Hours Tested PRODUCTION FOR 10/12/2004 4 TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED -Air... Press. 241 1,160 24-HoUR RATE7 7. Date T.D. Reached 8/13/2004 8. KB Elevation (ft): 75.56' 9. Plug Back Depth (MD+ TVD) 10310 + 8920 10. Total Depth (MD+TVD) 10400 + 9006 11. Depth where SSSV set (Nipple) 2100' MD 19. Water depth, if offshore NIA MSL 36" 17-1/2" 12-1/4" 8-1/2" 6-1/8" 24. SIZE 4-1/2", 12.6#, 13Cr80 PBU N-11C 15. Field 1 Pool(s): Prudhoe Bay Field 1 Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028283 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 8 cu yds Concrete 3720 cu ft Permafrost 'E' and PF 1883 cu ft Class 'G', 230 cu ft 'G' 393 cu ft Class 'G' 135 cu ft Class 'G' DEPTH SET (MD) 9757' PACKER SET (MD) 9701' DEPTH INTERVAL (MD) 2200' AMOUNT & KIND OF MATERIAL USED Freeze Protect with 151 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Gas Lift OIL-BsL GAs-McF WATER-BsL 251 399 142 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". N /1r-::. ,.Oi¡'¡.T.0.,.;·:··...·......·.. one ~~: ¡i ~". - 'J 'l ;;JJß¡;Jl j Form 10-407 Reviseð 12/2003 OIL-BsL 1,504 27. GAs-McF 2,392 W A TER-BsL 852 CHOKE SIZE I GAS-OIL RATIO 1760 1,590 OIL GRAVITY-API (CORR) 25.7 OR\G\NAL ---~ ~ CONTINUED ON REVERSE SIDE ~ (,¡; ?8. GEOLOGIC MARKERS. 29. eRMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 9924' 8580' None Shublik 9969' 8614' Sadlerochit 10084' 8709' Zone 3 10285' 8896' 30. list of Attachments: Summary of Daily Drilling Reports and Post-Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed TerrieHubble /fÓ~ ~ Title Technical Assistant Date 10-13 "öLf PBU N-11C 204-142 Prepared By NamelNumber: TeffieHubble, 564-4628 Well Number Drilling Engineer: Ken Allen, 564-4366 Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IrEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. 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 Legal Name N-11 B Common Name: N-11 B 8/9/2004 FIT 8/13/2004 FIT 4,779 (psi) 12.50 (ppg) 4,457 (psi) 10.00 (ppg) . . Printed: 8/23/2004 9:26:36 AM 612 (psi (psi 670 0.90 (ppg) 8.50 (ppg) 7,360.0 (ft) 8,576.0 (ft) 8,308.0 (ft) 9,918.0 (ft) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-11B N-11B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 8/5/2004 Rig Release: 8/16/2004 Rig Number: Spud Date: End: 8/16/2004 8/6/2004 18:00 - 22:00 4.00 MOB P PRE Rig down. Disconnect lines at pits/sub interconnect Move out pits. Move Rig from N-O. Spread hurculite over mats in N-11 C cellar area. Move and spot pits. 22:00 - 00:00 2.00 MOB P PRE Move truck shop, parts house and camp. Install grating and spill containment around well head in cella, berm around cellar. Connect pits and sub at interconnect Accept rig at 00:00 hrs 8/7/2004 8/7/2004 00:00 - 03:00 3.00 WHSUR P DECOMP RIG ACCEPTED @ 00:01 HRS 8/7/2004. Take on seawater. R/U secodary annulus valve. Check pressures on IA and OA - both '0'. 03:00 - 03:30 0.50 WHSUR P DECOMP RlU DSM lubricator & Pull BPV. Tubing pressure = '0' 03:30 - 06:00 2.50 CLEAN P DECOMP R/U to circulate out freeze protection diesel. Pump 35 bbl seawater down annulus taking diesel returns up tubing. Switch and pump 155 bbl hot (120 F) seawater down tubing taking diesel returns up annulus until clean. Monitor well - static. RID & blow down circulating lines. 06:00 - 06:30 0.50 WHSUR P DECOMP Install two way check valve (TWC). Test from below to 1000 psi - OK. 06:30 - 07:30 1.00 WHSUR P DECOMP N/D Tree & adapter flange. Remove from cellar. Test for N.O.R.M.= 0.2 TO 0.3 uRem/hr. 07:30 - 09:00 1.50 WHSUR P DECOMP Inspect Tubing Hanger. Threads OK. Work LDS. One lock down screw frozen.- had to grind off end of LDS form insde of tubing head bowl. 09:00 - 11 :00 2.00 BOPSUF P DECOMP N/U Spacer Spool & BOPE. 11 :00 - 15:30 4.50 BOPSUP P DECOMP Test BOPE to 250 psi. Low & 3500 psi. High. Test all but Lower Rams. Will test after pulling tubing. This autorized by Lou Grimaldi, AOGCC, who also waived witness of test 15:30 - 17:00 1.50 WHSUR P DECOMP Blow down choke, choke lines & Top Drive. R/U DSM lubricator & pull TWC. 17:00 - 18:00 1.00 PULL P DECOMP M/U landing Jt & screw into Hanger. B.O.L.D.S. Pull Hanger & string to floor w/140K up wt. Well static. UD Landing jt & Hanger. 18:00 - 20:00 2.00 CLEAN P DECOMP Circulate bottoms up with seawater @ 7 BPM 1320 psi. No gas - No solids. RlU Camco control line spooler and hold PJSM with all hands. 20:00 - 22:30 2.50 PULL P DECOMP POH & Lay Down 53 Jts 4.5" tbg + SSSV assembly. Recovered 26 Clamps + 4 SS Bands. 22:30 - 23:00 0.50 PULL P DECOMP RID Camco spooling unit & move off floor. 23:00 - 00:00 1.00 PULL P DECOMP Continue POH, Laying Down Tubing. 8/8/2004 00:00 - 05:30 5.50 PULL P DECOMP Continue POH. Laying down 41/2" Tubing and completion tools. Total 229 Jts + 18.94 ft. Cut-off. R/D Tubing Tongs. Clear & clean floor. NOTE: Tubing is badly pitted and eroded, some joints with holes. Tubing cut 100% with chemical cutter. 05:30 - 06:30 1.00 BOPSUP P DECOMP Rig up and test lower Pipe Rams to 250 psi Low and 3500 psi High. Install wear bushing. 06:30 - 07:30 1.00 CLEAN P DECOMP Rig up Schlumberger Eline unit 07:30 - 10:15 2.75 CLEAN P DECOMP Run 8" gauge ring and junk basket on Eline to top of cut 4 1/2" Printed: 8/23/2004 9:26:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-11 B N-11 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 8/5/2004 Rig Release: 8/16/2004 Rig Number: Spud Date: End: 8/16/2004 8/8/2004 07:30 - 10:15 2.75 CLEAN P DECOMP tubing at 9225' (Eline mesurement). Recover half a bucket of trash. 10:15 - 16:00 5.75 DHB P DECOMP Run and set one 9 5/8" EZSV bridge plug at 9194' and second one at 8323' 16:00 - 16:30 0.50 DHB P DECOMP Rig down Schlumberger Eline unit. 16:30 - 17:30 1.00 DHB P DECOMP Test 9 518" casing and EZSV bridge plug to 3500 psi for 30 minutes. 17:30 - 18:45 1.25 STWHIP P WEXIT M/U Milling Assy & MWD of 9 5/8" Whipstock BHA #1. 18:45 - 20:00 1.25 STWHIP P WEXIT Orient, Up-Load and Shallow Test MWD. 20:00 - 22:30 2.50 STWHIP P WEXIT Pick up Whipstock and pin to Milling Assy. Continue to P/U DC's, HWDP and Bumper Sub. 22:30 - 00:00 1.50 STWHIP P WEXIT RIH picking up 4" DP from Shed. 8/9/2004 00:00 - 01 :30 1.50 STWHIP P WEXIT Continue RIH with Whipstock, picking up 4" drill pie from shed. 01 :30 - 03:30 2.00 STWHIP P WEXIT RIH with stands out of derrick to 8120'. 03:30 - 04:30 1.00 STWHIP P WEXIT Connect blower hose to top drive. Break circulation and bring pumps up to 500 GPM @ 2110 psi. Orient tool face. 04:30 - 05:00 0.50 STWHIP P WEXIT RIH and set Whipstock anchor on EZSV @ 8,331', Driller's Depth. Tool face orientation @ 71 Deg Right. Shear off Milling assy. 05:00 - 06:00 1.00 STWHIP P WEXIT Displace well from seawater to 10.9 ppg LSND Milling fluid. 06:00 - 12:30 6.50 STWHIP P WEXIT Mill 8 1/2" window in 9 5/8" casing from 8308' to 8324'. Drill to 8338' to pass mills through window. 12:30 - 13:30 1.00 STWHIP P WEXIT Circulate around 55 bbl high vis sweep with SuperSweep fibers. Noted added metal shavings in sweep. Total1711bs metal recovered from milling operation. 13:30 - 14:30 1.00 STWHIP P WEXIT Perform FIT at 9 5/B" window at 8308' MD, 7360' TVD, 612 psi, EMW 12.5 ppg. 14:30 - 17:30 3.00 STWHIP P WEXIT POH, standing back DP, to BHA. 17:30 - 19:30 2.00 STWHIP P WEXIT Stand Back HWDP, UD DC's & Milling Assy. Upper Mill full gauge. 19:30 - 21 :00 1.50 BOPSUF P 'WEXIT Pull Wear Bushing. P/U jetting tool and flush stack & tubing head. Install Wear Bushing. 21 :00 - 23:00 2.00 STWHIP P WEXIT P/U 8 1/2" directional drilling BHA # 2. RIH with 4" HWDP from derrick. Shallow test MWD. 23:00 - 00:00 1.00 STWHIP P WEXIT Continue RIH with BHA #2, picking up 4" drill pipe from shed. 8/10/2004 00:00-01:15 1.25 STWHIP P WEXIT Continue picking up 4" drill pipe from shed, RIH with BHA # 2. 01:15 - 03:00 1.75 STWHIP P WEXIT Continue RIH with stands from derrick to 8,212'. 03:00 - 04:15 1.25 STWHIP P WEXIT Service Top Drive & Crown. Slip & Cut Drilling Line 152'. Install blower hose on top drive. 04:15 - 05:30 1.25 STWHIP P WEXIT Take SPR's. Take ECD Baseline readings. Orient Tool Face to 70 deg. right, shut down pumps and slide through window with no problem. Tag @ 8332'. Stage up pumps to 500 GPM. Ream under gauge hole from 8332' to 8338' 05:30 - 00:00 18.50 DRILL P INT1 Directional Drill 8 1/2" Hole from 8,338' to 9'647'.510 GPM I 3330 psi. WOB = 8 to 15K, P/U Wt = 185K, Dn Wt. = 155K, ROT Wt = 169K, Torque on bottom = 6.5K, Off bottom = 4.5K Rotating @ 70 RPM. Calculated ECD = 11.4 ppg. Actual ECD = 11.54 ppg AST = 6.91 Hrs., ART = 6.33 Hrs. Control drilling to limit ROP to 100 ft / hr as per program. Pumped sweeps @ 8,736' & 9,265' - saw no increase in cuttings at shakers. 8/11/2004 00:00 - 03:30 3.50 DRILL P INT1 Directional Drill 8 1/2" Hole from 9,674' to 9'915'. 500 GPM / 3450 psi. WOB = 10 to 15K, P/U Wt = 195K, Dn Wt. = 160K, ROT Wt = 169K, Torque on bottom = 6 K, Off bottom = 4.5K, Printed: 8/23/2004 9:26:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-11 B N-11 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 8/5/2004 Rig Release: 8/16/2004 Rig Number: Spud Date: End: 8/16/2004 8/11/2004 00:00 - 03:30 3.50 DRILL P INT1 Rotating @ 80 RPM. Calculated ECD = 11.4 ppg. Actual ECD = 11.54 ppg Control drilling to limit ROP to 100 ft / hr as per program. 03:30 - 04:30 1.00 DRILL P INT1 Circulate Bottoms Up for samples at Geologist request. 04:30 - 04:45 0.25 DRILL P INT1 Drill an additional 5 ft to 9,920' with same parameters. 04:45 - 06:00 1.25 DRILL P INT1 Circulate Hi-Vis, weighted Sweep @ 520 GPM / 3405 psi. & 100 RPM. 06:00 - 07:00 1.00 DRILL P INT1 POH to 8,212'. No Problems. 07:00 - 07:30 0.50 DRILL P INT1 SeNice Top Drive & Crown. 07:30 - 08:30 1.00 DRILL P INT1 RIH to 9,838. Wash & Ream to 9,920' - No Fill. 08:30 - 10:00 1.50 DRILL P INT1 Pump Hi-Vis Sweep. Circulate @ 520 GPM / 3360 psi. Shakers Clean. 10:00 - 15:45 5.75 DRILL P INT1 POH to 9,169'. Take sUNeys @ 9,137' & 9,106'. Pump Dry Job & Drop 2.5" rabbit w/ tail. Continue POH. MAD Pass from 8,400' to 8'200' as per Geologist request. Continue POH & stand back HWDP. 15:45 - 18:30 2.75 DRILL P INT1 UD DC's. Down load MWD & pull probe. UD MWD, Float sub, stab & motor. Clear & clean floor. 18:30 - 19:30 1.00 CASE P INT1 R/U to run 7" Liner. PJSM with Rig Crew & SeNice Hands. 19:30 - 22:15 2.75 CASE P INn Run 42 Jts, 7", 26#, L-80, BTC-M Liner as per program. 22:15 - 23:00 0.75 CASE P INT1 M/U Hanger / Packer Assy. + 1 stand 4" DP. Circulate One Liner Volume. 23:00 - 00:00 1.00 CASE P INT1 RIH with 7" Liner on 4" DP stands from derrick. 8/12/2004 00:00 - 03:00 3.00 CASE P INT1 Continue RIH with 7" Liner on 4" DP to 8,294'. 03:00 - 03:30 0.50 CASE P INT1 Circulate DP & Liner capacity (148 BBLS), staging pumps up to 8 BPM @ 1037 psi 03:30 - 05:00 1.50 CASE P INT1 Run in open hole with 7" Liner on 4" DP to bottom @ 9920. 05:00 - 07:00 2.00 CASE P INT1 P/U and M/U cement hoses and circulation system. Stage I pumps up to 8 BPM and circulate/condition mud for cement 1.25[ CEMT job. PJSM with Cementers. 07:00 - 08:15 P INT1 Switch over to Dowell and Cement as follows: Pump 2 Bbls water and pressure test lines to 4000 psi. Mix & pump 38 Bbls of 11.9 ppg MudPush @ 3.5 BPM. Mix & Pump 72 Bbls (339 sX), 15.8 ppg, class "G" Slurry @ 5 BPM. Kick plug out with 5 Bbls water. Switch back to rig pumps and displace with 141 Bbls 11.1 ppg Mud @ 8 BPM, slowing to 3 BPM to latch. Final pres. 942 psi. Bump Plug w/ 3500 psi to set Hanger. 08:15 - 08:30 0.25 CASE P INT1 Set down 40K to confirm 'HMC' Liner Hanger set. Bleed off pressure & rotate 15 turns to right. Pressure up to 1000 psi and pick up out of seals. At loss of pressure: pump 15 Bbls at 5 BPM to send cement up annulus. Set down 70 K rotating @ & RPM to set 'ZXP' Packer. 08:30 - 10:00 1.50 CASE P INT1 Circulate out cement @ 7 BPM. ObseNed srnall increase in Ph and some cement contaminated mud to surface. 10:00 - 10:30 0.50 CASE P INT1 Rig Down Circulating manifold & Baker plug dropping cement head. 10:30 - 13:00 2.50 CASE P INn POH 13:00 - 14:30 1.50 CASE N RREP INT1 Long awaited National Oilwell engineer on location. Trouble shooting Auto - Driller. 14:30 - 15:30 1.00 CASE P INT1 POH. UD Baker C-2 Liner running tool. 15:30 - 16:30 1.00 DRILL P PROD1 Pick up & M/U 6 1/8 BHA # 3. 16:30 - 17:00 0.50 DRILL P PROD1 Orient MWD & Motor. Up-Load MWD. 17:00 - 19:45 2.75 DRILL N RREP PROD1 Repair Auto-Driller Printed: 8/23/2004 9:26:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-11 B N-11 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: Rig Release: Rig Number: 8/5/2004 8/16/2004 Spud Date: End: 8/16/2004 8/12/2004 19:45 - 20:45 1.00 CASE P INT1 R/U and test 7 " Liner under blind rams to 3500 psi. Hold & Chart for 30 minutes. bleed pressure & R/D. 20:45 - 21 :45 1.00 DRILL P PROD1 Complete P/U BHA #3. Shallow test MWD, RIH w/ HWDP from derrick. 21 :45 - 22:30 0.75 DRILL P PROD1 RIH to 2,658'. 22:30 - 23:45 1.25 DRILL N RREP PROD1 Calibrate Auto-Driller 23:45 - 00:00 0.25 DRILL P PROD1 Continue RIH w/ BHA #3. 8/13/2004 00:00 - 02:30 2.50 DRILL P PROD1 RIH to 9,641'. 02:30 - 03:00 0.50 DRILL P PROD1 Service Top Drive & install blower hose. 03:00 - 04:45 1.75 DRILL P PROD1 Wash & Ream down to 9,785' Tag cement. Drill cement stringers to Landing Collar @ 9832. Drill Landing collar & hard cement to 9,910'. Drilling w/10 to 17 K WOB. 230 GPM @ 1600 psi, 40 RPM 04:45 - 07:00 2.25 DRILL P PROD1 Pump Hi-Vis sweep & displace with 8.4 ppg FloPro Mud, 233 GPM @ 1180 psi. 07:00 - 07:45 0.75 DRILL P PROD1 Drill Shoe and 20' of new hole to 9,940'. 07:45 - 08:45 1.00 DRILL P PROD1 Circulate clean & perform FIT. TVD = 8,570', Mud Wt = 8.5 ppg, Surface Pressure = 670 psi. FIT = 10.0 ppg EMW. 08:45 - 18:00 9.25 DRILL P PROD1 Directional Drill 6 1/8" Hole from 9,940 to 10,400' - TD. 262 GPm @ 1560 psi, WOB = 15 to 35 K, TQ = 7 K P/U Wt. = 220 K, Dn Wt = 150 K, Rot Wt = 173 K, AST = 3.6 Hrs., ART = 3.39 Hrs. 18:00 - 18:30 0.50 DRILL P PROD1 Pump Hi-Vis Sweep into 9 5/8" Casing. 18:30 - 19:00 0.50 DRILL P PROD1 Pump out of hole to 7" shoe @ 9,918' at full drilling rate - 262 GPM. 19:00 - 19:30 0.50 DRILL P PROD1 Service Top Drive. 19:30 - 20:00 0.50 DRILL P PROD1 RIH to 10,309. No Problems. Precautionary wash to bottom @ 10,400. 20:00 - 22:00 2.00 DRILL P PROD1 Circulate Hi-Vis Sweep, Surface to Surface @ 260 GPM, rotating @ 80 RPM. 22:00 - 23:30 1.50 DRILL P PROD1 POH to position Cric Sub @ Top of 7" Liner @ 8,144'. 23:30 - 00:00 0.50 DRILL P PROD1 Drop Ball and open Circ. Sub. Pump Hi-Vis Sweep @ 525 GPM & 1200 psi. 8/14/2004 00:00 - 00:30 0.50 DRILL P PROD1 Circulate out Sweep @ 525 GPM - fair amount of sand over shakers - cleaned up well. 00:30 - 03:00 2.50 DRILL P PROD1 POH standing back 4" DP to HWDP. 03:00 - 04:30 1.50 DRILL P PROD1 Lay down HWDP,Circ. Sub, Flex Collars, Jars. Drain MWD & Motor. 04:30 - 05:00 0.50 DRILL P PROD1 Download MWD. 05:00 - 06:00 1.00 DRILL P PROD1 Break down MWD & remove probe. UD MWD & Motor. 06:00 - 07:00 1.00 CASE P RUNPRD R/U to run 4.5", 13CR, Production Liner. 07:00 - 09:00 2.00 CASE P RUNPRD Run 14 Jts of 4.5",12.6#, 13CR, Vam Ace & Vam Top Prod. Liner as per program. 09:00 - 10:00 1.00 CASE P RUNPRD M/U ZXP Liner Top Packer & Flex-Lock Hanger Assy. 10:00 - 15:30 5.50 CASE P RUNPRD RIH w/ Liner to 9,831 '. Filling pipe every 10 stands. Fluid displacement correct. M/U Plug Dropping / Cement Head to a single and lay down same on skate 15:30 - 16:30 1.00 CASE P RUNPRD Circulate surface to surface @ 6 BPM 1 600 psi. 16:30 - 17:00 0.50 CASE P RUNPRD Run Liner in to 10,375' 17:00 - 18:15 1.25 CASE P RUNPRD M/U Cement Head & wash to bottom @ 10,400' No Fill - No Problems. Circulate @ 6 BPM /750 psi. PJSM with Crew,MI & Dowell. Have Dowell batch mix Cement. 18:15-19:45 1.50 CEMT N CEMT RUNPRD Dowell ran out of cement when cement batched was only 15.0 Printed: 8/23/2004 9:26:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-11 B N-11 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 8/5/2004 Rig Release: 8/16/2004 Rig Number: Spud Date: End: 8/16/2004 8/14/2004 18:15 - 19:45 1.50 CEMT N CEMT RUNPRD ppg. Waited on bulk cement from plant. When Cement was mixed began job. Dowell pumped water and got pressure immediately. Blew down line from rig and discovered that Dowell pump manifold had cement plug. Dowell hands chipped cement out of manifold and prepared to again attempt job. 19:45 - 20:30 0.75 CEMT P RUNPRD Cement as Follows: Dowell pump 2 bbls water & test lines to 4000 psi. Pump 5 bbls CW-100, 7 bbls, 9.7ppg. MudPush followed by 24.2 bbls (94 sx), 15.8 ppg 'G', GasBlock Slurry w/ 1.53 cU.ftIsk yield. Flush cement through 'Tee' with 2 bbls water and turn over to rig pumps. Drop dart and displace with 107 bbls 8.5 ppg mud @ 6 BPM Slowed pump 0 2.5 BPM and observed latch up @ 97 Bbls. Continued pumping & bumped plug with 4000 psi. CIP @ 20:30 Hrs. 20:30 - 21 :00 0.50 CASE P RUNPRD With 4000 psi on string: set down to confirm hanger set. Bleed pressure and check floats -OK. P/U 4 ft then slack off 50 K to set ZXP Liner Top Packer. Rotate slowly and apply 50K again. Pressure up to 1000 psi and P/U 12 ft to remove RS pack-off from RS nipple. Upon loss of pressure begin circulation. 21 :00 - 22:00 1.00 CASE P RUNPRD Circulate out cement - 4+ Bbls cement to surface. 22:00 - 23:30 1.50 CASE P RUNPRD UD Baker cement head, hose & circulating manifold. Screw in Top Drive & Displace wellbore to Seawater. 23:30 - 00:00 0.50 CASE P RUNPRD POH laying down 4" drill Pipe. 8/15/2004 00:00 - 00:30 0.50 CASE P RUNPRD POH UD 4" DP. 00:30 - 02:45 2.25 CASE N RREP RUNPRD National Oilwell engineer making final adjustment and calibrations to Auto-Driller. 02:45 - 09:30 6.75 CASE P RUNPRD Continue POH UD 4" DP - 330 Jts Total. 09:30 - 10:00 0.50 CASE P RUNPRD C/O elevators. Make service breaks & UD Baker running tool. 10:00 - 10:45 0.75 RUNCOtv1=' RUNCMP Pull wear bushing, drain stack. M/U Tubing Hanger to TC-LL Landing Jt and make dummy run. 10:45 - 11 :30 0.75 CASE P RUNPRD Test Casing, Liners and Laps under blind rams to 3500 psi. Hold and chart for 30 minutes. 11 :30 - 12:30 1.00 RUNCOtv1=' RUNCMP R/U to run 4.5", 13CR Completion String. 12:30 - 12:45 0.25 RUNCOM> RUNCMP PJSM with Co. Rep, TP, Crew, Baker & Caser. 12:45 - 00:00 11.25 RUNCOM> RUNCMP Run 4.5",12.63, 13CR, Vam Top Tubing Completion as per program. 8/16/2004 00:00 - 02:00 2.00 RUNCOrvP RUNCMP Complete running 4.5", 12.6#, 13CR Vam Top Completion String. Total 230 Jts. Ran + Jewelry. 02:00 - 02:30 0.50 RUNCOtv1=' RUNCMP Pick up Jt # 231 RIH and space out. No pup Jts needed to space out 6.57' into Tie - Back. 02:30 - 03:30 1.00 RNTBHG P TUBHGR UD Jt #231 and P/U Tubing Hanger with pup jt and Landing Jt. M/U to string & RIH to Mark. R.I.L.D.S.. R/U to reverse circulate. 03:30 - 06:00 2.50 CONDHL P OTHCMP Reverse circulate 295 Bbls seawater treated with 25 gal per 100 bbls of Corrosion Inhibitor. Displace to position with an additional 165 BBls of clean seawater. 3BPM / 200 psi. 06:00 - 08:00 2.00 RUNCOtv1=' RUNCMP Drop 1 7/8" Ball/ Rod to RHC Plug. Pressure test tubing to 4000 psi to set S-3 Packer. Hold and chart for 30 minute test. Bleed tubing to 1900 psi. Pressure test Annulus to 3500 psi. Hold & chart for 30 minutes. Bleed Annulus then tubing. Pressure Annulus to 2500 psi to shear DCR valve in GLM located @ 3150'. Pump 3 Bbls each way - OK - Full shear. 08:00 - 08:30 0.50 WHSUR P TUBHGR Pull Landing Jt. Dry rod and set TWC. Test from below to 1000 psi. Printed: 8/2312004 9:26:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: N-11 B N-11 B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 8/5/2004 Rig Release: 8/16/2004 Rig Number: Spud Date: End: 8/16/2004 8/16/2004 08:30 - 10:30 2.00 RUNCOrvP 10:30 - 14:30 4.00 BOPSUP P 14:30 - 16:30 2.00 BOPSUF P 16:30 - 18:00 1.50 WHSUR P 18:00 - 18:30 0.50 WHSUR P 18:30 - 21:30 I 3.00 WHSUR P I 1.00 I WHSUR P 21 :30 - 22:30 22:30 - 00:00 1.50 WHSUR P RUNCMP RID Bails & Elevators - UD in shed. Clear & Clean Floor, P/U rotary cover & clean out sumps. WHDTRE Open all BOP doors, remove rams. Clean rams & cavities. WHDTRE N/D BOPE. WHDTRE N/U 4 1/8", 5M, Cameron Tree & adapter flange. Test Hanger void, Adapter Flange & Tree to 5000 psi. WHDTRE R/U DSM lubricator & pull TWC. OTHCMP PJSM with Little Red. R/U & test lines to 3000 psi. Pump 151 Bbls of diesel down annulus. Shut in and allow to U-tube to freeze protect tubing and annulus to 2200'. OTHCMP R/U DSM lubricator & set BPV. Test from below to 1000 psi. RID DSM & Little Red. OTHCMP RID back-up annulus valves. Secure tree. Install valves & guages. Clean up cellar. RIG RELEASED @ 23:59 HRS, 08/16/2004. Printed: 8/23/2004 9:26:45 AM . . Well: Field: API: Permit: N-11 C Prudhoe Bay Unit 50-029-21375-02-00 204-142 Accept: Spud: Release: Rig: 08/07/04 08/10/04 08/16/04 Nabors 7ES POST RIG WORK 08/26/04 PULLED B & R. PULLED 1" DGLV'S WI BK LATCHES FROM STA' S 1 & 2. 08/27/04 RAN LIB TO CONFIRM STA #4 @ 5771' SLM WAS EMPTY, FISHED STA #4 OUT OF RHC PLUG @ 9735' SLM. PULL STA #6, SET STA'S #6,4,2, & 1. PULLED EMPTY RHC-M. 08/28/04 DRIFTED W/2 7/8 D-GUN & SAMPLE BAILER TO 10,283' SLM (10,299' CORRECTED) (GOT SAMPLE OF SANDI CEMENT). LOGGED RST FROM 9770 TO 10296 FT. AS REQUESTED IN PROGRAM AND TRANSMITTED ASCII DATA FILES TO TOWN FOR PERFORATION PICKS. LOG CORRELATION PASS FROM TO TO 9300 FT. THROUGH JEWELRY AND GLM 1. TIED INTO MWD LOG 14-AUGUST-04. TAGGED TO AT 10296 FT. NO PROBLEMS RIH AND POOH. PAD OPERATOR NOTIFIED WELL LEFT SHUT IN. 09/17/04 RAN FIVE GUN RUNS OF 2.88" HSD 6 SPF POWER JET 2906 CHARGES ARRANGED AT 60 DEG PHASING. ALL RUNS WERE TWENTY FOOT CARRIERS LOADED TWENTY FEET EXCEPT ONE CARRIER LOADED FIFTEEN FEET TO COMPLETE A 35 FOOT ZONE. ALL SHOTS FIRED. TIED INTO SLB RST LOG DATED 28- AUG-04. PERFORATED ZONES ARE 10121'-10141',10151'-10191' AND 10213'-10248. NOTIFIED PAD OP TO POP WELL AT 2MM LIFT GAS TO LOW PRESSURE HEADER AS PER PROGRAM. LEFT WELL SHUT-IN AND SECURED. . . 07 -Sep-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well N-11 C Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window I Kickoff Survey: Projected Survey: 8,296.86 I MD 8,308.00' MD 10,400.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. :::o/:~~~ :::~8 Signed 1Jwvl Ó/tj Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) :;zò~{ ~ (l{ ~ DEFINITIVE . Halliburton Sperry-Sun North Slope Alaska BPXA PBU WOA N Pad N-11A N-11C Job No. AKZZ3218334, Surveyed: 13 August, 2004 Survey Report 2004 27 August, Your Ref: AP/500292137502 Surface Coordinates: 5966927.00 N, 634409.00 E (700 19' 03.3062" N, 148054' 37.6420" Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . W) Surface Coordinates relative to Project H Reference: 966927.00 N, 134409.00 E (Grid) Surface Coordinates relative to Structure Reference: 1487.26 N, 1033.25 E (True) Kelly Bushing Elevation: 75.56ft above Mean Sea Level Kelly Bushing Elevation: 75.56ft above Project V Reference Kelly Bushing Elevation: 75.56ft above Structure Reference Survey Ref: svy4359 S"'P'f""If""I~-su:.., OF't1 L. L I"" d 5 Eo F'tV' I c: Eo 5 A Halliburton Company HalJiburlon Sperry-Sun Survey Report for PBU_WOA N Pad - N-11A - N-11C Your Ref: AP/500292137502 Job No. AKZZ3218334, Surveyed: 13 August, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ("/100ft) 8296.86 43.370 186.100 7282.19 7357.75 2550.51 S 30.06 W 5964376.36 N 634424.61 E 458.93 Tie On Point MWD+IIFR+MS 8308.00 43.340 186.150 7290.29 7365.85 2558.12 S 30.87 W 5964368.74 N 634423.93 E 0.410 461.01 Window Point 8336.16 43.340 189.320 7310.78 7386.34 2577.26 S 33.48 W 5964349.55 N 634421.67 E 7.726 466.80 8431.49 43.980 199.960 7379.84 7455.40 2640.74 S 50.10 W 5964285.78 N 634406.19 E 7.729 493.86 . 8525.25 43.470 203.600 7447.61 7523.17 2700.91 S 74.12 W 5964225.20 N 634383.25 E 2.738 527.68 8620.42 43.280 209.200 7516.81 7592.37 2759.40 S 103.16W 5964166.19 N 634355.27 E 4.045 566.14 8715.37 43.020 215.300 7586.11 7661.67 2814.28 S 137.77 W 5964110.71 N 634321.64 E 4.401 609.49 8810.24 42.030 220.490 7656.05 7731.61 2864.86 S 177.10W 5964059.43 N 634283.22 E 3.841 656.78 8907.35 39.970 224.340 7729.35 7804.91 2911.90 S 220.02 W 5964011.63 N 634241.15 E 3.356 707.01 9004.60 38.660 230.920 7804.62 7880.18 2953.41 S 265.46 W 5963969.31 N 634196.47 E 4.492 758.78 9040.14 38.320 233.500 7832.44 7908.00 2966.96 S 282.93 W 5963955.45 N 634179.24 E 4.618 778.29 9072.28 38.250 235.370 7857.67 7933.23 2978.55 S 299.13 W 5963943.58 N 634163.25 E 3.611 796.20 9103.70 37.870 239.570 7882.41 7957.97 2988.96 S 315.45 W 5963932.87 N 634147.12 E 8.328 814.04 9194.82 37.960 245.660 7954.32 8029.88 3014.68 S 365.12 W 5963906.26 N 634097.92 E 4.107 867.33 9290.82 38.240 250.350 8029.88 8105.44 3036.85 S 420.01 W 5963883.12 N 634043.43 E 3.028 925.17 9387.85 39.610 257.640 8105.41 8180.97 3053.58 S 478.54 W 5963865.35 N 633985.21 E 4.925 985.68 9482.59 40.910 263.160 8177.73 8253.29 3063.74 S 538.86 W 5963854.10 N 633925.08 E 4.006 1046.85 9579.62 41.570 266.820 8250.70 8326.26 3069.31 S 602.56 W 5963847.39 N 633861.49 E 2.578 1110.58 9675.73 42.100 266.890 8322.31 8397.87 3072.83 S 666.56 W 5963842.73 N 633797.56 E 0.554 1174.26 9771.31 43.050 267.970 8392.69 8468.25 3075.72 S 731.16 W 5963838.68 N 633733.02 E 1.254 1238.43 9847.24 42.730 266.490 8448.33 8523.89 3078.22 S 782.78 W 5963835.26 N 633681.46 E 1.392 1289.73 . 9917.70 42.490 265.720 8500.18 8575.74 3081.45 S 830.37 W 5963831 .17 N 633633.94 E 0.814 1337.18 9961.44 42.010 265.230 8532.56 8608.12 3083.77 S 859.68 W 5963828.33 N 633604.67 E 1.331 1366.47 9994.34 38.700 266.380 8557.63 8633.19 3085.34 S 880.93 W 5963826.38 N 633583.46 E 10.312 1387.67 10026.06 34.260 269.340 8583.13 8658.69 3086.07 S 899.76 W 5963825.32 N 633564.64 E 15.053 1406.36 10056.27 29.520 270.020 8608.77 8684.33 3086.16 S 915.72 W 5963824.93 N 633548.69 E 15.735 1422.11 10087.81 24.530 270.310 8636.86 8712.42 3086.13 S 930.04 W 5963824.72 N 633534.36 E 15.827 1436.22 10119.65 22.270 265.170 8666.08 8741.64 3086.60 S 942.67 W 5963824.02 N 633521.75 E 9.559 1448.75 10149.75 21.940 265.780 8693.97 8769.53 3087.49 S 953.96 W 5963822.92 N 633510.47 E 1.335 1460.03 10242.04 19.690 261.850 8780.24 8855.80 3090.97 S 986.55 W 5963818.87 N 633477.95 E 2.868 1492.74 27 August, 2004 - 10:10 Page 2 of 3 DrillQuest 3.03.06.006 ~ Halliburton Sperry-Sun Survey Report for PBU_WOA N Pad - N-11A - N-11C Your Ref: API 500292137502 Job No. AKZZ3218334, Surveyed: 13 August, 2004 North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 10337.03 18.100 265.320 8870.11 8945.67 3094.44 S 1017.10 W 5963814.85 N 633447.47 E 10400.00 18.100 265.320 8929.96 9005.52 3096.04 S 1036.60 W 5963812.90 N 633428.00 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are-relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 260.31 00 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10400.00fl., The Bottom Hole Displacement is 3264.96fl., in the Direction of 198.5110 (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8296.86 8308.00 10400.00 2550.51 S 2558.12 S 3096.04 S 30.06 W 30.87 W 1036.60 W Tie On Point Window Point Projected Survey 7357.75 7365.85 9005.52 Survey tool proøram for N-11A - N-11C From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8296.86 0.00 8296.86 7357.75 10400.00 7357.75 BP High Accuracy Gyro - BOSS-GYRO (N-11A) 9005.52 MWD+IIFR+MS (N-11 C) 27 August, 2004 - 10:10 Page 3 of 3 Dogleg Rate (0/100ft) 2.049 0.000 BPXA Vertical Section Comment 1523.44 1542.92 Projected Survey . . Dril/Quest 3.03.06.006 . . 07 øSep-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well N-11C MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window I Kickoff Survey: Projected Survey: 8,296.86' MD 8,308.00' MD 10,400.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date / c¡ J~1-~ vl Signed /JI ...' /UrtYW) ()V Please call me at 273-3545 if you have any questions or concerns. Regards, William 1. Allen Survey Manager Attachment(s) ;( O~~)LfÀ_ Halliburton Sperry-Sun North Slope Alaska BPXA PBU WOA N Pad N-11A - N-11C MWD . Job No. AKMW3218334, Surveyed: 13 August, 2004 Survey Report 27 August, 2004 Your Ref: API 500292137502 Surface Coordinates: 5966927.00 N, 634409.00 E (700 19' 03.3062H N, 148054' 37.6420H W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 966927.00 N, 134409.00 E (Grid) Surface Coordinates relative to Structure Reference: 1487.26 N, 1033.25 E (True) Kelly Bushing Elevation: 75.56ft above Mean Sea Level Kelly Bushing Elevation: 75.56ft above Project V Reference Kelly Bushing Elevation: 75.56ft above Structure Reference SI:1E!!r""r""Y-SUI'1 QR.L..L.IN G SSRVICeS A Halliburton Company Survey Ref: svy4360 Halliburlon Sperry-Sun Survey Report for PBU_WOA N Pad - N-11A - N-11C MWD Your Ref: API 500292137502 Job No. AKMW3218334, Surveyed: 13 August, 2004 BPXA North Slope Alaska Measured True Sub·Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8296.86 43.370 186.100 7282.19 7357.75 2550.51 S 30.06 W 5964376.36 N 634424.61 E 458.93 Tie On Point MWD Magnetic 8308.00 43.340 186.150 7290.29 7365.85 2558.12 S 30.87 W 5964368.74 N 634423.93 E 0.410 461.01 Window Point 8336.16 43.340 189.320 7310.78 7386.34 2577.26 S 33.48 W 5964349.55 N 634421.67 E 7.726 466.80 8431 .49 43.980 200.240 7379.84 7455.40 2640.69 S 50.25 W 5964285.83 N 634406.04 E 7.930 494.01 . 8525.25 43.470 203.410 7447.61 7523.17 2700.84 S 74.33 W 5964225.26 N 634383.04 E 2.399 527.87 8620.42 43.280 208.250 7516.80 7592.36 2759.64 S 102.78 W 5964165.96 N 634355.64 E 3.498 565.81 8715.37 43.020 215.410 7586.12 7661.68 2814.74 S 136.98 W 5964110.26 N 634322.44 E 5.163 608.79 8810.24 42.030 220.260 7656.05 7731.61 2865.37 S 176.26 W 5964058.94 N 634284.07 E 3.609 656.04 8907.35 39.970 224.420 7729.35 7804.91 2912.47 S 219.12 W 5964011.08 N 634242.06 E 3.520 706.21 9004.60 38.660 231.050 7804.63 7880.19 2953.89 S 264.63 W 5963968.84 N 634197.30 E 4.523 758.04 9040.14 38.320 233.570 7832.45 7908.01 2967.41 S 282.12 W 5963955.01 N 634180.05 E 4.515 777.57 9072.28 38.250 235.390 7857.67 7933.23 2978.98 S 298.33 W 5963943.15 N 634164.05 E 3.515 795.49 9103.70 37.870 239.830 7882.42 7957.98 2989.36 S 314.68 W 5963932.49 N 634147.90 E 8.794 813.35 9194.82 37.960 245.900 7954.33 8029.89 3014.86 S 364.45 W 5963906.09 N 634098.58 E 4.093 866.71 9290.82 38.240 250.900 8029.89 8105.45 3036.65 S 419.49 W 5963883.33 N 634043.94 E 3.226 924.63 9387.85 39.610 258.040 8105.42 8180.98 3052.89 S 478.16 W 5963866.04 N 633985.57 E 4.832 985.20 9482.59 40.910 263.880 8177.74 8253.30 3062.46 S 538.58 W 5963855.39 N 633925.34 E 4.212 1046.36 9579.62 41.570 268.300 8250.72 8326.28 3066.80 S 602.36 W 5963849.90 N 633861.65 E 3.078 1109.96 9675.73 42.100 269.230 8322.33 8397.89 3068.18 S 666.45 W 5963847.38 N 633797.59 E 0.849 1173.37 9771.31 43.050 268.490 8392.71 8468.27 3069.47 S 731.10 W 5963844.93 N 633732.98 E 1.123 1237.31 9847.24 42.730 266.800 8448.34 8523.90 3071.60 S 782.73 W 5963841.88 N 633681.39 E 1.572 1288.56 . 9917.70 42.490 265.720 8500.20 8575.76 3074.71 S 830.33 W 5963837.92 N 633633.86 E 1.092 1336.01 9961.44 42.010 265.700 8532.58 8608.14 3076.91 S 859.65 W 5963835.20 N 633604.58 E 1.098 1365.28 9994.34 38.700 266.290 8557.65 8633.21 3078.40 S 880.90 W 5963833.32 N 633583.36 E 10.127 1386.48 10026.06 34.260 269.520 8583.15 8658.71 3079.11 S 899.74 W 5963832.27 N 633564.54 E 15.247 1405.17 10056.27 29.520 270.400 8608.79 8684.35 3079.13 S 915.69 W 5963831.97 N 633548.59 E 15.765 1420.90 10087.81 24.530 270.770 8636.88 8712.44 3078.99 S 930.02 W 5963831.85 N 633534.26 E 15.830 1434.99 10119.65 22.270 265.530 8666.10 8741.66 3079.37 S 942.64 W 5963831.24 N 633521.64 E 9.643 1447.51 10149.75 21.940 266.370 8693.99 8769.55 3080.17 S 953.94 W 5963830.24 N 633510.36 E 1.518 1458.78 10242.04 19.690 262.430 8780.25 8855.81 3083.31 S 986.57 W 5963826.52 N 633477.80 E 2.870 1491.46 27 August, 2004 - 10:12 Page 2 of3 DríllQuest 3.03.06.006 Halliburlon Sperry-Sun Survey Report for PBU_WOA N Pad - N-11A - N-11C MWD Your Ref: API 500292137502 Job No. AKMW3218334, Surveyed: 13 August, 2004 North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 10337.03 18.100 265.820 8870.12 8945.68 3086.50 S 1017.15 W 5963822.79 N 633447.28 E 10400.00 18.100 265.820 8929.98 9005.54 3087.92 S 1036.66 W 5963821.01 N 633427.79 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 260.31 0° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10400.00ft., The Bottom Hole Displacement is 3257.29ft., in the Direction of 198.558° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8296.86 8308.00 10400.00 2550.51 S 2558.12 S 3087.92 S Tie On Point Window Point Projected Survey 7357.75 7365.85 9005.54 30.06 W 30.87 W 1036.66 W Survey tool proaram for N-11A - N-11C MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8296.86 0.00 8296.86 7357.75 10400.00 7357.75 BP High Accuracy Gyro - BOSS-GYRO (N-11A) 9005.54 MWD Magnetic (N-11C MWD) 27 August, 2004 - 10:12 Page 3 of3 Dogleg Rate (0/100ft) 2.033 0.000 Vertical Section Comment 1522.15 1541.62 Projected Survey BPXA . . DrillQuest 3.03.06.006 j ~LHl:AU" ACTUATOR .. KB. 8.EV .. BF. 8.EV .. KOP= .Max Angle .. Datum MD.. Datum TVD" Mct:VOY AxaSON 75.5' 46.95' 4200' --4705800' 10,400' 8930' SS N-11&ctual Completion - SoeCmt'd D~L(T - \)Q.~·fT· 4-112" HES X-Nipple ID '" 3.813" -2100' 6 3136 3138 0 5 4504 4500 3 4 5777 5500 46 3 7091 6450 41 2 8270 7350 43 1 9485 8250 41 CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DCR RKP 1.5" 816/20().4 DUM RK 1.5" 816/20().j DUM RK 1.5" 816J20o.f DUM RK 1.5" 816120().4 DUM BK 1" 816/2004 DUM BK 1" 816/2004 . ~ 13-318" CSG, 72#. / L-80. ID '" 12.347" 2696' 4-1/2".12.6#. 13CR TBG. ID '" 3.958" L- - ~ Top of 7", 2811 LNR - 8144' 4-1/2" HES X Nipple. ID '" 3.813" - 9,680' 7" x 4-112" S-3 Packer - 9,700' 4-1/2" HES X Nipple.ID '" 3.813· - 9.724' 4-112" HES XN Nipple, ID = 3.725" - 9,745' 4-1/2" WLEG - 9757' 4-1/2" LNR HangerJZXP - -9153' - Bottom of Whipstock _ (9-518" Exit Point) -8324' Top Bridge Plug -8320' - - r, 26# L-BO LNR -9918' 4-112".12.6#, 13CR LNR. ID = 3.958" 4-1/2" landing Collar - 10,309' 4-1/2" Float Collar -10398' Bottom of EZSV -9220'- Þ. .... Chemical Cut -9230' Top Cement -9350' 4-1/2" OTIS XA SLIDING SLV,ID = 3.813" 9446' TIW TBG Seal Assy 9508' - 9-518" x 4-112" TIW HBBP PKR 9523' Tubing Punch (4 SPF) 9547'-9557' Top 7" LNR 9599' 4-1/2" TBG TAIL, ID '" 3.958" 9641' I 964r HBKRCBP(08/26/03) I Apparent Parted liner @ 9925' and 10089'1 ~ from PDS long run on July 3. 2003. !td IMiUout Window 9902'-9906'1 9-518" CSG, 47#, L-80. ID '" 8.681" 9861' 7· LNR, 26#, L-SO. IJ45 9902' _ 2-718·LNR.6.16t.L-80..00579bpf.D.2......1· H 11204' I REV BY CCWIoeITS DATE REV BY coa.t.ENTS ORIGINAL COMPLETION 08124/03 KF/KAK SAND DU\4P SIDETRACK (N-11B) 08126103 I3JM'KK SET BP; TaG PUNCH RNITP CORRECTIONS 05114104 KWA Proposed Con,:)letJon (N-11C) BJMcL./TLH SETSP 08116104 AM'BD ACTUAL COJ.RET1ON(N-11C) MWmH LNR TOP PKR & DATUM lFDA TE JJlTtH PUlL BP I DATE 0&113/81 11/21189 03/09/02 07/16/03 08117103 08/20/03 PRUDHOE BAY UNrr WB.L: N-11B PERMrr No: 1991050 API No: 50-029-21375-01 SEe 8. T11 N, R13E. 1023' FSL & 540' FWL. BP exploratIon (Alaska) ~~;J æJ,= , iJ1E\ - nJ-=:¡ . (ill ~- FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OILAlWD GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay N-11 C BP Exploration (Alaska) Inc. Permit No: 204-142 Surface Location: 1023' NSL, 540' EWL, SEe. 08,TIIN, Rl3E, UM Bottomhole Location: 2082' SNL, 518' WEL, SEC. 18, TIIN, Rl3E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907 659- 0 (pager). S' c r BY ORDER 91 THE COMMISSION DATED this~ day of July, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. STATE OF ALASKA . ALASKA OiL AND GAS CONSERVATION COMlVfíSSION PERMIT TO DRILL 20 AAC 25.005 ~\/ED o Drill Ii Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1023' NSL, 540' EWL, SEC. 08, T11N, R13E, UM Top of Productive Horizon: 2067' SNL, 429' WEL, SEC. 18, T11N, R13E, UM Total Depth: 2082' SNL, 518' WEL, SEC. 18, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 634409 y- 5966927 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 8300 feet Maximum Hole Angle: 47 degrees / ./ 1b. Current Well Class 0 Exploratory Ii DevelopmênfOil o MultiplëZonê o Stratigraphic Test 0 Service 0 Development Gas D ,Singlß .?Qne 5. Bond: II Blanket 0 Single Well 11. Well Name and Number: / 70 :",,' Bond No. 2S100302630-277 PBU N:1JC 7, - . 6. Proposed Depth: 12. Field 1 Pool(s}: MD 10381' TVD 8989' Prudhoe Bay Field 1 Prudhoe Bay 7. Property Designation: Pool ,-./ ADL 028283 ~ r"'" L Þ K;} 7004 ~ -" ~ - 1 8. Land Use Permit: 13. Approximate Spud Date: 08/10/04 14. Distance to Nearest Property: 28000' 9. Acres in Property: 2560 18. Casing Program: Size Casing 7" Hole 8-1/2" 6-1/8" 4-1/2" Weight 26# 12.6# Specifications Grade Coupling Length L-80 BTC-M 1829' 13Cr-80 VAM TOP 552' 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 78.70' feet 1024' away from N-24 at 8300' MD 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3150 Surface: 2295 -SettinØ)R~pth'(,J_// .., .Ql.lantity9fÇ~l'J)eht . ~oPf<"<-~eBottomi>· (cJ~orsacks) MD TVD MD TVD (including stage data) 8150' 7251' 9979' 8626' 404 cu ft Class 'G' 9829' 8516' 10381' 8989' 101 cu ft Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be çcjmpletedforRedriUANp Re-:entrYQpera(i()nª) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): Effective Depth MD (ft): Depth TVD 11204 8727 964 7 9593 8322 Casing Length Siie Structural Conductor Surface Intermediate Production Liner Junk (measured): NIA 100' 2697' 20" x 30" 13-3/8" 8 cu yds Concrete 3720 cu ft Permafrost 'E' and PF 100' 2697' 100' 2697' Liner 9868' 303' 1596' 9-5/8" 7" 1883 cu ft Class 'G', 230 cu ft Class 'G' 379 cu ft Class' G' , 279 cu ft PF 'C' 168 cu ft Class 'G' 9868' 9599' - 9902' 9608' - 11204' 8533' 8326' - 8560' 8333' - 8727' 2-7/8H Perforation Depth MD (ft): 10820' - 11110' Perforation Depth TVD (ft): 8776' - 8729' 20. Attachments II Filing Fee, $100 0 BOP Sketch II Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Property Plat 0 Diverter Sketch 0 Seabed Report II Drilling Fluid Program II 20 AAC 25.050 Requirements Date: 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name BiIIlsaacson Title Senior Drilling Engineer Signature 1- )LlL~ L ~-t. Contact Ken Allen, 564-4366 Phone 564-5521 Date T /1."/01 Prepared By Name/Number: Sondra Stewman, 564-4750 Permit To Drill API Number: Permit App~olal, ¡ ,/ See cover letter for Number: 21'37'- /7<'.? 50- 029-21375-02-00 Date: 7¡/-I/jt. ~ I.{ other requirements Conditions of Approval: Samples ired DYes )8(No Mud Log Required 0 Yes ~NO , Hydro Su Ide Measures ~e~ 0 No . Directional ,Survey Required ~Y~s 0 No Other: ~st fuÆ ~ p'; Per ZJA1tL IS ,o~S Lh)ÇO./ tt.lfe.y1rt..~·te ,Bo PE I ~ û.f f,ro f(e~ - I Lt.' /'0-401. t?1 ~, p \ ~ ,)(1 r t· 0 t 5 f~, 000 c.lu.y 1 "L<-\ ~ )0"C~i1tÇ, 81) rH\J t/;d tl't\L .¿ 1" 1""' S ::;r~~:~~v e . ed OfNjJt; '- 0 RIG' N A L ~~~~~~~I~~ION Date 1£~!~ ""-/ .~ ,Planned Well Summary Well N-11 C Well Type Low angle Sidetrack Target Objective Zone 4 I AFE Number: I PBD 4P2264 I I API Number: I 50-029-21375-02 Suñace Northing Easting Offsets TRS Location 5,966,927.00 634,409.00 4,257' FNL / 4,739' FEL 11 N, 13 E, 08 ~ Target Northing Easting Offsets TRS Location 5,963,821.00 633,506.00 2,066' FNL / 429' FEL 11N,13E,18 Bottom Northing Easting Offsets TRS Location 5,963,804.00 633,417.00 2,082' FNL / 518' FEL 11N,13E,18 / Planned KOP: 8,300' md Planned TD: 10,381' md Planned Spud: 08/10/04 Planned TVD: 8,989' I Rig: I Nabors 7ES 1/ I BFE: I 46.95' I RTE: I 75.45' Directional Program Approved Well plan: WP12 I Exit point: I 8,300' md /7,284' sstvd -470 at 5,800' in the original well bore, -43.00 in the planned 8-1/2" intermediate section from 9,362' md to drilling out the 7" casing shoe -9,994' md. There are no close approach issues in drilling N-11 C. All surrounding wells pass major risk criteria. Standard MWD. Well N-24, with center-ta-center distance of -1 ,024' at 8,300' md. 28,000' to the nearest PBU property line. Maximum Hole Inclination: Proximity Issues: Survey Program: Nearest Well: Nearest Property Line Logging Program Hole Section: 8-1/2" intermediate: 6-1/8" production: Cased Hole: Open Hole: Required Sensors I Service Real time MWD Dir/GRlPWD throughout the interval. Real time MWD Dir/GRlRes throughout the interval. Two sample catchers will be required at company man call out. None planned None planned N-11 C Sidetrack Version 1.0 Page 1 , -.,....-- Type LSND Hole Section / operation: Density (ppg) PV 10.9 10-15 Type LSND Hole Section / operation: Den~.· fi)¡pg) PV ~/ 10-15 Hole Section / operation: Type Density (ppg) PV FloPro SF 8.4 - 8.6 7 - 12 .- Mud Proaram I Set Whip stock / mill window in 9 5/8" casing Funnel Vis YP Chlorides API FL pH 65 - 90 35 - 40 < 1,500 4 - 6 9.0 - 9.5 I Drilling 8-1/2" interval- window to section TD Funnel Vis YP Chlorides API FL pH 50 - 80 22 - 28 < 1,500 4 - 5 9.0 - 9.5 I Drilling 6 1/8" production interval Funnel Vis YP Chlorides API FL 45-60 22-30 <30,000 4-8 pH 9.0-9.5 Casina I Tubina Proaram Hole Casing/Tubing Wt. Grade Connection Length Top Bottom Size Size I / md / tvd md/tvd 8 Ÿ2" 7" 26.0# L-80 BTC-M 1,829' 8,150/7,251 9,979 / 8,626 6 1/8" 4-1/2" 12.6# 13Cr -80 VAM TOP 552' 9,829/8,516 10,381/8,989 Tubing 4-1/2" 12.6# 13Cr -80 VAMTOP 9,829' Surface 9,829/8,516 Casing String: Slurry Design Basis: Fluids Sequence / Volume: Casing String: Slurry Design Basis: Fluids Sequence / Volume: N-11C Sidetrack Version 1.0 Cementina Proaram 7", 26#, L-80, BTC-M drilling liner Lead slurry: None planned Tail slurry: fully cemented 7" X 8 Ÿ2" annulus with 40% excess, plus 80' of 7", 26# shoe track, plus 150' of 9-5/8" x 7" liner lap. Pre-Flush None planned Spacer 35bbls MudPUSH at 11.9ppg Lead Slurry None planned //J Tail Slurry 72bbls 1401 cf I~X Class 'G', 15.8ppg; 1.16 cf/sk. 4 1/2", 12.6#, 13Cr-80, Vam TOP solid production liner Lead slurry: none planned Tail slurry: 552' of 4 1/2" X 6 1/8" annulus with 40% excess, plus 85' of 4 1/2", 12.6# shoe track, plus 150' of 7" X 4 Ÿ2" liner lap, plus 200' of 7" X 4" drill pipe annulus. Pre-Flush Spacer Lead Slurry Tail Slurry 5bbls CW 1 00 10bbls MudPUSH II at 9.5ppg None Planner: ." 18bbl/1 01 C~," sx Class 'G', 15.8ppg w/silica; 1.53 cf/sk. Page 2 Test 9 5/8" casing to surface Intermediate casing window 9 5/8" casing I 7" liner Intermediate liner shoe -- '- Casina I Formation Intearitv Testina Test Point Bridge plug to surface 20' beyond middle of window Float equipment to surface 20' new formation beyond shoe Test Type 30 min recorded FIT 30 min recorded FIT Test pressure /' 3,500psi surface 12.5ppg EMW 3,500psi surface /~ 10.0ppg EMW Well Control Well control equipment consisting of 5,OOOpsi working pressure pipe rams (2), blindlshear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: Maximum anticipated BHP: Maximum suñace pressure: Calculated kick tolerance: Planned BOPE test pressure: BOPE configuration for 7" drilling liner. Well Interval: Maximum anticipated BHP: Maximum suñace pressure: Calculated kick tolerance: Planned BOPE test pressure: Planned completion fluid: 8-1/2" intermediate drilling liner section 3,15j)psi at 8,550' sstvd. :95 ái (based upon BHP and a full column of gas from TO@0.1 0 psi/ft) IÍrÍfir . e with 11.3 ppg EMW FIT (FIT to 12.5 ppg EMW) psi low 13,500psi high -14 day test cycle ../ Variable Bore Rams will remain installed, rather than CIO to 7" pipe rams. The rig will follow the current, best practice of picking up a joint of drill'-y'- pipe, crossed over to casing thread, in the event of a kick. This - 1\ configuration provides two sets of employable rams, rather than one. 6-1/8" production liner section 3,150psi at 8,800' sstvd. ~psi (based upon BHP and a full column of gas from TO @ 0.10 psi/ft) (infi~jte with 8.8 ppg EMW FJ (FIT to 10.0 ppg EMW) 250psi low I 3,500psi high 8.4ppg seawater I 6.8ppg Diesel Disposal No annular injection in this well. Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at 08-04. Any metal cuttings should be sent to the North Slope Borough. All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 for injection. All Class I wastes are to be hauled to Pad 3 for disposal. Annular Injection: Cuttings Handling: Fluid Handling: N-11C Sidetrack Version 1.0 Page 3 '.-' ~ GeoloQic ProQnosis Formation MD TVDss Comments Top Kingak Above Kickoff Kickoff 8300 7284 TJF 8677 7570 TJE 8892 7740 TJD 9193 7975 TJC 9594 8270 TJB 9757 8389 Sag River 9978 8550 Shublik 10025 8585 / TSAD I TZ4B 10116 8665 3150 psi @ 8800 POWC 10180 8725 TCGL I TZ3 8825 (below TO) TD Criteria I TD Criteria: I 200' MO below the POWC. This includes -100' for shoe track. Fault ProQnosis Formation MD Intersect TVDss Estimated Direction of U rt· ty Encountered Intersect Throw Throw nce am Fault #1 Kingak 8645 7544 -90' West +/- 100' NOTE: Fault #1 was crossed in the N-11A parent wellbore with no reports of losses or hole instability. Fault N-11 C Sidetrack Version 1.0 Page 4 L__ -- Operations Summary Pre-Ria Operations: 1. Bleed OA, IA and tubing pressures to zero. Test the 9-5/8" pack-off, Function all LOS, repair or replace as necessary. 2. MIT the OA to 2000 psi. 3. RU Coil Tubing. Cement P & A N-11 B lateral with coil tubing from the top of the sand plug to 9350'. 4. CMIT IA and tubing to 3000 psi for 30 minutes (this should be done post coil cement plug). 5. RU Slick-line. Drift tubing and tag TOC at 9350' with gauge ring / junk basket. 6. RU RU E-line. RIH with Gamma Ray, CCl and string shot tool. Perform string shot and log Gamma Ray from TOC up, tying into previous jewelry log. GR log should continue to a minimum of 500' above the THRZ. POOH. RIH and chemical cut tubing -9230', in the middle of joint #6. Oust above first GlM & 10' pup). *** Tubing Tally dated 7/4/85 *** Note: Gamma Ray log will be used to pick the Kick off point for the Rotary Sidetrack. *** 7. Circulate the well to seawater. Freeze protect the IA and tubing with diesel to - 2200'. 8. Bleed all pressures to zero. Set BPV. Secure well. 9. Remove the wellhouse. If necessary, level the pad. y Ria Operations: 1. MIRU Nabors 7ES 2. Pull BPV. Circulate out freeze protection and displace well to Sea Water. 3. Monitor OA, IA and T for pressure. Verify well is dead. 4. Set TWC. Nipple down tree. Nipple up and test BOPE. Pull TWC. 5. Pull 4-1/2" tubing from pre-rig cut at - 9230' (Have a spear on location; previous CTD sidetrack may have damaged threads). 6. RU e-line. Run GRlJB for 9-5/8",47# casing to top of tubing stub. 7. MU 9-5/8", 47# EZSV bridge plug on e-line with CCL. RIH and set just above the top of the tubing stub - 9220'. POOH for 2nd EZSV bridge plug. RIH and set the 2nd plug at - 8320' MD (Set the bridge plug at ±8320' to avoid cutting a casing collar with the whipstock mill). RD e-line. Note: The final setting depth for the 2nd EZSV (whipstock bottom) will be optimized from the pre-rig Gamma Ray and CCl logs. 'T ~ç I 0 ~ 40 I ~¡? Y'Ð\I CLl, \J.J61r 8. PU milling assy. RIH picking up dp to top' I!ZSV. Pressure test the 9-5/8" casing to 3500 psi for 30 / minutes. Change well over to 10.9 ppg milling fluid. 9. RIH with 8-1/2" whipstock and milling assembly to EZSV. Orient and set the whipstock. 10. Mill a window in the 9-5/8" casing at ±8,300' MD plus 20' from mid window. Perform FIT to 12.5 ppg. /' POOH for Drilling BHA. Verify that the mud weight is at least 10.9 ppg prior to cutting the window. 11. MU the 8-1/2" drilling assembly with DIRlGRlRES/PWD and RIH. Kick off and drill 8-1/2" intermediate interval, turning at 4.5°/100' to -260° azimuth and holding -43° inclination. ~. 12. Drill ahead to casing point at Top Sag River to an estimated depth of 9,979' MD. 13. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing 150' to /' 8,150' MD. Set hanger /Iiner top packer and displace cement with mud. POOH. 14. MU 6-1/8" BHA with DIRlGRlRES and RIH to the landing collar. 15. Pressure test wellbore to 3500 psi for 30 minutes. ,./" 16. Drill shoe track. Swap over to 8.5 ppg mud and drill 20' of new formation. Perform FIT to 10.0 ppg. 17. Drill the 6-1/8" production interval as per directional plan (dropping to 20° inclination by TSAD) to and /' estimated TO of 10,381 . 18. Run and cement a 4-1/2", 12.6#, 13Cr-80 Vam TOP liner throughout the 6-1/8" wellbore and 150' / back into the 7" drilling liner to 9,829' MD. Set liner top packer and displace well to clean seawater above the liner top. 19. Run 4-1/2", 12.6#, 13Cr-80 Vam TOP completion tying into the 4-1/2" liner top. / 20. Set packer, test and record the tubing to 3500 psi and annulus to 3500 psi for 30 minutes each. N-11C Sidetrack Version 1.0 Page 5 ~ .~ 21. Set and test TWC to 1000 psi. / / 22. NO BOPE. NU and test the tree to 5000 psi. Pull TWC. ' 23. Freeze protect the well to -2000'. Set BPV and secure the well. 24. RDMO. Post-Ria Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. MIRU e-line to perforate -70' (Depths to be determined from MWD logs obtained during rig sidetrack). 4. Install gas lift valves. Estimated Spud Date: 08/10/04 Job 1: Move In I Ria Up I Test BOPE Planned Phase Time 30 hours Planned Phase Cost $78,302 Reference RP .:. "Drilling/Workover Close Proximity Surface and Subsurface Wells" SOP. .:. IHydrogen Sulfide <I SOP. .:. "ADW Rig Move" RP. Issues and Potential Hazards ~ No wells will require shut-in for the rig move onto N-11B. However, N-26 is 30.0' to the North, and N-23 is 65.0' to the South. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. ~ The N-11 B well bore will be secured with 2 barriers, (the P&A cement plug and seawater). Prior to pulling the tree, verify there is a static column of seawater to surface and that no pressure exists. ~ N-Pad is designated as an H2S site. Standard Operating Procedures for H2S precautions should be follOWèd at all times. Recent H2S data from the pad is as follows: Well Name H2$-Rf¡)ading #1 Closest SHL with H2S Reading N-1 0 ~pm #2 Closest SHL with H2S Reading N-12 20 ppm #1 Closest BHL with H2S Reading N-09 10 ppm #2 Closest BHL with H2S Reading N-24 5 ppm Max Recorded H2S Reading on the Pad N-15 220 ppm N-15 below 50 ppm-starting 4/15/2000 Most recent reading of (1~ppm was N-26 on 2/1/02 Date 8/12/200 8/16/2000 4/14/2004 10/20/2003 10/4/1995 ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud ~ Note that the N-11 conductor was abandoned in 1985. N-11 A is NOT a sidetrack from N-11, but ~ rather a Grass Roots well drilled in 06/1985. N-11 B is the first sidetrack from N-11 A. - j\ Job 2: De-complete Well N-11C Sidetrack Version 1.0 Page 6 .~J - Planned Phase Time 60 hours Planned Phase Cost $211,316 Reference RP .:. "De-completions" RP Issues and Potential Hazards ~ The N-11 B well bore will be secured with 2 barriers, (the P&A cement plug and the seawater). Prior to pulling the tree, verify there is a static column of seawater to surface and that no pressure exists. ~ Monitor the well to ensure the fluid column remains static prior to pulling the completion. ~ Note and record required PU weight to pull tubing at cut point (-9230'). ~ Have all wellhead and completion equipment NORM-tested, following retrieval. ~ This wellhead is a McEvoy SSH. The tubing hanger is a 12" X 4.5" TDS OR Butt top and bottom (records are unclear at this time). The threads are most likely damaged due to the coil tubing sidetrack. Have a spear on location as a contingency. Once the stack has been nippled down, verify the hanger thread and type in preparation for de-completion. ~ There is a 4-1/2" Otis BVN SSSV with dual X" encapsulated control lines at 2094'.There should be about 25 rubber protectors securing the control lines. The well plan called for a protector every other joint, but the well record does not list the actual number ran. Job 3: Run Whip Stock Planned Phase Time 30 hours Planned Phase Cost $178,356 Reference RP .:. "Whipstock Sidetrack" RP. Issues and Potential Hazards ~ A 9 5/8" whip stock will be run and set in the existing intermediate casing. ~ According to the initial cementing report, there should be cement behind the 9 5/8" casing at the sidetrack point. ~ Once milling is complete, circulate a minimum of 1-1/2 bottoms up and pump a "Super Sweep" pill to remove metal debris created from the milling process. Ditch magnets should be used throughout job. ~ Once the milling BHA is out of the hole the entire stack and flow lines should be flushed to remove metal debris that may have settled out in these areas. Ensure BOP equipment is operable. Job 5: Drill 81/2" Intermediate Hole Interval Planned Phase Time 112 hours Planned Phase Cost $583,616 Reference RP .:. "Prudhoe Bay Directional Guidelines" RP N-11C Sidetrack Version 1.0 Page 7 ..-' '- .:. IIShale Drilling, Kingak and HRZ' RP. .:. "Lubricants for Torque and Drag Managemenf' RP .:. "Leak-off and Formation Integrity Tests" SOP Issues and Potential Hazards ~ This well bore will exit the original well in the upper Kingak shale, and drill to the top of the Sag River formation. Previous N-pad wells drilled the Kingak with 9.7 to 10.0ppg mud weights. For this well, the Kingak will require a mud weight of 10.9ppg, according to the Kingak Polar plot. Maintain mud weight at 10.9 from the window to 7" liner point. Follow all shale drilling practices to minimize potential problems. ~ KICK TOLERANCE: I e worst-case scenario of 8.2 ppg pore pressure at the Sag River depth, a fracture gradient 11 3 ppg at the 9 5/8" casing window, and 10.9 ppg mud in the hole, the kick tolerance i Infi . e. ~ This well path wi ross a fault in the Kingak at -7,544' sstvd, -8,645' md. The fault has a throw of approximately 90' to the West. This same fault was crossed in the N-11A wellbore and there were no reports of losses or hole instability problems, the crossing of this fault is deemed a low risk hazard. Job 6: Run and Cement 7" Intermediate Liner Planned Phase Time 24 hours Planned Phase Cost $183,820 Reference RP .:. IIShale Drilling, Kingak and HRZ' RP. .:. IIlntermediate Casing and Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner' RP .:. Schlumberger Cement Program. Issues and Potential Hazards ~ Swab and surge pressure should be minimized with controlled liner running speeds and by breaking circulation slowly. Excessive swab / surge pressures could initiate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Job 7: Drill 6 1/8" Production Hole Interval Planned Phase Time 50 hours Planned Phase Cost $368,949 Reference RP N-11C Sidetrack Version 1.0 Page 8 <- ~ .:. "Leak-off and Formation Integrity Tests" SOP .:. "Prudhoe Bay Directional Guidelines" RP .:. "Lubricants for Torque and Drag Managemenr RP Issues and Potential Hazards ~ The history of losses in the parent wellbore are associated with faults in the production section. The N-11 C well bore does not cross any planned faults in the production section. N-pad is a highly faulted area so be prepared for the possibility of losses from unmapped faults. The parent well bores loss circulation history is as follows: · N-11 A lost 3340 bbls at a mapped fault in Zone 4. The N-11 C wellbore will not drill near this fault. · N-11BPB1 lost over 1300 bbls of fluid in the Shublik B near a junction of two faults. N-11C avoids this high risk area with a higher kick off point and drilling further North. · N-11 BPB2 lost 250 bbls of fluid in Zone 4 near a junction of two faults. N-11 C avoids this high risk area with a higher kick off point and drilling further North. · N-11 B lost 350 bbls of fluid in Zone 4 at a mapped fault tip. N-11 C avoids this fault tip by drilling 150' to the North. Job 9: Run 4%" Production Liner Planned Phase Time 24 hours Planned Phase Cost $160,345 Reference RP .:. "Modified Conventional Liner Cementing" RP .:. "Handling and Running 13 Chrome" RP .:. Schlumberger Cement Program. Issues and Potential Hazards ~ The completion design is to run a 4-112", 12.6#, 13Cr-80 Vam TOP solid liner throughout the production interval. ~ Differential sticking is possible. The 8.6ppg Flo-Pro will be -785 psi over balanced to the Ivishak Zone 4 formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4-1/2" liner will be run to extend -150' back up into the 7" liner. Take all the normal precautions while running the Yam TOP 13Cr-80 tubing: clean threads if contaminated, use a stabbing guide, properly dope and hand-start each pin. Use Jet Lube Seal Guard thread compound and torque turn each connection. Tubing should arrive on location with the proper thread dope. Confirm type of thread compound prior to RIH. N-11C Sidetrack Version 1.0 Page 9 -- -- Job 12: Run 4 %" 13Cr-80 Completion Planned Phase Time 24 hours Planned Phase Cost $432,465 Reference RP .:. "Completion Design and Running" RP .:. "Handling and Running 13 Chrome" RP .:. "Casing and Tubing connections" RP Issues and Potential Hazards » Diesel will be used to freeze protect the well to 2000'. The diesel flash point is 1 00° F. Diesel vapor pressure is - 0.1 psia at 100° F. » The completion, as designed, will be to run a 4-1/2", 12.6#, 13Cr-80, VAM TOP production tubing string, stinging into the 4-1/2" liner tieback sleeve. Take all the normal precautions while running the Yam TOP 13Cr-80 tubing: clean threads if contaminated, use a stabbing guide, properly dope and hand-start each pin. Use Jet Lube Seal Guard thread compound and torque turn each connection. Tubing should arrive on location with the proper thread dope. Confirm type of thread compound prior to RIH. / Job 13: ND/NU/Release Ria Planned Phase Time 12 hours Planned Phase Cost $42,821 Reference RP .:. "ADW Rig Move" RP. .:. "Freeze Protecting an Inner Annulus" RP. Issues and Potential Hazards » No wells will require shut-in for the rig move onto N-11B. However, N-26 is 30.0' to the North, and N-23 is 65.0' to the South. These are the closest neighboring wells. Care should be taken while moving off the well. Spotters should be employed at all times. N-11C Sidetrack Version 1.0 Page 10 TREE = WELLHEAD = AcTUAtOR; KB. ELEV = .........--...........-. --....... BF. ELEV = "'U'V"'.___J~·'·_·""',""'A KOP= Max Angle = 'öaiumuMD; _'__~"'...m.....m....L'......h'" ..'L~,'" ,. DatumìVD = 4" CrN McEVOY AXElSON 75.5' 46.95' 4200' -47@5800' N/A .... ......" "'.,........ 8800' SS ~ 13-3/8" CSG, 72#, / L-80, ID = 12.347" 2696' Bottom of Whipstock (9-5/8" Exit Point) -8300' Top Bridge Plug -8320' - Bottom of EZSV -9220' Chemical Cut -9230' Top Cement -9350' 9-5/8" CSG, 47#, - ~ L-80, ID = 8.681" 9867' N-11t:rProposed Completion ~olid/Cmt'd / 4-1/2", 12.6#, 13CR TBG, ID = 3.958" L' .~ Top of 7". 26# LNR - 8150' 4-1/2" HES X Nipple, ID = 3.813" 7" x 4-1/2" S-3 Packer '4-1/2" HES X Nipple, ID = 3.813" 4-1/2" HES XN Nipple, ID = 3.725" 4-1/2" WLEG 4-1/2" LNR Hanger/ZXP - -9829' þ -- 4-1/2" HES X-Nipple ID = 3.813" -2100' ~ GAS LIFT MANDRELS ST MD ìVD DEV lYÆ VL V LATCH PORT DA TE 5 4 3 2 1 I I z :8: - 7", 26# L-80 LNR -9979' 4-1/2",12.6#, 13CR LNR, ID = 3.958" 4-1/2" Landing Collar 4-1/2" Float Collar -1 0381' 4-1/2" OTIS XA SLIDING SLV, ID = 3.813" 9446' TIW TBG Seal Assy 9508' 9-5/8" x 4-1/2" TIW HBBP PKR 9523' Tubing Punch (4 SPF) 9547'-9557' Top 7" LNR 9599' DATE 05/13/81 11/21/99 03/09/02 07/16/03 08/17/03 08/20/03 REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK (N-11A) RN/TP CORRECTIONS BJMcL/TLH SET IBP MW/TLH LNR TOP PKR & DATUM UPDATE JJ/TLH PULL IBP I 4-1/2" TBG TAIL, ID = 3.958" 9641' = ~ I 9647' 1-1 BKR CIBP (08/26/03) 1 _ Apparent Parted liner @ 9925' and 10089' - _____ from PDS long run on July 3, 2003. Jtd I Millout Window 9902'-9906' I 7" LNR, 26#, L-80, IJ45 9902' - ~ 12-7/8" LNR, 6.16#, L-80, .00579 bpf,ID=2.441" 1-1 11204' I I PBTD 1-1 11168' DATE REV BY COMMENTS 08/24/03 KF/KAK SAND DUMP 08/26/03 BJrwKK SET IBP; TBG PUNCH 05/14/04 KMJA Proposed CorT'4Jletion PRUDHOE BAY UNIT WB..L: N-11 B ÆRMIT No: '1991050 API No: 50-029-21375-01 SEe 8, T11 N, R13E, 1023' FSL & 540' FWL BP Exploration (Alas ka) TREE = 4" CrN WELLHEAD = McEVOY ACTÛÄTOR;;; . AXElSÖN kB.uäBï'';;; 78.7' ". .......... .......... BF. ELEV = 46.95' ............. ...... .m. KOP = 4200' 'Max Än~l.e~;;;~'fôT@i'1ö"945i Datum MD = NIA ÓiÙÚm'iVÖ,;;;uc""'~"'äãö6ïSS c_ N-11 B P&A / '-~ ~ 13-3/8" CSG, 72#, / L-80, 10 = 12.347" 2696' ~ Top Bridge Plug -8330' - Þ ~ Bottom of EZSV -9220' Chemical Cut -9230' Top Cement -9350' þ -- 4-1/2" OTIS XA SLIDING SLY, 10 = 3.813" 9446' TIW TBG Seal Assy 9508' 9-5/8" x 4-112" TIW HBBP PKR 9523' Tubing Punch (4 SPF) 9547'-9557' Top 7" LNR 9599' I I í. w', ¡ Z ~ 9-518" CSG, 47#, -.4 L-80, 10 = 8.681" 9867' - 4-1/2" TBG TAIL, 10 = 3.958" 9641' I 9647' 1--1 BKR CIBP (08/26/03) 1 Apparent Parted liner @ 9925' and 10089' ;;::::::::: ~ from PDS long run on July 3, 2003. @ I Millout Window 9902'-9906' I 7" LNR, 26#, --' L-80, IJ45 9902' I PBTD 1 I 11168' I 2-7/8" LNR, 6.16#, L-80, .00579 bpf. ID = 2.441" 1--1 11204' 1 DATE 05/13/81 11/21/99 03/09/02 07/16/03 08/17/03 08/20/03 REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK (N-11A) RNITP CORRECTIONS BJMcLfTLH SET IBP MVVfTLH LNR TOP PKR & DATUM UPDATE JJffiH PULL IBP I DATE REV BY COMMENTS 08/24/03 KF/KAK SAND DUMP 08/26/03 BJMlKK SET" IBP; TBG PUNa-! 05/14/04 KWA Proposed ColTpletion PRUDHOE BAY UNIT WELL: N-11B PERMIT No: ~991050 API No: 50-029-21375-01 SEC 8. T11 N, R13E, 1023' FSL & 540' FWL BP Exploration (Alaska) 4" CrN McEVOY AXELSON 78.7' 46.95' '42ÓÖi .................. . 101 @ 10945' - ,. .. .... .~. ..... NJA 8800' SS TREE = WELLHEAD = ACTUATOR = KB. ELEV = SF. B-EV = KOP= Max Angle = Datum MD = Datum1VD = ~ 113-3/8" CSG, 72#, L-80, ID = 12.347" l-i 2696' r--J Minimum ID = 2.441" @ 9608' TOP OF 2-7/8" LINER Chemical Cut -9230' Top Cement -9350' 1 TOP OF 7" LNR l-i 9599' I TOP OF 2-7/8" LNR (ÆR 07/04/03? PDS CALlÆR) l-i 9580' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 9641' 19-5/8" CSG, 47#, L-80, ID = 8.681" l-i 9867' ÆRFORATION SUMMARY REF LOG: PDS MEMORY INDUCT/GR ON 11/18/99 ANGLE A T TOP ÆRF: 95 @ 10820' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10820 - 10855 C 11/21/99 2" 4 10868 - 10897 C 11/21/99 2" 4 10919 - 10988 C 11/21/99 2" 4 11004 - 11041 C 11/21/99 2" 4 11052-11110 C 11/21/99 17" LNR, 26#, L-80, U451-i 9902' N-11 B Final Pre-Rig / ~~ - ~ = I' I i ~ ~.§.. I 9641' 1--14-1/2" TBG TAIL, ID = 3.958" 1 A I - .~~ :::: ::::DC:L::::3:~AILABLE I Apparent Parted liner @ 9925' and 10089' ./ from PDS long run on July 3, 2003. ~/ Milloul Window 9902'-9906' Ia.· 'fIfI L " / /~, I I ~,. -' ~ ~= - i ~'--, . ~ :g ~ "' t S~YNOTES: 70o@ 10321' & 90o@ 10474' 2094' 1--14-1/2" OTIS SSSV NIP, ID= 3.813" 1 ~ GAS LIFT MANDRB...5 ST MD lVD DEV ïYPE VLV LATCH PORT DATE 7 3790 3711 0 OTIS RA 6 5614 5315 46 OTIS RA 5 6821 6164 43 OTIS RA 4 7409 6608 40 OTIS RA 3 8010 7068 40 OTIS RA 2 8647 7536 43 OTIS RA 1 9260 7991 41 OTIS RA 9446' 1--14-1/2" OTIS XA SLIDING SLV, ID = 3.813" 9508' l-i TrN TBG SEAL ASSY I ,~~ ....... 9523' 1--19-5/8" X 4-1/2" TIW HBBP PKR 1 9547' - 9557'1-i TBG PUNCH (4 SPF) 1 9563' 1-i4-1/2" OTIS X NIP, ID = 3.813" 1 9593' I-iTOPO F SAND 1 9605' 1-f4-1/2" MILLED OTIS XN NIP, ID = 3.80" 9608' 1- 4-1/2" KB REf PKR W/BKR SEAL ASSY, ID = 2.40" 12-7/8" LNR, 6.16#, L-80, .00579 bpf, ID = 2.441" l-i 11204' DA TE REV BY COMMENTS 08/24/03 KF/KAK SAND DUMP 08/26/03 BJMlKK SET IBP; TBG PUNCH PRUDHOE BAY UNIT W8..L: N-11B ÆRMIT No: 1991050 API No: 50-029-21375-01 SEC 8, T11 N, R13E, 1023' FSL & 540' FWL DATE 05/13/81 11/21/99 03/09/02 07/16/03 08/17/03 08/20/03 REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK (N-11A) RNfTP CORRECTIONS BJMcLffiH SET IBP MWffiH LNR TOP PKR & DATUM UPDATE JJffiH PULL IBP n BP Exploration (Alaska) TREE = WB...LHEAD = ACTUA TOR = KB. B...EV = 'SF. ELS/ = KOP= Max Angle = . _._.............m......_.·_~...·_··,··.. Datum MD = Datum1VD = 4" CrN McEVOY AXB...SON 78.7' 46.95' 4200' 101 @ 10945' NIA 8800' SS '.~ 113-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2696' Minimum ID = 2.441" @ 9608' TOP OF 2-7/8" LINER I TOP OF 7" LNR 1-1 9599' TOPOF 2-7/8" LNR (ÆR 07/04/03? PDS CALlÆR) l-i 9580' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 9641' I 9-5/8" CSG, 47#, L-80, ID = 8.681" l-i 9867' ÆRFORA TION SUMMARY REF LOG: PDS MEMORY INDUCT/GR ON 11/18/99 ANGLEATTOPÆRF: 95 @ 10820' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 10820 - 10855 C 11/21/99 2" 4 10868-10897 C 11/21/99 2" 4 10919 - 10988 C 11/21/99 2" 4 11004-11041 C 11/21/99 2" 4 11052-11110 C 11/21/99 17" LNR, 26#, L-BO, U451-i 9902' N-11 B - ~ L I I i :8: ì ~ SAh:dYNOTES: 70° @ 10321' & 90° @ 10474' 2094' 1-i4-1/2" OTIS SSSV NIP, ID = 3.813" 1 ~ ST MD 1VD 7 3790 3711 6 5614 5315 5 6821 6164 4 7409 6608 3 8010 7068 2 8647 7536 1 9260 7991 GAS LIFT MANDRB..S DEV 1YÆ VLV LATCH PORT DATE OaTIS RA 46 OTIS RA 43 OTIS RA 40 OTIS RA 40 OTIS RA 43 OTIS RA 41 OTIS RA I 9446' 1-14-1/2" OTIS XA SLIDING SLV, ID = 3.813" I 9508' 1-1 TrN TBG SEAL ASSY 1 I 9523' l-i 9-5/8" X 4-1/2" TrN HBBP PKR 1 9547' - 9557'1-i TBG PUNCH (4 SPF) 1 9563' 1-i4-1/2" OTIS X NIP, ID = 3.813" 1 9593' l-i TOP 0 F SAND 1 9605' 1-14-1/2" MILLED OTIS XN NIP, ID = 3.80" 9608' 1- 4-1/2" KB REf PKR W/BKR SEAL ASSY, ID = 2.40" DA TE REV BY COMMENTS 08/24/03 KF/KAK SAND DUMP 08/26/03 BJM'KK SET IBP; TBG PUNCH 05/14/04 KWA Added tbg parts and org depths =I' ~ JIl'" '-' ~ ~~"'ì:: - or- = ! .1 ~ 9641' 1-14-112" TBG TAIL,ID = 3.958" ~ · J .~~ :::: ::::C:L::::3:~A~BLE Apparent Parted liner @ 9925' and 10089' / from PDS long run on July 3, 2003. ~/ MilloutWlndow9902'-9906' 12-7/8" LNR, 6.16#, L-80, .00579 bpf, ID = 2.441" l-i 11204' DATE 05/13/81 11/21/99 03/09/02 07/16/03 08/17/03 08/20/03 REV BY COMMENTS ORIGINAL COM PLETION SIDETRACK (N-11A) RN/TP CORRECTIONS BJMcLfTLH SET IBP . MWfTLH LNR TOP PKR & DATUM UPDATE JJfTLH PULL IBP n PRUDHOE BAY UNrr WB...L: N-11B ÆRMrr No: "1991050 API No: 50-029-21375-01 SEC 8, T11 N, R13E, 1023' FSL & 540' FWL BP Exploration (Alaska) ''''4> " -..,J1"" ~ ,/, ~~ ", ( Nome TVD +NI-S +EJ·W Nonhin¡ Eutina Shape N-IIC Faullljl 7619050 ·2598.91 -151057 5964326.00 634304.00 Poly¡on ~¡¡g~~ 8672050 ·3089058 -958055 5963821.00 633$()6.00 Poly¡on 8740050 ·3089.58 -958055 5963821.00 633$()6.00 Poial SECTION DETAILS Azi lVD +N/-S +FJ-W DLeg TFace VSee Target 186.11 7360.02 -2552.72 -30.21 0.00 0.00 2552.72 189.58 7374.53 -2566.36 -32.09 12.00 85.00 2566.36 260.30 8176.57 -3005.86 -468.61 4.50 117.63 3005.86 260.30 8636.98 -3078.84 -895.69 0.00 0.00 3078.84 260.31 8740.50 -3089.58 -958.55 19.00 179.99 3089.58 N-llC T1 D (' 260.31 8800.50 -3093.26 -980.07 0.00 0.00 3093.26 260.31 8988.44 -3104.77 -1047.50 0.00 0.00 3104.77 FORMATION TOP DETAILS No. TVDPath MDPath Formadon I 7645.50 8677.01 TJF 2 7815.50 8892.34 TJE 3 8050.50 9193.40 TID 4 8345.50 9594.23 TJC 5 8464.50 9757.63 TJB 6 8625.50 9978.71 TSGR 7 8660.50 10025.34 Shublh 8 8740.50 10116.90 TSAD 9 8800.50 10180.75 POWC TARGET DETAILS 634409.00 70'19'03.306N 148'5-4'37.642W NlA Nome +NI-S +EJ·W Nonhin¡ N-IIB 1488.15 1001.05 5966927.00 LonaiIUdc: SIo< LaIiIUdc: Eulins WELL DETAILS Date: Reviewed: Date: Checked: MWD+IF1l+MS Plan: N-IIC wpl2 (N·lIB/Plan N-llC) Created By: Digital Busi..... Client U.... Dale: 7/21/2004 Tool , ' , ' ).. '..-.. .-.... .-L -- ·s1IUtiDi:- t~IOO" 8~' M >;V360£2'1ivD ~ ...¡ ._ en _. ..\ . -..--- ·i··1 __ ___ SF Die 4.5/1 :xr : 832r 1Y..D. 7J14.p""Y) ..-¡ _...- . . --- ¡--- . t~~.·.·.·.···..l..............·....·. ···-···1 ¡ . ·'.IC FIlUII#I; ... . i j --+- --- --...--.------.--j 1-----------:.-.._· -- ---...------ --------.....: i i ..l i - ------------ ·------t--- i -------- i i = =====- ¡ --~----~-~--- I ¡ i ' - ---.- --------·--------f·- - ---.- ! - - -,---_._-~.__._- .-------- I - .----------- I --- I ----.----.-----------------______1 i I , "30 , . - ---0-- ____________________--bl.l ~ (J'I.llr) .. I I ._-~~~~_._-- -------~_.._--- --=-=~-_._. ¡ I.. 112" ------t------ , I ¡ I I - -- .---. -_._~=~=~ ----~----~~_._----- --+-~.=~-~=:==._~= .== \ I I .. 3900 .....___.__.1_______ .-- m._._____ ---- --.. . 43.36 UG Ð~ Ð~ moo 2QOO moo 8300.00 8320.00 9362.26 9994.47 10116.90 10180.75 10380.75 I 2 3 4 5 6 7 Inc See MD 7.000 4.500 Size SURVEY PROORAM Dcplh Fm Dcplh To SurvcylPlan 8JOO.00 10380.75 Planned: N-IIC wpl2 V46 CASING DETAILS 3600 3000 3300 Vertical Section at 180.00° [300ft/in] 2700 2400 9000 ---.'.. ----~ 8700 8400 _ ._'.'~___. .__.._..,..._____ ___.___4 9S I .... i 8100 ~ '€ ~ ~ 7800 ..-.-.....--...---."..- 7500 , . 8625.50 9978.71 7" 8987.74 10380.00 41/2" 7200 Name No. lVD MD REFERENCE INFORMATION Co-ordillllc JNÆ) Ref.........: Well CcI1bC: N·llB. True Nof1h VCI1ica1 (TYD) Refaeacc: 2805+46.95 75.$0 Soclioa (VS) Rcfcrcncc: Sial- (0.00N,0.00I!) M_~~~;=~O COMPANY DETAILS BP Amoco Qk:ulaôca MCIbod: Miaimum CUrvIIuIe == ~~~Nonh Error Swfoœ: EIIipIicaI + CaÅI¡ Womina MCIbod: R..... Buod COMPANY DETAILS BP Amoc:o REFERENCE INFORMATION Co«dinaœ (NIE) Refcrcncc: Wen Ccnw. N·II B. True Nor1h VCIÛCII (TVD) Ref....... 28.5+46.9575.50 Soction (VS) Rcfonmcc: Slot· (O.OON.O.OOE) MIIIIIRdCalcu~~-= ~~=~O SURVEY PROGRAM Depth Fm Depth To SlIMyi1'1an 8300.00 10380.75 PIannod: N-IIC wpl2 V46 Tool MWD+IFR+MS Plan: N·IIC wp12 (N-IIB/Plan N-IIC) Created By: Digital Businesa Client Use, Date: 7121/2004 CalcuIoIioa Mediad: Minmum CuMIwe =~ ~yW¿kNonh Error Swûœ: EUiplicll + Cain¡ Wamin¡ Mediad: Rulcl Bucd Checked: Date:_ WELL DETAILS Name +N/-S +EJ-W Nonhina Eulin¡ !..aþ!Udo Lon¡itudc SIoI N-IIB 1488.15 1031.05 5966927.00 634409.00 70oI9'03J06N 148°S4'37.642W N/A TARGET DETAILS -1800 6~0 l Name TVD +N/·S 7619.50 -2598.91 8672.50 -3089.58 8740.50 -3089.58 +EI·W Northing 5964326.00 5963821.00 5963821.00 Easting Shape 634304.00 Polyg:m 633506.00 Polygor' 633506.00 Point N-IIC Fault#1 N·IIC Polygon N·IICTl D -151.57 -958.55 -958.55 SECTION DETAILS See MD lne Azi TVD +N/·S +E/·W DLeg TFaee VSee Target -2100 I 8300.00 43.36 186.11 7360.02 -2552.72 -30.21 0.00 0.00 2552.72 2 8320.00 43.62 189.58 7374.53 -2566.36 -32.09 12.00 85.00 2566.36 3 9362.26 43.26 260.30 8176.57 -3005.86 -468.61 4.50 117.63 3005.86 4 9994.47 43.26 260.30 8636.98 -3078.84 -895.69 /0.00 0.00 3078.84 5 10116.90 20.00 260.31 8740.50 -3089.58 -958.55 19.00 179.99 3089.58 N·IICr D 6 10180.75 20.00 260.31 8800.50 -3093.26 -980.07 0.00 0.00 3093.26 700 7 10380.75 20.00 260.31 8988.44 -3104.77 -1047.50 0.00 0.00 3104.77 ( - ~,_.. ..--..-...-- -~-_.._,.,._---- __.______..I.-__~. _~_____._ ___ __ ..___ ----,-------'",.._- ---- -'- ..-".---.------ CASING DETAILS -2400 No. TVD MD Name Siz¡: , , ___, ._____..._ __,_'_~_.'.'_,__...___........_____ __.._..._, ".,_,._,_ .'. ...____ ___.___ .__ __..'_,.,___..,__'_,__, ,.__ ___..._e___._. .__.____._. .__ ,_" ____ , , ------.------- ---------+-------- -. .--.----- +------------------- ! -. ------- ----- ---.. -- -----...---j--- ..-.-..--- ..---. ___..__.._.__n__________ ----... ..--f------.--...-----....---- ------. i -- ----------. - .---- ..--.. ----.--------. .-.¡..---..----....--. . -...--.- --..-----.-.- ..--.-----.. -- -·-r--....- .---------- -----------....-. f -2700 :=~-- ,Œ~~~;~-;~~~~==~~~~~f~=~~~~ - ,-.---- ,,------~ ~-:iB(?oi-1 B' ~ ---- ---.. . . _ 7"1'·--" ------------~-_~ =~---~~ ___ -:::_:~~~:~------- r----.. _: :::.3_~_~_::>~_~~362..'261.MJ::~~.~~~~~-=- ~_::::::. :::.::~ -3000 =~ ~ '00.' , 4 II)" \ ßÞ """"" ------t-------· -------------- ----. ---=-~þ-t-N~HA-.:N.-)-I A]-------- ------.----.-- t------------·--·----- -.---- ., ',"'''''' I I #' --- -.-.---.-.-,- -'------ 8625.50 8987.74 9978.71 7" 10380.00 41/2" 7.0')(} 4.5 )(; FORMATION TOP DET AJLS No. TVDPath I 2 3 4 5 6 7 8 9 7645.50 7815.50 8050.50 8345.50 8464.50 8625.50 8660.50 8740.50 8800.50 MDPath 8677.01 8892.34 9193.40 9594.23 9757.63 9978.71 10025.34 10116.90 10180.75 TJF TJE TJD' TJC TJB TSC R Shu,lik TSPD POVv'C Fom¡.':tion ./' ! i ¡ _.- l' -I C w';)17 '"'''' """ .... ......1'... ( -3300 - -"-----,, -1200 -900 -600 -300 West(-)/East(+) [3ooftlin] o 300 600 ........,,/,.....,...,......:?:i.~ ......../_. .. /..<,,~ /...... ..........~, ~~ ¿f ...;¡..</. . c·~ 7' #.../', ... ,,", ---,--- ·3600 ----.--...- ._-.,- ----_.-..'-,_.,---,-~---_._.'-- -..---" c~ BP-GDB BP Plaûning Report '----/ Company: BP Amoco Field: Prudhoe Bay Site: PB N Pad WeD: N-11B Wellpath: Plan N-11C Plan: N-11Cwp12 Date: 7/2112004 Time: ·07:07:29 Page: 1 Co-ordinate(NE) Reference: Well: N-11 B, True North Vertical (TVD) Reference: 28.5+46.9575.5 Section (VS) Reference: Well (0.OON,0.OOE,180.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Principal: Yes Date Composed: Version: Tied-to: 5/14/2004 46 From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: PB N Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: 5965420.89 ft From: Map Easting: 633404.63 ft Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Latitude: 70 18 48.671 N Longitude: 148 55 7.726 W North Reference: True Grid Convergence: 1.02 deg Slot Name: Latitude: 70 19 3.306 N Longitude: 148 54 37.642 W Well: N-11 B N-11 B Well Position: +N/-S 1488.15 ft Northing: 5966927.00 ft +EI-W 1031.05 ft Easting: 634409.00 ft Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 9978.71 8625.50 7.000 8.500 7" 10380.00 8987.74 4.500 6.125 4 1/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 CM3 0.00 0.00 0.00 CM1 0.00 0.00 0.00 THRZ 0.00 0.00 0.00 BHRZ 0.00 0.00 8677.01 7645.50 TJF 0.00 0.00 8892.34 7815.50 TJE 0.00 0.00 9193.40 8050.50 TJD 0.00 0.00 9594.23 8345.50 TJC 0.00 0.00 9757.63 8464.50 TJB 0.00 0.00 9978.71 8625.50 TSGR 0.00 0.00 10025.34 8660.50 Shublik 0.00 0.00 10116.90 8740.50 TSAD 0.00 0.00 10180.75 8800.50 POWC 0.00 0.00 Targets Map M'ap <:,.;...:.- Latitude-'-> <-,.; Longitude,~. Name Description TVD +N/-S +EI-W Northing Easting Dei Min. See~ Deg MinSeC. . c Dip. Dir. ft ft ft ft . ft,· N-11C Fault#1 7619.50 -2598.91 -151.57 5964326.00 634304.00 70 18 37.746 N 148 54 42.063 W -Polygon 1 7619.50 -2598.91 -151.57 5964326.00 634304.00 70 18 37.746 N 148 54 42.063 W -Polygon 2 7619.50 -3435.14 73.52 5963494.00 634544.00 70 18 29.522 N 148 54 35.498 W -Plan out by 172.91 at 7619.50 -2764.67 -102.35 5964161.16 634356.17 70 18 36.116 N 148 54 40.627 W N-11 C Polygon 8672.50 -3089.58 -958.55 5963821.00 633506.00 70 18 32.920 N 148 55 5.599 W -Polygon 1 8672.50 -3164.13 -649.81 5963752.00 633816.00 70 18 32.187 N 148 54 56.594 W -Polygon 2 8672.50 -2903.67 -839.19 5964009.00 633622.00 70 18 34.748 N 148 55 2.118 W -Polygon 3 8672.50 -2963.35 -1193.34 5963943.00 633269.00 70 18 34.161 N 148 55 12.447 W -Polygon 4 8672.50 -3248.49 -1077.42 5963660.00 633390.00 70 18 31.357 N 148 55 9.065 W -Plan out by 35.08 at 8672.50 -3083.67 -923.97 5963827.52 633540.46 70 18 32.978 N 148 55 4.590 W N-11CT1 D 8740.50 -3089.58 -958.55 5963821.00 633506.00 70 18 32.920 N 148 55 5.599 W -Plan hit target '~' BP-GDB BP Planning Report ~ 2 Oracle Page: TlDle: 07:07:29 Well:N-11 B, True North 28.5+46.95 75.5 Well (O.OON,O.OOE, 180.00Azi)· Minimum Curvature Db: Date: 7/2112004 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Section (VS) Reference: Survey Calculation Method: BP Amoco Prudhoe Bay PB N Pad N-11 B Plan N-11C Company: Field: Site: Well: WeUpath: Plan Section Information MD Ind ft deg Target N-11CT1 D TFO deg 0.00 85.00 117.63 0.00 179.99 0.00 0.00 Build Turn deg/10OO degl1000 0.00 17.33 6.79 0.00 0.01 0.00 0.00 0.00 1.31 -0.03 0.00 -19.00 0.00 0.00 DLS degl1000 0.00 12.00 4.50 0.00 19.00 0.00 0.00 +F.J-W ft -30.21 -32.09 -466.61 -695.69 -958.55 -960.07 -1047.50 +N/-S ft -2552.72 -2566.36 -3005.66 -3078.64 -3069.58 -3093.26 -3104.77 TV» ft 7360.02 7374.53 6176.57 6636.96 6740.50 8600.SO 6968.44 Azim deg 186.11 189.58 260.30 260.30 260.31 260.31 260.31 43.36 43.62 43.26 43.26 20.00 20.00 20.00 6300.00 8320.00 9362.26 9994.47 10116.90 10160.75 10360.75 Survey MD ft TooVComment Start Dir 12/10 Start Dir 4.5/1 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MapE ft 634424.50 634422.66 634422.34 634419.49 634416.24 MapN ft 5964374.35 5964360.69 5964357.28 5964340.39 5964323.73 DLS degl100ft 0.00 12.00 4.50 4.50 4.50 E/W ft -30.21 -32.09 -32.67 -35.63 -39.36 N/S ft -2552.72 -2566.36 -2569.75 -2566.59 -2603.19 Sys TV» ft 7264.52 7299.03 7302.65 7320.86 7339.21 TV» ft 7360.02 7374.53 7378.15 7396.36 7414.71 Azim deg 186.11 169.56 169.67 191.33 192.62 Ind deg 43.36 43.62 43.52 43.01 42.52 6300.00 6320.00 6325.00 6350.00 6375.00 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 634412.56 634408.53 634404.07 634399.21 634393.96 5964307.31 5964291.14 5964275.23 5964259.56 5964244.19 4.50 4.50 4.50 4.50 4.50 -43.33 -47.67 -52.41 -57.55 -63.08 -2619.54 -2635.64 -2651.47 -2667.03 -2662.32 7357.71 7376.34 7395.10 7413.97 7432.96 7433.21 7451.64 7470.60 7469.47 7508.46 194.34 195.89 197.46 199.06 200.69 42.05 41.60 41.17 40.77 40.38 6400.00 6425.00 6450.00 6475.00 6500.00 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 634388.32 634362.28 634375.85 634369.03 634361.83 5964229.06 5964214.24 5964199.69 5964165.43 5964171.46 4.50 4.50 4.50 4.50 4.50 -66.99 -75.30 -61.96 -69.06 -96.51 -2697.34 -2712.06 -2726.50 -2740.64 -2754.47 7452.06 7471.25 7490.53 7509.90 7529.34 7527.56 7546.75 7566.03 7585.40 7604.64 202.34 204.01 205.71 207.43 209.17 40.02 39.66 39.37 39.06 36.62 6525.00 6550.00 6575.00 6600.00 6625.00 N-11C Fault#1 MWD+IFR+MS MWD+IFR+MS TJF MWD+IFR+MS 634356.17 634354.25 634346.29 634345.63 634337.95 5964161.16 5964157.79 5964144.43 5964143.36 5964131.36 4.50 4.50 4.SO 4.50 4.50 -102.35 -104.33 -112.53 -113.21 -121.10 -2764.67 -2768.00 -2761.22 -2762.26 -2794.12 7544.00 7548.86 7568.43 7570.00 7588.05 7619.50 7624.36 7643.93 7645.50 7663.55 210.49 210.93 212.71 212.65 214.50 36.64 36.58 36.37 36.36 36.19 6643.79 6650.00 6675.00 6677.01 6700.00 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 634329.24 634320.16 634310.72 634300.91 634290.74 5964118.65 5964106.24 5964094.15 5964062.40 5964070.97 4.50 4.50 4.50 4.50 4.50 -130.04 -139.34 -149.00 -159.02 -169.39 -2806.69 -2618.94 -2830.66 -2642.44 -2853.66 7607.72 7627.43 7647.17 7666.93 7686.71 7683.22 7702.93 7722.67 7742.43 7762.21 216.30 216.12 219.95 221.78 223.62 36.03 37.91 37.61 37.74 37.69 6725.00 6750.00 6775.00 6600.00 6625.00 MWD+IFR+MS MWD+IFR+MS TJE MWD+IFR+MS MWD+IFR+MS 634260.22 634269.35 634261.61 634258.13 634246.57 5964059.89 5964049.15 5964041.91 5964036.76 5964028.72 4.50 4.50 4.50 4.SO 4.50 -180.11 -191.17 -199.04 -202.57 -214.31 -2864.57 -2875.11 -2862.22 -2865.30 -2895.13 7706.50 7726.28 7740.00 7746.06 7765.82 7762.00 7801.78 7815.50 7621.56 7641.32 225.46 227.30 226.57 229.14 230.97 37.68 37.69 37.72 37.74 37.81 6650.00 8875.00 6692.34 6900.00 6925.00 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 634234.66 634222.45 634209.69 634197.01 634163.81 5964019.04 5964009.72 5964000.76 5963992.16 5963963.94 4.50 4.50 4.50 4.50 4.50 -226.38 -238.78 -251.49 -264.53 -277.87 -2904.60 -2913.71 -2922.44 -2930.60 -2938.79 7765.56 7805.27 7824.94 7844.56 7864.14 7861.06 7880.77 7900.44 7920.06 7939.64 232.79 234.61 236.42 238.21 239.98 37.91 36.03 36.19 36.37 38.58 6950.00 6975.00 9000.00 9025.00 90SO.00 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 634170.29 634156.47 634142.35 634127.93 634113.21 5963976.06 5963968.61 5963961.51 5963954.80 5963948.46 4.50 4.50 4.50 4.50 4.50 -291.53 -305.48 -319.73 -334.27 -349.10 -2946.40 -2953.63 -2960.47 -2966.93 -2973.00 7883.65 7903.09 7922.46 7941.74 7960.93 7959.15 7978.59 7997.96 6017.24 6036.43 241.74 243.48 245.20 246.90 248.58 36.82 39.08 39.37 39.66 40.02 9075.00 9100.00 9125.00 9150.00 9175.00 TJD MWD+IFR+MS MWD+IFR+MS 634102.20 634098.21 634062.93 5963944.05 5963942.52 5963936.96 4.50 4.50 4.50 -360.19 -364.20 -379.58 -2977.22 -2978.68 -2963.96 7975.00 7980.03 7999.02 6050.50 8055.53 6074.52 249.79 250.23 251.85 40.29 40.38 40.77 9193.40 9200.00 9225.00 --~ BP-GDB BP Planning Report - 3 Oracle Page: Time: 07:07:29 Well: N-11B, True North 28.5+46.95 75.5 Well (0.ooN,0.00E,180.00Azi) Minimum Curvature Db: Date: 7/21/2004 Co-ordinate(NE) Reference: Vertical (fVD) Reference: Section (VS) Reference: Survey Calculation Method: BP Amoco Prudhoe Bay PB N Pad N-11B Plan N-11C Company: Field: Site: Well: Wellpath: Survey MD ft Tool/Comment MapE ft MapN ft DLS degl100ft EIW ft N/S ft Sys TVD ft TV» ft Azim deg loci deg MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS End Dir : 9362 MWD+IFR+MS 634067.38 634051.56 634035.47 634019.13 634002.54 633994.32 633985.74 5963931.80 5963927.02 5963922.65 5963918.67 5963915.08 5963913.47 5963911.85 4.50 4.50 4.50 4.50 4.50 4.50 0.00 -395.23 -411.13 -427.30 -443.71 -460.36 -468.61 -477.22 -2988.84 -2993.33 -2997.42 -3001.11 -3004.40 -3005.86 -3007.33 8017.89 8036.65 8055.28 8073.77 8092.13 8101.07 8110.35 8093.39 8112.15 8130.78 8149.27 8167.63 8176.57 8185.85 253.45 255.02 256.57 258.09 259.58 260.30 260.30 41.17 41.60 42.05 42.52 43.01 43.26 43.26 9250.00 9275.00 9300.00 9325.00 9350.00 9362.26 9375.00 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 633968.90 633952.07 633935.24 633918.41 633901.57 5963908.66 5963905.47 5963902.28 5963899.10 5963895.91 0.00 0.00 0.00 0.00 0.00 -494.11 -511.00 -527.89 -544.77 -561.66 -3010.22 -3013.10 -3015.99 -3018.87 -3021.76 8128.56 8146.76 8164.97 8183.17 8201.38 8204.06 8222.26 8240.47 8258.67 8276.88 260.30 260.30 260.30 260.30 260.30 43.26 43.26 43.26 43.26 43.26 9400.00 9425.00 9450.00 9475.00 9500.00 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS TJC MWD+IFR+MS 633884.74 633867.91 633851.08 633838.13 633834.24 5963892.72 5963889.53 5963886.35 5963883.89 5963883.16 0.00 0.00 0.00 0.00 0.00 -578.55 -595.44 -612.33 -625.31 -629.21 -3024.65 -3027.53 -3030.42 -3032.64 -3033.30 8219.59 8237.79 8256.00 8270.00 8274.20 8295.09 8313.29 8331.50 8345.50 8349.70 260.30 260.30 260.30 260.30 260.30 43.26 43.26 43.26 43.26 43.26 9525.00 9550.00 9575.00 9594.23 9600.00 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 633817.41 633800.58 633783.75 633766.91 633750.08 5963879.97 5963876.78 5963873.59 5963870.41 5963867.22 0.00 0.00 0.00 0.00 0.00 -646.10 -662.99 -679.88 -696.77 -713.66 -3036.19 -3039.08 -3041.96 -3044.85 -3047.73 8292.41 8310.62 8328.82 8347.03 8365.23 8367.91 8386.12 8404.32 8422.53 8440.73 260.30 260.30 260.30 260.30 260.30 43.26 43.26 43.26 43.26 43.26 9625.00 9650.00 9675.00 9700.00 9725.00 MWD+IFR+MS TJB MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 633733.25 633728.11 633716.42 633699.58 633682.75 5963864.03 5963863.06 5963860.84 5963857.66 5963854.47 0.00 0.00 0.00 0.00 0.00 -730.54 -735.70 -747.43 -764.32 -781.21 -3050.62 -3051.50 -3053.51 -3056.39 -3059.28 8383.44 8389.00 8401.65 8419.85 8438.06 8458.94 8464.50 8477.15 8495.35 8513.56 260.30 260.30 260.30 260.30 260.30 43.26 43.26 43.26 43.26 43.26 9750.00 9757.63 9775.00 9800.00 9825.00 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 633665.92 633649.09 633632.25 633615.42 633598.59 5963851.28 5963848.09 5963844.91 5963841.72 5963838.53 0.00 0.00 0.00 0.00 0.00 -798.10 -814.98 -831.87 -848.76 -865.65 -3062.16 -3065.05 -3067.94 -3070.82 -3073.71 8456.27 8474.47 8492.68 8510.88 8529.09 8531.77 8549.97 8568.18 8586.38 8604.59 260.30 260.30 260.30 260.30 260.30 43.26 43.26 43.26 43.26 43.26 9850.00 9875.00 9900.00 9925.00 9950.00 MWD+IFR+MS 7" Start Dir 19/10 MWD+IFR+MS MWD+IFR+MS 633581.76 633579.26 633568.65 633564.96 633549.23 5963835.34 5963834.87 5963832.86 5963832.16 5963829.18 0.00 0.00 0.00 19.00 19.00 -882.54 -885.05 -895.69 -899.39 -915.17 -3076.59 -3077 .02 -3078.84 -3079.47 -3082.17 8547.30 8550.00 8561.48 8565.54 8584.73 8622.80 8625.50 8636.98 8641.04 8660.23 260.30 260.30 260.30 260.30 260.30 43.26 43.26 43.26 42.21 37.46 9975.00 9978.71 9994.47 10000.00 10025.00 Shublik N-11 C Polygon MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 633549.03 633540.46 633535.12 633522.72 633512.11 5963829.14 5963827.52 5963826.51 5963824.16 5963822.16 19.00 19.00 19.00 19.00 19.00 -915.38 -923.97 -929.33 -941.77 -952.41 -3082.21 -3083.67 -3084.59 -3086.72 -3088.53 8585.00 8597.00 8605.18 8626.75 8649.29 8660.50 8672.50 8680.68 8702.25 8724.79 260.30 260.30 260.30 260.31 260.31 37.40 34.58 32.71 27.96 23.21 10025.34 10040.18 10050.00 10075.00 10100.00 N-11C T1 D MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS POWC 633506.00 633503.28 633494.88 633486.47 633484.54 5963821.00 5963820.48 5963818.89 5963817.30 5963816.94 19.00 0.00 0.00 0.00 0.00 -958.55 -961.28 -969.71 -978.13 -980.07 -3089.58 -3090.05 -3091.49 -3092.93 -3093.26 8665.00 8672.61 8696.11 8719.60 8725.00 8740.50 8748.11 8771.61 8795.10 8800.50 260.31 260.31 260.31 260.31 260.31 20.00 20.00 20.00 20.00 20.00 10116.90 10125.00 10150.00 10175.00 10180.75 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 633478.07 633469.67 633461.27 633452.87 633444.47 5963815.71 5963814.12 5963812.54 5963810.95 5963809.36 0.00 0.00 0.00 0.00 0.00 -986.56 -994.99 -1003.42 -1011.85 -1020.28 -3094.36 -3095.80 -3097.24 -3098.68 -3100.12 8743.09 8766.58 8790.08 8813.57 8837.06 8818.59 8842.08 8865.58 8889.07 8912.56 260.31 260.31 260.31 260.31 260.31 20.00 20.00 20.00 20.00 20.00 10200.00 10225.00 10250.00 10275.00 10300.00 ,-,. BP-GDB BP-Planning Repo:rt .- Company: BP Amoco Date: 7/21/2004 Time: ·07:07:29 Page: . 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: N-11B, True North Site: PB N Pad Vertical (IVD) Reference: 28.5+46.95 75.5 Well: N-11 B Section (VS) Reference: Well (O.OON,O.OOE, t80.00Azi) WeUpath: Plan N-11C Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W DLS MapN MapE TooJ/Comment ft deg deg ft ft ft ft degl100ft ft ft 10325.00 20.00 260.31 8936.05 8860.55 -3101.56 -1028.71 0.00 5963807.77 633436.07 MWD+IFR+MS 10350.00 20.00 260.31 8959.54 8884.04 -3103.00 -1037.13 0.00 5963806.18 633427.67 MWD+IFR+MS 10375.00 20.00 260.31 8983.04 8907.54 -3104.44 -1045.56 0.00 5963804.59 633419.27 MWD+IFR+MS 10380.00 ~ 20.00 260.31 8987.74 8912.24 -3104.73 -1047.25 0.00 5963804.27 633417.59 4 1/2" 10380.75 20.00 260.31 8988.44 8912.94 -3104.77 -1047.50 0.00 5963804.22 633417.34 MWD+IFR+MS SONDRA D STEWMAN BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 PAY TO THE ;} I-V-" /" I~ ORDER OF /~ \..L....Å.:....., l" '--' {)1'1 E?_--W U-,V\c\..~(C.cL. First National '~nk' Alaska Anchorage, AK 99501 M~ î"\-\\C . "Mastercard Check" 89-6/1252 1 07 DATE (J7-l~- tfj I $lLl)oCC} \~, C>--y,\r:l ___-((\ v\~:5 ' - DOLLARS ( ~~/~ C _-~~~$t-~-,V'--"--_."--,.._- I: ~ 2 5 2 0 0 0 b 0 I: ~ ~ ~ L. II' b 2 2 7 II' ~ 5 b L. II- 0 ~ 0 7 ( ""-' ~ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAMEfi1tt ¡J-//C PTD# ;20 t¡ - / 'Ý ~?_ )( Development Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTJ LATERAL (If API number Jast two. (2) digits are between 60-69) PILOT (PH) Exploration Stratigraphic "'CLUE"· The permit is for a new weJJbore 'segment of existing weD', . Permit No, " API No. ProductioD. sbould continue to be reponed as a function' of tbe original API Dumber. stated above. . HOLE In accordance witb' 20 AAC 25.005(1), an records, data and logs acquired for the pilot bole must be clear]y differentiated "in botb name (name on permit plus PH) and API number (SO_ 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTJON DRY DITCH SAMPLE Tbe permit is approved subject ,to fuD comp)jance with 20 AAC 2S..0SS~ Approval to perforate and produce is contingeDt UpOD issuance of ~ conservation order approviDg a spa dng e:x ception. (Company Name) assumes tbe liability of any protest to tbe spacing . ~:Jception tbat may occur. An dry ditch sample sets submitted to tbe Commission must be iD no greater tban 30' sample intervals from below the permafrost or from wbere sampJes are first caught and ] 0' sample h:iter:vals through target zones. :.\N~LL P~~MI~ CHECKLI~1\: Field & Pool._'=~~E_~9~~A Y, PRU!?.~9E OIL - 640150 Well Name: ERUJ¿Hº~.-ªðYJJJ~~II_~.:.tlC PTD#: 2041420 Company J3f!.J~XeJ.º8All.ol~U8LASJ~8)Jt-.J'<~..._._..__._n_._____.______._____._ Initial Classrrype __PJ;V L1.:..0J_L___ GeoArea _aJ~_O Administration 1 pe(mitfee attache.d. . . . . . . . . . . . . . _ .Y~s. . . . . . . . . . . . 2 .Leas~ .number .apRrop-riate. Yes. 3 _U.nique welt n_a!Jl~ _anq O~lTJb_er _ . _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ _ . . . . - - - . . - . - - - - - . .Y~$ . - - - - - - - - . - - - - - - - - - - - - - - - - . - - . - - - - - - - - - - - - - - - - - . . - - - - - - . - . - - - - - . - - - - - - - - - - - 4 WellJQcat~d in.a. d.efine.d .pool. . . . . . . . Yes - . . . . - - - . - - - - . . . . - - . . . . . . . . - . . . . . 5 _WellJQcated pr.oper .distance. from driJling unit.b.ound.al)'. . .Y~s . . . . . - . . . . . - 6 .Well JQcat~d pr.oper _distance_ from Qtber wel!s. . . _ _ _ . . . . . . . . . . . . . . Yes 7 .S.ufficientacreage.ayailable in.drilJiOg un.it. . . . . . . . . . _ . . . . . . . . . _ _ . . .Y~$ _ . . _ _ . . . . - . - . . . . . . . . - . - . . . . . . . - . . 8 Jf.d~viateq. .is. weJlþQre platincJu_ded . . . . . . . _ . . . . Yes - . . . . . . - 9 _Qper:ator only- affected party.. _ . . _ _ _ . . . . . _ . _ _ . _ . . . _ 'y~s .. . . - . . - . - - - - . - - - . . . - - - . .. - . . . - . - .. . . . . . . . . . . . . 10 _Qper.ator bas_appropriate_ b.ond tnJQrce _ . _ _ _ _ .. . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . Yes _ - . _ - - - . - . - - - - - - - - - - - - - - - . - . . . . - - - - - - - - . . - - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - 11 P~rmit c.an þe issued w.itbQut co.nserva.tion order. _ . _ _ . . . . _ _ _ Y~s . . . . . - - . - . . . . . . - . - . .. - - - - - . . . . . - - . - . . . . . . - . - - . Appr Date 12 P~rmit c_an þe iS$u.ed w.itbQut acl.mini~tr:ati\(e_approvaJ . . _ _ _ . . . . __ _ . . _ . . . _ . Yes - - - - - . - . - - - - - - - . . . . . . . . . . - . . . . .. ........ - - . . . . . . . . . - . . - - . - . . RPC 7/27/2004 13 Can permit be approved before 15-daywait Yes 14 .WelUQcatecl within area and.strata _authorized by_lojectioo Ord~r # (putlO# in_colJ1rn.ents).(For. NA. . . - - . . . . . . - - - - - - . - . - . . . . . - - . - - - . - . . . . - - - - . . . . . - - - - - - - - - . - . . . - 15 _AJI WeUs_WitJ1i.n.1(4_llJite_are.a.of reyieW id~ot[fieq (FO($.erv.ic~_w.etlOI1Iy-). _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . . - - - - - - - - . - - . - - - - - - - - - . - - - - - - - - 16 Pre-produçed injectQr; .durat.iQn_of pre-:pro.ch,lctiol'J I.ess. than 3. montbs. (for.servtce well QnJy) . _ NA. _ . _ _ _ . _ . . - - - - - .. . . - - - . - - . - . . - - . .. - - . . . . . . . .. .. - - - . . . - - . - - - - - - - - - - . - - - . . 17 .ACMP_ F:inding _of CQn.si.st.ençy_ h.as bee.n .is.sue.d for.tbi$ pr.olect _ _ . _ . . . . . _ _ _ . _ . . _ NA _ . . _ . . . - - . - . .. . - . . . . . . - . - . - - - . . . . . . . . - - . . . . . . - - - . - - . . . - . - . - - . Engineering Appr Date WGA 7/27/2004 Geology Appr RPC Date 7/27/2004 ------.---------...-.-..- ..___._____._Program JlEy_..______..n._ .._m Well bore seg Unit JJ.6.5_0 On/Off Shore PJl_______ Annular Disposal o l.J - - - - ~ - - - - - - . - - - . - - - - - - - ( --._._------~- 18 _C.ondu.ctpr st(ing_PfQvided _ _ _ _ . _ .. .. _ _ . _ . . .. . _ _ .. _ _ .. . . _ . . .. . _ _ _ NA. - - - . . - - .. - - - - . . . - . . . - - - - - - . - . . -- - . - - . - - - - - - . - . - - - .. - - - . - . - . . - . . . - . - - - - - - . - 19 .S_urJac~_casing_PJQtect$. all_known USDWs _ . . _ _ _ _ _ _ . . _ . . . . . . . _ . . . . _ NA - - . - . . . .. - - - - - - . . - .. . - . . . . - . - . - . . . . . . . .. . . . - . . - . - - . - . . . - - . . - - .. . - . . - - - - 20 .CMTv.otadequ.ate.to circ_utate_on.cOl'Jd.uctor_& SUJf.c.$g . . . . _ _ . . . . . . _ . .. ..... _ _ _NA. _ . _ _ . . - - - - - . . . . . . . . - . - . - . - . . . . - . . .. .. - . . . . - . - - . . - - - .. - - - . . . . . . . .. . - .. - - .. 21 .CMT v_ot adequ.ate.to tie-tnJQng _string to_sJ,JrJ c~g. .. _ . . _ _ _ _ . . . . _ . . . . _ _ _ _NA - - - . - - - - - . . . . . - _. . - - - - . - - . . . . - - . - - - .. . . . . - - . - - - - - . - . . . . . - - . - .. - - .. - - - - - . - 22 .CMT will çoyer.a!lklJown _pro.ductiye. bQri~Qn.s_ _ . _. .... _ _ _ _ _ . _ . _ _ _ _ _ . .. .. Yes. . - - . - - - . . . . . - . - - - - - . - . . . - . .. .. . - - -- . . . . . . . . - - .. - . - - - . - - . - . - . .. . . - - - - - - 23 _C_asiog d.e.si.g[1~ adequa.te f.or C,.T., B.&.p-ermafr.ost . . . . _ . . . . . . _ _ _ . .. . . . _ Y~s - - - - .. - - . . - - . - - - - - . . . . - - . . . - - .. - - . . . . - . . . - . - - - . - - . . - - . - . .. - . . - - -- . 24 .A.dequate.tan.kage_oJ re.serye pit. _ _ . . . _ .. _ _ _ _ . . _ _ _ . _ _ . _ _ _ _ _ _ . . _ . _. _.. .Y~$ _ _ . . _ . . ~ab_ors_7.ES,. . . . . - .. - . - - . - .. - - . - . . - . . - - - - - - . . . - - - - - - - . - - - - -- - - - - - - - - . . - . - - - 25 Jf.a..re-.drilt bas_a. 1.0:-4.0;3 fQr aba.ndon.me_nt be~o apPJQvßd . . . . . _ _ _ .. _ _ . . . . _ . Y~s . _ . _ . . . 7/2Q/20_0~.. . - . - . . . - - - - . - . . - - . . - - . - - - - -............ - - - . . - . - - . . . . . - . . . - - . 26 _A.dequate_w.e!lbore.$.ept;;lr¡:¡tio_n_prQPo~ed. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ .Y~$ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - . 27 Jf.divßr:ter Jeq.uired., CQes .it m.e~t. reguJatiol'Js. .. _ _ . . _ _ _ _ . . _ _ . _ _ _ _ _ _ . _ . . . _NA _ _ _ _ . . . Sidetrack. - - - - . . . . . . - - - - - - - - - . . . . - - - .. . - - .. . - - . - . . - . . . - . . - . - .. - - - . .. . .. . - . 28 .DJilIiog flujd. p-rogram schematic_& eq.uipJistadequate_ . _ _ _ ... _ .. _ .. .. . _ . . _ _ .. .. . . . Y~s _ _ _ _ .. . . Max MW.tO.9_ppg.. . . . . . - . - - - - - . . . . . . . . . - - . - - . - - . - - . . . . . . . . - . - . - . . . . . . . . . . - 29 .S.o.PEs,.d.o .they meßt. reguJa.tiol'J . . . . . . . . _ _ _ . _ . ._ _ . _ _ _ _ . . . .Y~s - . .. - . - . . . .. . . . - . . .- - .. - . . . . .. .. - - . - - . . . - . . . . . - . . - 30 .S.oPE.pre.s$ ratiog ap.propriate.; .test to _(pu.t PSig i.n _C9mmelJts) _ . . _ _ _ _ .. _ . _ _ . .. .. _ _ . . . Y~s _ _ _ _ . . . Test to _3500_ p-si. .!\lISP 22.95 psi.. - . - - . - - - . . . - - - - - - . . - - . . . - . - . . . . . . .- - . 31 .C_hoke.roanifolçl CQmpJies_ w/API. RP-53 (May 84). _ _ _ .. . _ . .. . _ _ . . . _ y~s . - - - - . - - - - - . . . . - . . . . - . - . - - . . - . - . . . . . . . . . . . . . . . - . - . . . . . . . . - - . . . . - - - . - - . - - - 32 .WQrk will occ.ur withoyt.operation _sbutdown. _ . . .. .. . . . _ . _ . _ . _ _ _ _ _ . . . .. .Y~s . - . - - . - . - . . . - - - - - -.... - - - . . . - - - .. . . . . . . . . . . - - - - - - .. - - - . . . . . . . 33 .Is. pres.ence_ Qf H2S gas_ p-rQb.aþIß _ _ _ . _ . . . _ _ . . . _ _ _ _ _ _ _ . _ _ _ . . . . . . _ _ _ _ Y~s . . _ _ .. . _ 10_0_PPIJ1. . . - - . - - - . - . . - . . . - - - - - - - - - - - . . . . - - . - - - - - - . - - - - - - . - - - . - . .. . . . . - - - 34 Mecba.nical_coodjtton.of wells within AOR yerified (For s.ervice w~U only) _ . _ _ .. . _ . . . . . . . _NA . . . - . . . - . . . . . . . . - . . . - . - - - - - - .. - - - - . . - .. .. - - . - - - - - - - - - - - - - - - - . - . . - .. - . - 35 P~rmit. c_ao Þe iss~eçl wlo. hydr:ogen. s.ulfide. meas_ures. _ . _ _ . . . . _ .. _ _ _ . . . 36 _D.ata.PJeseoteC on_ p-ote.ntial oveJp-re$.sur~ .zones _ . . _ .. .. _ _ _ . . . . _ _ . . . 37 .S~i.slJ1ic.analysjs. Qf .$hallow gas.zooes. . . . _ .. _ . . _ . . _ . _ _ .. _ _ . . . 38 _S~abed _C9I1d.itioo survey _(if Qff-~h_o(e) _ .. .. _ .. .. . . .. . _ _ . . . . 39 _ GQnta.ct nam.elpJ1one_ fQr_w.eßkly progre~s_rep-ort$ [exploratory .only). _ _ _ _ _ . . . G~lo~i,: I· I J ~1:~~r, ~\;. V #h' Engineering Commissioner: Date ( _.-,-_..._.~--."._-- _ . . . _ _ . _N.o_ _ _ _ _ _ _ _ . _ . . . _ _ _ .. _ _ _ .. . . _ _ _ _ . _ _ _ _ _ . _ ... _ _ . . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ . . . . . _ . _ . . . _ . _ _ . . .NA. . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . . _ . . _ _ _ _ . _ . .. . . . . _ _ _ . .. .. .. _ _ _ _ . _ _ . _ _ _ ..... .NA _ _ _.... _' _.. _ _.. _. _.... _.. _ _ _... _.. -. -. .. -- -.. - - - -... -. -...- .... _N.A_ _ _ _ _... _ _ _ _ ... _.. _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _. _ _. _ _. _. _ _ _ _ _ _ _ _.. .. _. _.. _ _ _ _ _ _NA_ _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ . . _ _ .. _ _ _ _ _ .. _ _ . . _ _ _ . . _ _ _ _ _ _ _ _ _ .. _ _ _ .. _ _ _ .. _ _ _ . . _ _ _ .. ~#c "- - Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, intormation of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. "'-- .- cXocf - ('-Ie:¿ "--' Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 ~ Mon Oct 11 09:09:01 2004 J~7ði Reel Header Service name.. ...........LISTPE Oat e . . . . . . . . . . . . . . . . . . . . . 04/10/11 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOvm Continuation Number......01 Previous Reel Name.......UNKNOWN Cowments..... ............STS LIS Writing Library. ~ J Scientific Technical Services Tape Header Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 04/10 III Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. ...... .........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Co~@ents............ .... .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TÞ,PE HEADER Prudhoe bay ¡·1f¡.m/MF.D LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COHPANY: TAPE CREATION DATE: # JOB DATA N-IIC 500292137502 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 1l-OCT-04 JOB NU¡'1BER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MT¡W003218334 P. SMITH D. FERGUSON M\^1D RUN 2 MW0003218334 P. SMITH D. FERGUSON l'1WD RUN 3 MW0003218334 P. SMITH Þ.. MADSEN # SURFACE LOCATION SECTION: TOv-mSHIP: RANGE: FNL: FSL: FEL: fIr?L : ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 8 llN 13E 1023 540 75.56 46.95 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING BIT SIZE (IN) SIZE (IN) 8.500 9.625 6.125 7.000 DRILLERS DEPTH (FT) 8308.0 9920.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. RECE\Veo OCT 2. 0 20Q4 .-' . "" . ""'fins eommission ü,Jaskâ Uit &. Gas \jVõ" , Anci1mage 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). ,-,. '~ 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE N-llB WELLBORE. THE TOP OF THE vlliIPSTOCK WAS POSITIONED AT 8308'MD AND THE BOTTOM Í^7AS AT 8324 'MD. 4. t~JD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. 5. ~MD RUNS 2 & 3 COMPRISED DIRECTIONAL; DUAL GA~f~ RÞX (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4(EWR4). t~D RUN 2 ALSO INCLUDED PRESSURE WHILE DRILLING (Pvm). V~D PASS DATA WERE ACQUIRED OV~R THE RUN 1 INTERVAL WHILE POOH AFTER REACHING TD OF RUN 2. THESE DATA ~ŒRE MERGED WITH RUN 2 ¡',WID DATA. 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED- HOLE G~~~ RAY RUN ON 28 AUGUST 2004. THESE LOG DATA 1iÆRE PROVIDED BY K. COONEY (SIS/BP) ON 17 SEPTEMBER 2004. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 - 3 REPRESENT WELL N-llC WITH API#: 50-029-21375-02. THIS vÆLL REACHED A TOTAL DEPTH(TD)OF 10400'MD!9005'TVD. SROP SMOOTHED RATE OF PENETR~TION 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 SPACING) . SFXE = SMOOTHED FORV~TION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS, REFLECTING BIT DEPTHS. $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date oÍ Generation.......04/10/11 Maximum Physical Record. .65535 F i 1 e Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED W~D Depth shiÍted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 lL It FILE SUJI1MARY PBU TOOL CODE SGRC SFXE SEDP SEMP SESP SEXP SROP $ START DEPTH 8162.5 8283.5 8283.5 8283.5 8283.5 8283.5 8313.0 STOP DEPTH 10354.5 10361.5 10361.5 10361. 5 10361. 5 10361. 5 10402.0 BASELINE CURVE FOR SHIFTS: ..~~ ~c CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 8162.5 9303.5 9314.0 9321.5 9331.0 9344.5 9347.0 9350.5 9354.0 9365.0 9375.5 9384.0 9394.0 9403.0 9433.5 9436.5 9449.5 9462.5 9539.0 9569.5 9580.0 9583.5 9619.0 9632.5 9653.5 9666.0 9674.0 9683.5 9703.0 9719.5 9724.0 9730.5 9740.5 9743.5 9758.5 9777.5 9796.0 9892.5 9903.0 9911.0 9916.0 9923.0 9926.5 9931.0 9936.0 9951.0 9962.0 9968.0 9974.0 9977.0 9979.5 9981.0 9983.5 9987.5 9992.0 9996.0 10004.0 10007.5 10014.5 10018.0 10020.0 10022.5 10028.0 10037.5 10040.5 10045.0 10052.5 10060.5 10062.5 10065.0 10072.5 10076.5 GR 8159.0 9300.0 9309.5 9316.0 9326.5 9339.0 9344.0 9347.5 9349.5 9361.0 9371.5 9378.5 9389.0 9397.0 9430.5 9432.5 9445.0 9456.5 9534.5 9563.5 9575.0 9579.0 9615.0 9626.5 9649.5 9659.0 9666.5 9678.0 9697.5 9714.0 9717.5 9722.5 9731. 5 9734.5 9753.5 9774 . 0 9791. 5 9892.5 9903.0 9909.0 9912.5 9924.0 9927.0 9930.5 9936.5 9955.0 9964.5 9969.5 9974.0 9977.5 9980.0 9982.5 9984.5 9987.5 9993.0 9996.5 10004.5 10009.0 10015.5 10019.5 10022.0 10024.0 10029.5 10039.0 10042.0 10047.0 10053.5 10062.5 10064.5 10066.0 10072.5 10077.0 '~. ..~ 10080.0 10083.0 10086.0 10088.5 10097.0 10110.0 10116.0 10119.5 10124.0 10129.0 10134.0 10135.5 10139.5 10143.5 10147.5 10153.0 10156.5 10164.5 10170.0 10174.0 10178.0 10181.5 10185.0 10189.5 10204.0 10211.5 10214.5 10216.5 10218.5 10221.5 10224.0 10236.0 10238.5 10243.5 10249.5 10254.5 10258.5 10264.5 10267.5 10402.0 $ 10080.0 10083.0 10086.0 10088.5 10098.5 10108.0 10114.0 10118.5 10123.5 10127.5 10133.0 10135.0 10139.5 10143.5 10146.0 10152.0 10156.5 10163.0 10172.0 10176.0 10179.0 10182.5 10185.5 10189.0 10204.5 10211.5 10214.5 10217.0 10218.5 10222.0 10224.0 10236.0 10239.0 10243.0 10249.5 10254.5 10259.0 10262.5 10265.5 10400.0 # HERGED DATA SOURCE PBU TOOL CODE !'-fvm MWD ¡V¡í"m $ BIT RUN NO 1 2 3 MERGE TOP 8309.5 8338.5 9920.0 MERGE BASE 8338.5 9920.0 10400.0 # REMARKS: MERGED t1AIN PASS. $ Data Format Specification Record Data Record Type....... .... .......0 Data Specification Block Type.....O Logging Direction..... ...... ......Down Optical log depth units... ...... ..Feet Data Reference Point.. ...... ......Undefined Frame Spacing.... ............. ....60 .1IN Max frames per record. ............Undefined .Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP !'1V'JD FT/H 4 1 68 4 2 GR HWD API 4 1 68 8 3 RPX !'1V'JD OHf'1M 4 1 68 12 4 RPS HWD OHMM 4 1 68 16 5 RPM M'fm OHMM 4 1 68 20 6 RPD HWD OHMM 4 1 68 24 7 fET !"f¡^lD HOUR 4 1 68 28 8 ,~~. '-.".../ First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8162.5 10402 9282.25 4480 8162.5 10402 ROP ¡V¡WD FT/H 1. 23 413.23 106.105 4179 8313 10402 GR MWD API 12.41 566.99 99.1665 4385 8162.5 10354.5 RPX M'fJD OHMM 0.6 2000 6.44742 4157 8283.5 10361. 5 RPS MWD OHl'-'¡f/¡ 0.96 1557.24 5.76433 4157 8283.5 10361. 5 RPM MWD OHMM 0.43 2000 7.02807 4157 8283.5 10361.5 RPD ¡'-'fwD OHMM 0.16 2000 51.5352 4157 8283.5 10361. 5 FET tvfvW HOUR 0.29 56.6541 3.56865 4157 8283.5 10361.5 First Reading For Entire File..........8162.5 Last Reading For Entire File...........10402 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.... ...04/10/11 Maximum Physical Record..65535 File Type................ LO Next File Name....... ....STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/10/11 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAvv Wv'W Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUt-1l'-1ARY VENDOR TOOL CODE START DEPTH ROP 8309.5 $ 2 header data for each bit run in 1 .5000 separate files. STOP DEPTH 8338.5 # LOG HEADER DATA DATE LOGGED: SOFTí^ïARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG HINIMUM ANGLE: JvLll,xn1U1v1 ANGLE: 08-AUG-04 Insite 66.37 Memory 8338.0 8308.0 8338.0 8308.0 43.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 8308.0 BOREHOLE CONDITIONS -- ì1UD TYI?E: MUD DENSITY (LB/G): MUD VISCOSITY (S): HUD I?H: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHì~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT V~ CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT t-1T: NEUTRON TOOL HATRIX: MJI._TRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REViARKS : $ Data Format Specification Record Data Record Type.................. 0 Data Specification Block Ty~e.....O Logging Direction.................Down Optical log depth units....... ....Feet Data Reference Point....... .... ...Undefined Frame Spacing.....................60 .1IN Max frames per record......... ....Undefined Absent value...................... -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEI?T ROP HWDOIO LSND 11.00 56.0 9.5 600 5.0 .000 .000 .000 .000 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT 1 H 4 1 68 4 2 '--' .0 .0 .0 .0 First Last Name Service Unit Min Hax Hean Nsam Reading Reading DEPT FT 8309.5 8338.5 8324 59 8309.5 8338.5 ROP ]'1VWO 1 0 FT/H 2.58 9.13 5.22559 59 8309.5 8338.5 First Reading For Entire File..........8309.5 Last Reading For Entire File...........8338.5 File Trailer Service name.......... ...STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation... ....04/10/11 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name.. .... .... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......04/10/11 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER "-' FILE NUMBER: RAv,] t1ltJD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX FET RPD RPS RP¡V¡ ROP 3 ~o~ header data for each bit run in separate files. 2 .5000 START DEPTH 8159.0 8280.0 8280.0 8280.0 8280.0 8280.0 8339.0 STOP DEPTH 9881.5 9877.0 9877.0 9877 . 0 9877.0 9877.0 9920.0 $ " 7t LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DO~MHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MIND1UH ANGLE: VlAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR E 1fJR 4 $ BOTTOM) TOOL TYPE DUAL G]'\MMA RAY ELECTROt1AG. RESIS. 4 # 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): HUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) HUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: HUD FILTRATE AT MT: HUD CAKE AT MT: # NEUTRON TOOL HATRIX: t1ATRIX DENSITY: HOLE CORRECTION (IN): .u 11 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type..... ..... ........0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units.... .......Feet Data Reference Point..............Undefined Frame Spacing........ ..... ........60 .1IN Max frames per record..... ........Undefined Absent value...................... -999 Depth Units....................... 11-AUG-04 Insite 66.37 Hemory 9920.0 8338.0 9920.0 37.9 44.0 TOOL NUMBER 120558 134758 8.500 8308.0 LSND 11.00 53.0 9.3 1000 4.8 1.500 .730 1.050 1.950 81. 0 172.4 81. 0 81. 0 .'- c.____ Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP ¡1T¡JD020 FT/H 4 1 68 4 2 GR WtJD020 API 4 1 68 8 3 RPX Hv1DO 20 o Hìv1M 4 1 68 12 4 RPS WIJD020 OHMH 4 1 68 16 5 RPH HWD020 OHHH 4 1 68 20 6 RPD HvJD020 OHMr'1 4 1 68 24 7 FET ~lD020 HOUR 4 1 68 28 8 First Last Name Service Unit Hin Hax Mean Nsam Reading Reading DEPT FT 8159 9920 9039.5 3523 8159 9920 ROP MWD020 FT/H 23.83 300.87 108.874 3163 8339 9920 GR Wv"JD020 API 48.9 169.78 105.858 3446 8159 9881. 5 RPX MTtJD020 OHHH 0.6 2000 3.28072 3195 8280 9877 RPS WtJD020 OHfv1M. 0.96 1557.24 2.57064 3195 8280 9877 RPH MTtJD020 OHHH 0.94 2000 3.35432 3195 8280 9877 RPD MvW020 OHMM 0.16 2000 25.4059 3195 8280 9877 FET MWD020 HOUR 0.3 56.6541 2.95087 3195 8280 9877 First Reading For Entire File..........8159 Last Reading For Entire File...........9920 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation..... ..04/10/11 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...... .04/10/11 Maximum Physical Record. .65535 File Type................ LO Previous File Name..... ..STSLIB.003 Comment Record FILE HEADER FI LE Nut"1BER: RAv.] t'1WD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUM!vfF..RY VENDOR TOOL CODE FET RPD RP]'!¡ RPS RPX GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 9877.5 9877.5 9877 . 5 9877.5 9877.5 9882.0 9920.5 STOP DEPTH 10359.5 10359.5 10359.5 10359.5 10359.5 10352.5 10400.0 # LOG HEADER DATA DJI..T E LOGG ED: SOFTít1ARE SURFACE SOFTWARE VERSION: 13-AUG-04 Insite '- .- DOWNHOLE SOFTvV\RE 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: Ì"íAXIMUM ANGLE: " IT TOOL STRING (TOP TO VENDOR TOOL CODE DGR E~"ÎR4 $ BOTTOM) TOOL TYPE DUAL GAi"v!MA RAY Electromag Resis. 4 # 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: HUD CAKE AT HT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): " 1t REMARKS: $ Data Format Specification Record Data Record Type...... ...... ......0 Data Specification Block Type.....O Logging Direction.................Dovm Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record. ............Undefined Þbsent value...................... -999 Depth Units....................... Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset DEPT FT 4 1 68 0 ROP !V¡wD030 FT/H 4 1 68 4 GR MWD030 API 4 1 68 8 RPX MWD030 OHMM 4 1 68 12 RPS !-fwD030 OHI'111 4 1 68 16 RPM HWD030 OHMH: 4 1 68 20 RPD !vfWD030 OHI'111 4 1 68 24 FET ¡V¡wD030 HOUR 4 1 68 28 '-" 66.37 Memory 10400.0 9920.0 10400.0 18.1 42.5 TOOL NUMBER 62456 130910 6.125 9920.0 Flo Pro SF 8.50 42.0 9.4 3200 7.4 .480 .200 .470 .480 69.0 178.1 69.0 69.0 Channel 1 2 3 5 6 7 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9877.5 10400 10138.8 1046 9877 . 5 10400 ROP !-fvJD030 FT/H 1. 23 413.23 103.318 960 9920.5 10400 GR WI'JD030 API 12.41 566.99 74.7022 942 9882 10352.5 RPX !...¡rI'JD030 OHMM 0.95 317.97 16.9917 965 9877.5 10359.5 RPS HWD030 OHMH 1.14 234.29 16.4251 965 9877.5 10359.5 ~ "-' R H1 MV-JOO 3 0 OHMM 0.43 2000 21.3527 965 9877.5 10359.5 RPD HTI'J0030 OHMM 2.22 2000 139.32 965 9877.5 10359.5 FET !vffI'lDO 3 0 HOUR 0.29 53.4 5.68364 965 9877.5 10359.5 First Reading For Entire File.... ......9877.5 Last Reading For Entire File...........10400 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation... ....04/10/11 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name........ ...STSLIB.005 Physical EOF Tape Trailer Service name.............LISTPE Date.................... .04/10/11 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name........ ........ .UNKNŒ\'ì'J Continuation Number......01 Next Tape Name...........UNKNO~~ Corrrments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Da t e . . . . . . . . . . . . . . . . . . . . . 04/10/11 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number... ...01 Next Reel Name...........UNKNOWN Comments...... ...........STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File