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Home My WebLink About203-0501. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Install Gas Lift 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13,981' N/A Casing Collapse Conductor NA Surface 2,260 psi Production 4,760 psi Intermediate 7,020 psi Liner 7,500 psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 8,430 psi11,419'13,980' 3,666' 11,517' 13,434' Perforation Depth MD (ft): 858' 4-1/2' 7"2,152' 13-3/8" 9-5/8" 3,666' 11,517' NA 8,160 psi 5,020 psi 6,870 psi 3,190' 9,376' 10,944' Length Size Proposed Pools: 206' 206' TVD Burst PRESENT WELL CONDITION SUMMARY 11,420' 13,973' 11,412' 1,886 13,040' 206' 20" MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312799 203-050 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23146-00-00 Hilcorp Alaska LLC NORTHSTAR UNIT NS-23 NORTHSTAR NORTHSTAR OIL, KUPARUK OIL Same Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 18.8# L80 and 32# T-95 13,127' October 15, 2025 7" x 4-1/2" S-3 Permanent and 7" HRQ SVLN 13,079' MD/ 10,636' TVD and 2,148' MD/ 1,993' TVD See Schematic See Schematic 4-1/2" and 7" 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Aras Worthington aras.worthington@hilcorp.com Operations Manager 907-440-7692 Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:49 pm, Sep 30, 2025 Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.09.30 11:08:24 -08'00' Justus Hinks (3691) 325-588 DSR-10/2/25A.Dewhurst 07OCT25JJL 10/10/25 10-404 10/10/25 Install Gas-Lift Well: NS-23 PTD: 203-050 Well Name:NS23 API Number:50-029-23146-00 Current Status:Operable Kuparuk Producer Rig:SL, EL Estimated Start Date:October 15, 2025 Estimated Duration:Three days Reg.Approval Reqd?Yes Regulatory Contact:Darci Horner 907-777-8406 (O) First Call Engineer:Aras Worthington 907-440-7692 (M) Second Call Engineer:Ryan Thompson 907-301-1240 (M) Current Bottom Hole Pressure (Kuparuk):2,816 psi @ 9,300 ssTVD (SBHPS 4/5/25) (5.9 ppge) Max. Anticipated Surface Pressure (Kuparuk):1,886 psi Gas Gradient (0.1 psi/ft) History NS23 was drilled and completed as an Ivishak injector in 2003. The well was re-completed as a Kuparuk Producer via an IA cement job in 2023 via Sundry #323-051. The well only flowed for a short period of time in 2023 after the re-complete. It was successfully BOL in mid-March of 2025 and since then has been a cycle well, periodically dying off due to not having any artificial lift mechanism. Last Well Test: 72 bopd, 558 bwpd, 4mmscfd Fgas, 750 psi WHP, 56% WC. Objective Punch tubing above the TOC in the IA and install a retrievable patch with an integral sliding sleeve for artificial lift (gas-lift). Integrity Status o MIT-T passed to 2,688 psi on 5/6/25 o CMIT-TxIA passed to 2,717 psi on 5/6/25 o TOC in the IA 7,827 per CBL of 4/25/23 Install Gas-Lift Well: NS-23 PTD: 203-050 Procedural steps Slickline/Eline/Fullbore 1. PT PCE to 2,500 psi high, 250 psi low. a. Per CFR 250.711, well control drills must be performed on a regular basis and documented. Perform at least 1 well control drill per week and document in both AWGRS daily summary and log entries. 2. Pull the SSSV. 3. Drift for 7 patch; Max OD/length of two part patch 5.688 (packer) x 4.5 (Sliding Sleeve), 25 OAL. See attached patch schematic 4. Punch tubing just below the tubing collar @ ~7,718 MD (see caliper snapshot attached). Two feet of tubing punch-gun, 7,718 7,720 MD. a. Hold a differential (~500 psi) on the tubing when punching and note pressure fall- off after firing gun or b. Plan to pump down the tubing with returns from the IA to verify TxIA comms after punching. 5. EL MU bottom section of patch. Set ME @ 7,730 MD. 6. SL MU top section of patch. Sting into seal assy and set upper ME @ 7,710 MD. 7. Set a plug in the 2.813 X-nipple @ 10,938 MD. 8. MITT or MITIA to 2,500 psi target pressure, 2,750 psi max pressure to validate that patch has integrity. 9. Pull the plug from 10,938 MD. 10. Open the Sliding Sleeve. 11. Set SSSV. Attachments Current Schematic Proposed Schematic Patch Schematic Caliper Snapshot Install Gas-Lift Well: NS-23 PTD: 203-050 Current Schematic Install Gas-Lift Well: NS-23 PTD: 203-050 Proposed Schematic Tbg Punch @ ~7720 MD straddled by 7 Patch w/ Integral Sliding Sleeve Install Gas-Lift Well: NS-23 PTD: 203-050 Patch Schematic 4.0 4.0 Install Gas-Lift Well: NS-23 PTD: 203-050 Caliper Snapshot MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC NS-23 NORTHSTAR UNIT NS-23 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 NS-23 50-029-23146-00-00 203-050-0 N SPT 10650 2030500 2500 980 2730 2705 2694 53 101 100 99 OTHER P Sully Sullivan 5/6/2025 NS23 was shut in on 3-31-25 two weeks before the biennial MIT testing was due. This well requires a MIT-T and CMIT-T by IA to 2500 psi per AOGCC accepted procedures before the well can be brought online. This test reflects the CMIT-T x IA see related inspection for CMIT-T 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:NORTHSTAR UNIT NS-23 Inspection Date: Tubing OA Packer Depth 981 2741 2709 2697IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS250507094902 BBL Pumped:6 BBL Returned:4.6 Friday, July 18, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 999 9 9 9 9 9 This test reflects the CMIT-T x IA James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 12:36:38 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC NS-23 NORTHSTAR UNIT NS-23 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 NS-23 50-029-23146-00-00 203-050-0 N SPT 10650 2030500 2500 840 2756 2702 2688 57 61 60 60 OTHER P Sully Sullivan 5/6/2025 NS23 was shut in on 3-31-25 two weeks before the biennial MIT testing was due. This well requires a MIT-T and CMIT-T by IA to 2500 psi per AOGCC accepted procedures before the well can be brought online. This test reflects the MIT-T see related inspection for CMIT-TXIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:NORTHSTAR UNIT NS-23 Inspection Date: Tubing OA Packer Depth 1159 1365 1368 1366IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS250507084249 BBL Pumped:5.5 BBL Returned:3.6 Friday, July 18, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 99 99 9 9 9 This test reflects the MIT-T James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 12:34:21 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Set Packer w/X-Nipple Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,980 feet 13,040 feet true vertical 11,419 feet NA feet 10,919', 11,282', Effective Depth measured 13,040 feet 13,079', 13,122'feet true vertical 10,603 feet 8,896, 9,187, 10,636, 10,672 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2" L-80 13127 10,677 Tubing (size, grade, measured and true vertical depth) 7" T-95 11,230' 9,145' 2,148' (MD) Packers and SSSV (type, measured and true vertical depth) 7" HRQ SVLN See Above 1,992' (TVD) 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Northstar, Kuparuk Oil 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Operations Engineer Contact Phone: 4-1/2" Perm, 9-5/8" ZXP, 7" S-3, 7" ZXP 325-213 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 4955 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Aras Worthington aras.worthington@hilcorp.com 907-564-4763 N/A measured true vertical Packer MD 3,666' Size 3,190' 9,376' Length 858' Casing TVD 4-1/2" Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 124 Gas-Mcf 132 568 7495077 123 768600 751 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-050 50-029-23146-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC CBL ran 4/25/23 emailed to melvin.rixse@alaska.gov on 4/25/23 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0312799 NORTHSTAR / NORTHSTAR OIL, KUPARUK OIL NORTHSTAR UNIT NS-23 Plugs Junk measured measured Surface 13-3/8"3,666' 11,419'13,980' 2,152' 11,517'Intermediate Production Liner 7" 11,517' 13,434' 10,944' 9-5/8" 7,500psi 6,870psi 8,160psi 8,430psi 7,020psi Burst 5,020psi Collapse 2,260psi 4,760psi Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 1:09 pm, Jun 03, 2025 Digitally signed by Ryan Thompson (3984) DN: cn=Ryan Thompson (3984) Date: 2025.06.03 10:03:34 - 08'00' Ryan Thompson (3984) JJL 6/3/25 RBDMS JSB 061225 DSR-6/3/25 Well Name Rig API Number Well Permit Number Start Date End Date NSI NS-23 Eline / Fullbore 50-029-23146-00-00 203-050 4/23/2025 5/7/2025 Fullbore: T/I/O= 1,000/551/51 (PRESSURE TEST (INTEGRITY)) Pre-AOGCC CMIT-TxIA to 2,717/2,707 psi ***PASSED*** Pumped 10.7 bbls of Crude down TxIA to reach 2,789/2,769 psi. 1st 15-minute loss of 33/25 psi, 2nd 15-minute loss of 21/21 psi, 3rd 15-minute loss of 18/16 psi, for a total loss of 72/62 psi in 45 minutes. Bled back ~7.7 bbls. Valve Positions - SV/WV/SSV= Closed, MV= Open, IA/OA= OTG FWHP= 970/1,010/62 5/4/2025 - Sunday 5/5/2025 - Monday LRS Travel from NorthStar to Prudhoe Bay 5/3/2025 - Saturday Slickline: ***WELL S/I ON ARRIVAL*** FUNCTION TEST WLV=PASS EQUALIZE & PULL 3-1/2" XX-PLUG @ 10,939' MD SET 3-1/2" XX-PLUG @ 10,939' MD (8x1/8" ports 23" lih) ***WELL LEFT S/I ON DEPARTURE. NOTIFY PAD OP OF WELL STATUS*** Fullbore: T/I/O= 288/508/55 (PRESSURE TEST (INTEGRITY)) Pre-AOGCC MIT-T to 2.590 psi ***PASSED*** Pumped 61.5 bbls of Crude down TBG to reach 2,743 psi. 1st 15-minute loss of 122 psi, 2nd 15-minute loss of 31 psi, for a total loss of 153 psi in 30 minutes. Bled back ~7.1 bbls. Valve Positions - SV/WV/CV/SSV= Closed, MV= Open, IA/OA= OTG FWHPs= 1,000/571/47 4/23/2025 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary ***WELL SHUT IN ON ARRIVALL*** RIG UP AK E-LINE STANBY FOR LRS TO LOAD WELL PT 250L 3500H SET TRI POINT PACKER @ 10920' ME. TOP OF PACKER @ 10919' MD. (OAL= 20.22', 3 1/2" X-nipple @ 10,938' MD) , CCL STOP DEPTH=10905.7, CCL-ME=14.3' JOB COMPLETE ***WELLSHUT IN ON DEPARTURE*** 4/24/2025 - Thursday Fullbore: T/I/O = 660/626/36 (PRESSURE TEST(INTEGRITY)) MIT-T/COMBO. Pump 76 bbls to try and pressure up for a MIT-T. Established a LLR of 1 bpm @ ~2290 psi. Off pump pressure began to drop rapidly. Area authorities notified upon completion. Well SI Upon departure. FWHPs = 1600/780/37 Well Name Rig API Number Well Permit Number Start Date End Date NSI NS-23 Eline / Fullbore 50-029-23146-00-00 203-050 4/23/2025 5/7/2025 Hilcorp Alaska, LLC Weekly Operations Summary Slickline: ***CONT WSR FROM 5/06/25*** FUNCTION TEST WLV=PASS EQUALIZE & PULL 3-1/2" XX-PLUG FROM 10,939' MD SET 7" FXE (ser# HNS-4 93" OAL) @ 2,148' MD OPS INJECTED GAS TO WELL AND PERFORMED PASSING CLOSURE TEST (T. SPARKS) ***WELL LEFT S/I ON DEPARTURE. NOTIFY PAD-OP OF STATUS*** Fullbore: T/I/O = 840/1159/57. (PRESSURE TEST INTEGRITY) AOGCC rep. Sully Sullivan witnessed an MITxT to 2756 psi (PASSED) and a CMIT TxIA to 2730/2705 (PASSED). Pumped 5.5 bbls dsl down the tbg to achieve a test pressure of 2756 psi. Tbg lost 54 psi in the first 15 min and 14 psi in the second 15 min. Bled back 3.6 bbls dsl. Pumped 6 bbls dsl to pressure the tbg up to 2730 and the IA to 2741. In the first 15 min the T/IA lost 35/33, in the second 15 min the T/IA lost 11/11. Bled back 4.6 bbl dsl. 5/7/2025 - Wednesday 5/6/2025 - Tuesday _____________________________________________________________________________________ Revised By: DH 5/29/2025 SCHEMATIC Northstar Unit Well: NS-23 Last Completed: 4/27/2023 PTD: 203-050 TD =13,981’ (MD) / TD =11,420’ (TVD) 20” KBE =56.55’/CB =15.8’ 7” Tubing Punch @ 13,015’-13,020’ 3/10/23 2 5 6 9 12, 13 7 Top of cement in IA ~ 7,827’ per HAL CBL 4/25/23 9-5/8” 1 3 10 8Min ID= 3.260” @ 13,113’ Composite Bridge Plug @ 13,040’ 3/10/23 PBTD =13,973’ (MD) / PBTD =11,413’(TVD) 4 13-3/8” 11 4-1/2” 6 TOC in tubing tagged @ 12,347’ SLM 3/29/23 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 169# / X-56 / N/A N/A Surface 206' N/A 13-3/8" Surface 68# / L-80 / BTC 12.415” Surface 3,666’ 0.1497 9-5/8" Intermediate 53.5# / L-80 / BTC-M 8.535” Surface 11,517’ 0.0708 7" Liner 29# / L-80 / Hydril 521 6.184” 11,282’ 13,434’ 0.0371 4-1/2” Liner 12.6#/L-80 / Vam Ace 3.958” 13,122’ 13,980’ 0.0152 TUBING DETAIL 7” Tubing 32# / T-95 HS/ Vam Top 6.094” Surface 11,230’ 0.0361 4-1/2” Tubing 18.8#/L-80/Vam Top 3.640” 11,230 13,127’ NA JEWELRY DETAIL No Depth Item 1 2,148’ 7” 32# HRQ SVLN, ID= 5.963” 2 10,919’ Tripoint 4-1/2” x 7” Permanent Packer, OAL=21’ w/ 2.813” X-nipple 4/23/25 3 11,230’ 7” x 4-1/2” Cross-over, ID= 3.640” 4 11,282’ 9-5/8” x 7” Baker ZXP HR Liner Top Packer, ID = 6.200” 5 11,304’ 9-5/8” x 7” Baker Flex Lock Liner Hanger, ID = 6.200“ 6 13,063’ 4-1/2” HES “R” Nipple, ID = 3.437” 7 13,079’ 7” x 4-1/2” Baker S-3 Permanent Packer, ID = 3.56” 8 13,102’ 4-1/2” HES ‘R’ Nipple, ID= 3.437” 9 13,113’ 4-1/2” HES ‘RN’ Nipple, ID= 3.26”, (13,097’ ELMD) 10 13,122’ 7” x 5” Baker ZXP Liner Top Packer, ID = 4.370” 11 13,124’ 4-1/2” Wireline Exit Guide, ID = 3.850” bottom @ 13,127’ 12 13,145’ 7” x 5” Baker Flex Lock Liner Hanger, ID= 4.350” 13 13,154’ 5” x 4-1/2” Cross-over, ID= 3.940” PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Size Kuparuk 11,062’ 11,131’ 9,010’ 9,066’ 70’ 4/26/2023 Open 2-7/8” Ivishak 13,629’ 13,869’ 11,112’ 11,321’ 240’ 6/5/2003 Closed 4-5/8” Reference log: LWD on 5/7/2003. CASING / OPEN HOLE / CEMENT DETAIL 20" Driven 13-3/8" 606 sx Permafrost ‘L’, 492 sx Class ‘G’ in 16” hole 9-5/8" 630 sx Econolite, 700 sx Class ‘G’ in 12-1/4” hole 7” 315 sx Class “G” in 8-1/2” hole 4-1/2” 120 sx Class “G” in 6-1/8” hole WELL INCLINATION DETAIL KOP @ 284’ Max Hole Angle = 42 deg. @ 10,324’ Max Angle at Top Perf: 31 Deg. @ 13,629’ TREE & WELLHEAD Tree ABB-VGI 7” 6.5KSI Wellhead ABB-VGI 13-5/8” Multibowl 6.5KSI GENERAL WELL INFO API: 50-029-23146-00-00 Initially Drilled - Nabors 33E –5/10/2003 Initial Completion –Nabors 33E –6/9/2003 Kuparuk Recomplete –4/27/2023 SAFETY NOTE Well requires a SSSV. 5 joints of 18.8# 13Cr-95 Vam Top HC across the 7” liner just below the 7” tubing. Tubing restriction @ 7’ MD. Use R-Lock for SSSV. Do not run No-Go ring on lock. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/15/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250515 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 241-23 50283201910000 223061 4/24/2025 AK E-LINE Plug/Perf T40412 END 2-72 50029237810000 224016 4/4/2025 READ CoilFlag T40413 IRU 241-01 50283201840000 221076 4/30/2025 AK E-LINE Perf T40414 IRU 241-01 50283201840000 221076 4/23/2025 AK E-LINE Plug/Perf T40414 KU 33-08 50133207180000 224008 4/22/2025 AK E-LINE PPROF T40415 MRU D-16RD 50733201830100 180110 4/21/2025 AK E-LINE Cement/Perf T40416 NSU NS-06 50029230880000 202101 4/21/2025 AK E-LINE PPROF T40417 NSU NS-19 50029231220000 202207 4/27/2025 AK E-LINE Perf T40418 NSU NS-20 50029231180000 202188 4/24/2025 AK E-LINE Perf T40419 NSU NS-23 50029231460000 203050 4/23/2024 AK E-LINE Packer T40420 PBU 02-10B 50029201630200 200064 3/21/2025 BAKER SPN T40421 PBU 06-19B 50029207910200 224095 3/1/2025 BAKER MRPM Borax T40422 PBU S-100A 50029229620100 224083 2/28/2025 BAKER MRPM Borax T40423 PBU Z-235 (Revised)50029237600000 223055 4/1/2025 READ InectionProfile T40424 SRU 231-33 50133101630100 223008 5/1/2025 AK E-LINE Plug/Perf T40425 Revision Explanation: Processing report added Please include current contact information if different from above. T40420NSU NS-23 50029231460000 203050 4/23/2024 AK E-LINE Packer Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.16 08:15:21 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Ryan Thompson To:Regg, James B (OGC); Wallace, Chris D (OGC) Cc:Justus Hinks Subject:Operable - NS-23 (PTD# 2030500) - AOGCC Witnessed CMIT-TxIA & MIT-T Passed Date:Tuesday, May 6, 2025 3:53:18 PM Mr. Regg – Producer NS-23 (PTD# 2030500) passed an AOGCC witnessed MIT-T and CMIT-TxIA on 5/6/25. The well is now re-classified as Operable and will be brought online. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Monday, March 31, 2025 11:53 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Justus Hinks <jhinks@hilcorp.com> Subject: Not Operable - NS-23 (PTD# 2030500) - Witnessed CMIT-TxIA & MIT-T due March 2025 Mr. Regg – Producer NS-23 had an IA cement job completed in March 2023 with a requirement per Sundry #323-051 for 2 year CMIT-TxIA and MIT-T due in March 2025. The well will now be re-classified as Not Operable and shut in today 3/31/25 until the sundry required MIT’s are completed. Please respond with any questions. Thank you, NS-23 (PTD# 2030500) passed Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Set Packer w/ X-Nipple 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 13,981'N/A Casing Collapse Conductor NA Surface 2,260 psi Production 4,760 psi Intermediate 7,020 psi Liner 7,500 psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Aras Worthington Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312799 203-050 NORTHSTAR UNIT NS-23 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23146-00-00 NORTHSTAR Hilcorp Alaska, LLC Length Size Proposed Pools: 11,420' 13,938' 11,382' 1,886 NORTHSTAR OIL, KUPARUK OIL Same 206' 206' 18.8# L80 and 32# T-95 TVD Burst 13,127' 8,430 psi MD NA 8,160 psi 11,517' 5,020 psi 6,870 psi 3,190' 9,376' 10,944' 3,666' 11,517' See Schematic 11,419'4-1/2' 206' 20" 13-3/8" 9-5/8" 3,666' 7"2,152' See Schematic 907-564-4763 aras.worthington@hilcorp.com Operations Manager April 13, 2025 4-1/2" and 7" Perforation Depth MD (ft): C.O. 739 7" x 4-1/2" S-3 Permanent and 7" HRQ SVLN 13,079' MD/ 10,636' TVD and 2,148' MD/ 1,993' TVD 13,040' 13,980' 13,434' 858' Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-213 By Gavin Gluyas at 8:04 am, Apr 10, 2025 Digitally signed by Aras Worthington (4643) DN: cn=Aras Worthington (4643) Date: 2025.04.09 13:26:25 - 08'00' Aras Worthington (4643) SFD 4/10/2025 DSR-4/11/25JJL 4/10/25 10-404 Jack Lau 4/10/25 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.14 16:49:18 -08'00'04/14/25 RBDMS JSB 041725 Re-complete to Kuparuk Well: NS-23 PTD: 203-050 Well Name:NS23 API Number:50-029-23146-00 Current Status:Not Operable Kuparuk Producer Rig:SL/EL Estimated Start Date:April 13, 2025 Estimated Duration:Four days Reg.Approval Req’d?Yes - 403 Regulatory Contact:Darci Horner 907-777-8406 (O) First Call Engineer:Aras Worthington 907-440-7692 (M) Second Call Engineer:Ryan Thompson 907-301-1240 (M) Current Bottom Hole Pressure (Kuparuk):2,816 psi @ 9,300’ ssTVD (SBHPS 4/5/25) (5.9 ppge) Max. Anticipated Surface Pressure (Kuparuk):1,886 psi Gas Gradient (0.1 psi/ft) History NS23 was drilled and completed as an Ivishak injector in 2003. The well was re-completed as a Kuparuk Producer via and IA cement job in 2023 via Sundry #323-051. The well only flowed for a short period of time in 2023 after the re-complete. Several attempts to flow the well after being shut in for SVS testing failed. The well was successfully BOL in mid- March of 2025 and flowed for about two weeks before the biennial MITs expired. On March 31st 2025 the well was shut-in and made Not Operable pending completion of biennial MITs. Objective Set a permanent packer with an X-nipple profile to aid in execution of biennial MITs. Re-complete to Kuparuk Well: NS-23 PTD: 203-050 Procedural steps Slickline (Sundry not required) ***Prior to job, coordinate with operations whether they have weathered crude available for loading the well and have the well SI to meet the 48 hour static window*** 1. MIRU. Pressure test PCE 250psi low, 3,500psi high. a. Per BSEE 250.1506, well control drills must be performed on a regular basis and documented. Perform at least 1 well control drill per visit and document in both AWGRS daily summary and log entries. 2. Pull WRSSSV from 2,148' MD. 3. RIH and drift for 7" RBP. 4. Perform SBHPS after minimum 48 hour SI time. 15 min stops below: a. 11,493 MD / 9,300 SSTVD b. 11,244 MD / 9,100 SSTVD c. 10,869 MD / 8,800 SSTVD d. 10,481 MD / 8,500 SSTVD Above steps are complete. Eline (Sundry Approval Required) 5. MIRU. Pressure test PCE 250psi low, 3,500psi high. a. Per BSEE 250.1506, well control drills must be performed on a regular basis and documented. Perform at least 1 well control drill per visit and document in both AWGRS daily summary and log entries. 6. MU Tripoint Packer Assy on Baker 20 setting tool. 7. Tie-in and set packer with ME at ~10,920' MD (middle of a joint of 7") Slickline/Fullbore 8. MIRU. Pressure test PCE 250psi low, 3,500psi high. a. Per BSEE 250.1506, well control drills must be performed on a regular basis and documented. Perform at least 1 well control drill per visit and document in both AWGRS daily summary and log entries. 9. Load Tubing with 590 bbls (1.5 x top perf volume) with weathered Crude or diesel. Max tubing pressure 2,750 psi. 10. RIH w/ 2.813" X-plug (WSS discretion), set @ ~10,940' MD. 11. Perform state witnessed CMIT-TxIA and MIT-T to 2500 psi target pressure, 2750 psi max pressure. Send in 10-426 form to Ryan Thompson for AOGCC submittal. 12. Pull X-Plug. 13.Set WRSSSV @ 2,148'. Perform closure test. Re-complete to Kuparuk Well: NS-23 PTD: 203-050 Attachments Current Schematic Proposed Schematic Packer Spec Sheet Packer assy Load out sheet Re-complete to Kuparuk Well: NS-23 PTD: 203-050 Current Schematic Re-complete to Kuparuk Well: NS-23 PTD: 203-050 Proposed Schematic Re-complete to Kuparuk Well: NS-23 PTD: 203-050 Re-complete to Kuparuk Well: NS-23 PTD: 203-050 From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Northstar 23 packer installation PTD #203-050 Date:Thursday, April 10, 2025 11:07:15 AM -----Original Message----- From: Lau, Jack J (OGC) Sent: Thursday, April 10, 2025 9:29 AM To: Aras Worthington <Aras.Worthington@hilcorp.com> Cc: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com>; Darci Horner <dhorner@hilcorp.com>; Justus Hinks <jhinks@hilcorp.com> Subject: RE: Northstar 23 packer installation PTD #203-050 Aras, You have verbal approval to move forward installing a permanent packer with an x-nipple to facilitate integrity testing. Thanks, Jack -----Original Message----- From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Thursday, April 10, 2025 9:27 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com>; Darci Horner <dhorner@hilcorp.com>; Justus Hinks <jhinks@hilcorp.com> Subject: Northstar 23 packer installation PTD #203-050 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. Jack, As discussed via phone we agreed that this work, although not specifically referenced in the sundry matrix as needing a 403, would be submitted as such. We submitted a sundry application for this work yesterday and we are planning to execute the work as early as Saturday, April 12. Ice trail timing constraints on the island are a factor in this compressed schedule. As such we request a verbal approval for this work. Thanks and Best Regards, Aras Worthington (907) 440-7692 ________________________________ The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. ________________________________ Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/20/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230420 Well API #PTD #Log Date Log Company Log Type BCU 04RD 50133202390100 219011 5/16/2023 AK E-LINE Perf BCU 04RD 50133202390100 219011 5/17/2023 AK E-LINE Strip Guns NS-23 50029231460000 203050 4/25/2023 HALLIBURTON MFC PBU GNI-02A 50029228510100 206119 5/30/2023 READ Pressure Temperature Survey PBU GNI-03 50029228200000 197189 5/31/2023 READ Pressure Temperature Survey PBU J-29 50029234860000 213033 4/18/2023 BAKER SPN PBU A-06A 50029201180100 223015 4/6/2023 BAKER MRPM Please include current contact information if different from above. T37770 T37770 T37771 T37772 T37773 T37774 T37775 NS-23 50029231460000 203050 4/25/2023 HALLIBURTON MFC Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.21 13:29:44 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/13/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230417 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU B-21 50029215350000 186023 5/8/2023 HALLIBURTON Jewelry Log MPU B-21 50029215350000 186023 5/12/2023 HALLIBURTON Leak Detection Log MPU B-21 50029215350000 186023 5/13/2023 HALLIBURTON Multi Finger Caliper Report MPU I-04A 50029220680100 201092 4/17/2023 HALLIBURTON Cement Bond Log NS-16A 50029230960100 206141 4/3/2023 HALLIBURTON RBT NS-23 50029231460000 203050 4/25/2023 HALLIBURTON RBT PBU 09-24A 50029214280100 223003 4/9/2023 HALLIBURTON RBT-Coilflag PBU C-26A 50029208340100 198145 3/17/2023 HALLIBURTON Production Profile PBU M-201 50029237110000 222030 5/29/2023 HALLIBURTON Inj. Profile PBU S-32A 50029220990100 212082 5/23/2023 HALLIBURTON CAST CBL PBU S-37A 50029222910100 212092 5/19/2023 HALLIBURTON RBT PBU V-221 50029232460000 205013 5/14/2023 HALLIBURTON Inj. Profile PBU W-04 50029219070000 189008 3/8/2023 HALLIBURTON CAST CBL PBU W-209 50029231700000 203128 5/13/2023 HALLIBURTON Inj. Profile PBU W-219 50029234290000 210105 4/16/2023 HALLIBURTON Inj. Profile PBU Z-223 50029237200000 222080 2/28/2023 HALLIBURTON Inj. Profile SRU 213B-15 50133206540000 215130 4/28/2023 HALLIBURTON Perf Please include current contact information if different from above. T37729 T37729 T37729 T37730 T37731 T37732 T37733 T37734 T37735 T37736 T37737 T37738 T37739 T37740 T37741 T37742T37743 NS-23 50029231460000 203050 4/25/2023 HALLIBURTON RBT Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.13 13:09:15 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20230425 1330 APPROVAL post CBL Northstar NS-23 IA Cement CBL PTD 203-050 Sundry 323-051 Date:Tuesday, April 25, 2023 1:38:10 PM From: Rixse, Melvin G (OGC) Sent: Tuesday, April 25, 2023 1:30 PM To: 'Brenden Swensen' <Brenden.Swensen@hilcorp.com> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: RE: Northstar NS-23 IA Cement CBL PTD 203-050 Sundry 323-051 Brenden, Approved to continue work and perforating on Sundry 323-051. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Torin From: Brenden Swensen <Brenden.Swensen@hilcorp.com> Sent: Tuesday, April 25, 2023 11:08 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Northstar NS-23 IA Cement CBL PTD 203-050 Sundry 323-051 Hello Mel, Please see attached cement bond log for NS-23. Top of cement pick is at 7,830’ MD. TOC proposed in the sundry is 8,000’ MD. Let us know if we are approved to proceed with perforating the Kuparuk. Thanks, Brenden Swensen 907-748-8581 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:11 Township:13N Range:13E Meridian:Umiat Drilling Rig:NA Rig Elevation:NA Total Depth:13980 ft MD Lease No.:ADL0312799 Operator Rep:Suspend:P&A: Conductor:O.D. Shoe@ Feet Csg Cut@ Feet Surface:13-3/8"O.D. Shoe@ 3666 Feet Csg Cut@ Feet Intermediate:9-5/8"O.D. Shoe@ 11517 Feet Csg Cut@ Feet Production:O.D. Shoe@ Feet Csg Cut@ Feet Liner1:7"O.D. Shoe@ 13434 Feet Csg Cut@ Feet Liner2:4-1/2"O.D. Shoe@ 13980 Feet Csg Cut@ Feet Tubing:4-1/2"O.D. Tail@ 13127 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Bridge plug 13040 ft 12374 ft Wireline tag Initial 15 min 30 min 45 min Result Tubing IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Verification of cement across the Kuparuk formation prior to perforating the Kuparuk formation. MIT's were completed on 03-26- 2023 by Austin McLeod - both passing. Top of cement (TOC) tag was a good tag at 12374 ft MD with good cement sample from bailer. TOC was 673 ft high resulting in lower IA TOC; calculated IA TOC at 8367 ft MD should still be 2695 ft above top of new Perfs. A CBL log will be run in a few days to verify Cement in IA. March 29, 2023 Kam StJohn Well Bore Plug & Abandonment Northstar NS-23 Hilcorp Alaska LLC PTD #2030500; Sundry #323-051 none Test Data: Casing Removal: Nathan Williams Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 11-28-18 2023-0329_Plug_Verification_Northstar_NS-23_ksj           MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, April 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC NS-23 NORTHSTAR UNIT NS-23 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/26/2023 NS-23 50-029-23146-00-00 203-050-0 N SPT 10650 2030500 2500 1855 2770 2746 2742 18 20 20 19 OTHER P Austin McLeod 3/26/2023 CMIT- TxIA to 2500psi. Sundry 323-051. Re-complete to producer. Retainer @ 13,000 ft MD. TOC in IA @ ~ 8000 ft MD (CBL not done yet to verify). 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:NORTHSTAR UNIT NS-23 Inspection Date: Tubing OA Packer Depth 1816 2742 2716 2706IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230326181949 BBL Pumped:3.1 BBL Returned:3.3 Wednesday, April 26, 2023 Page 1 of 1 9 9 9 9 99 9999 9 9 9 9 CMIT- TxIA Sundry 323-051.Re-complete to producer. James B. Regg Digitally signed by James B. Regg Date: 2023.04.26 13:36:32 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, April 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC NS-23 NORTHSTAR UNIT NS-23 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/26/2023 NS-23 50-029-23146-00-00 203-050-0 N SPT 10650 2030500 2500 1995 2712 2703 2701 17 17 17 17 OTHER P Austin McLeod 3/26/2023 MITT to 2500psi. Sundry 323-051. Re-complete to producer. Retainer @ 13,000 ft MD. No tag done. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:NORTHSTAR UNIT NS-23 Inspection Date: Tubing OA Packer Depth 1508 1580 1578 1576IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230326181327 BBL Pumped:1.6 BBL Returned:1.4 Wednesday, April 26, 2023 Page 1 of 1 9 9 9 99 9 9 9 9 9 9 Sundry 323-051.Re-complete to producer. James B. Regg Digitally signed by James B. Regg Date: 2023.04.26 13:33:31 -08'00' 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. You don't often get email from brenden.swensen@hilcorp.com. Learn why this is important From:Rixse, Melvin G (OGC) To:Brenden Swensen Cc:DOA AOGCC Prudhoe Bay; Torin.Roschinger@hilcorp.com; Aras Worthington Subject:20230308 1517 APPROVAL Procedure Change NS-23 Cementing Change Request, PTN 203-050, Sundry 323-051 Date:Wednesday, March 8, 2023 3:19:53 PM Attachments:NS23 Sundry Without Retainer Resubmit.pdf Sundry_323-051_021023.pdf Brenden, Hilcorp is approved to forego the ball drop cement retainer as described in Sundry 323-051. The new procedure will still pump cement into annulus followed by holding pressure on the tubing as described in the ‘Retainer Resubmit’ (attached). As described in the original sundry, AOGCC will want to witness TOC tag above the CBP set at ~13,040’MD, the pressure test, and email the CBL. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). Cc AOGCC Inspectors From: Brenden Swensen <Brenden.Swensen@hilcorp.com> Sent: Wednesday, March 8, 2023 1:48 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com> Subject: NS-23 Cementing Change Request, PTN 203-050, Sundry 323-051 Hello Mel, Our timeline for the NS-16A (sundry 323-052) and NS-23 (sundry 323-052) is being compressed by equipment availability. The Halliburton pumping skid that we are using needs to be back in Cook Inlet to support the Monopod drilling program. Due to this constraint, we evaluated the risk with displacing cement volumetrically instead of setting the cement retainers. This will save us an estimated 2 days of slickline work and allow us to release the pump skid on time for it to be transported south. Please see the attached modifications to the previously approved sundry. FYI, we had originally looked at leaving the retainers out and only using the foam ball and straight displacement volumes. Running the retainers has little downside from a job risk perspective and add some “nice to have” upside by adding mechanical leverage to hold cement in place. This provides flexibility on holding pressures at surface. With this in mind, the original procedures included the retainers. However, the added “nice to have” benefit of running the retainers is being outweighed by the time constraints to support Monopod drilling. We can achieve the same success by holding pressure on the tubing and using hydrostatic pressure to hold the cement in place. Sample calculations have been added to the procedure for reference. Thanks, ~Brenden Swensen 907-748-8581 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Re-complete to Kuparuk Well: NS-23 PTD: 203-050 Well Name: NS23 API Number: 50-029-23146-00 Current Status: Operable Ivishak Gas Injector Rig: N/A Estimated Start Date: March 15, 2023 Estimated Duration: 2 weeks Yes Regulatory Contact: Darci Horner 907-777-8406 (O) First Call Engineer: Aras Worthington 907-440-7692 (M) Second Call Engineer: Torin Roschinger 406-570-9630 (M) Current Bottom Hole Pressure (Ivishak): 5200 psi @ 11,000 ssTVD (est.) Maximum Expected BHP (Ivishak): 5300 psi @ 11,000 ssTVD Max. Anticipated Surface Pressure (Ivishak): 4200 psi Gas Column Gradient (0.1 psi/ft) Current Bottom Hole Pressure (Kuparuk): 2400 psi @ 9000 ssTVD (est.) Maximum Expected BHP (Kuparuk): 2450 psi @ 9000 ssTVD Max. Anticipated Surface Pressure (Kuparuk): 1550 psi Gas Column Gradient (0.1 psi/ft) History NS23 was drilled and completed as an Ivishak injector in 2003. The value of the well as an ivishak injector has depleted to the point where a re-complete as a Kuparuk producer is proposed. Objective Execute an IA cement job to get cement across the Kuparuk interval. Perforate and produce the Kuparuk. The proposed TOC the IA is ~8000 MD which is ~3420 TVD below the surface casing shoe. A full reservoir abandonment of the Ivishak is not proposed at this time because there may be a future desire to either go back to the Ivishak perforations or perform a CTD sidetrack to another Ivishak target. Post-job Evaluation o MIT-T and CMIT-TxIA o CBL to confirm the Top of Cement (TOC) Long-Term Integrity Monitoring o Biennial MIT-T and CMIT-TxIA o Monitor and Record WHPs daily Re-complete to Kuparuk Well: NS-23 PTD: 203-050 Procedural steps Slickline & Fullbore 1. Pull the SSSV. 2. Drift for CBP/Cement retainer to ~13,063 MD (R-nipple of 3.437 ID). CBP and Retainer are both 3.44 max OD. 3. Tag the 3.437 XN nipple @ 13,063 w/ appropriate sized drift (3.60 3.44 wire and correct depth to tubing tally. 4. Set 4-1/2 (special order 3.44 OD for the 3.64 ID tubing) in the middle of the first full joint of tubing above the production packer (~13,040 MD*). 5. PT of tubing/CBP to 1500 psi to verify CBP set. Five-minute test, no more than 10% pressure loss. 6. Punch tubing in the middle of the first collar above the CBP. (~13,015 13,020 MD*). 7. Pump dead crude diesel down the tubing while taking returns up the IA, to confirm circulating rates and pressures through tubing punch. Circulate tubing and IA to diesel. (~722 bbls diesel surface-to-surface). 8. Set 4-1/2 Northern Solutions ball-drop-composite cement retainer (special order 3.44 OD for the 3.64 ID tubing) in the middle of the first full joint above the tubing punch (~13,000 MD*) *Note: All depths reference tubing tally of 6/8/2003. Fullbore 9. Pump down production tubing with returns from the IA: 10 bbls FW + Surfactant 108 bbls 14-15.8 ppg Class G cement Chase w/phenolic landing ball & two foam wiper balls Chase balls w/ ~428 bbls dead crude diesel and look for indication of ball landing on-seat Pump no more than 433 bbls total displacement after cement Hold at least 1700psi more on tubing vs IA pressure to keep cement hydrostatically in place. o 13015MD = 10582TVD, 8000MD = 6589TVD, 10582-6589 = 3993 delta o 141.5 / (131.5 + 40) = 0.825 sg * 8.33ppg = 6.87ppg dead crude o (14ppg 6.87ppg) / 8.33ppg * 0.433psi/ft * 3993 cement = 1479psi o Assumes tubing and IA loaded with dead crude provided by Northstar (API 40) If ball seats, apply no more than 2400 psi tbg pressure to verify seating (~500 psi over lift-pressure) Bleed-off tubing pressure. Bleed no more than 2-bbls to see if retainer poppet holds pressure from IA to tubing (lift pressure). If it does not hold pressure, bump tubing pressure back up to lift pressure and lock in pressure w/ tree valves Note: expected lift pressure is ~1900 psi Cement Calculations 7 4- volume from 13,015 11,282 30 bbls 9-5/8 x 4-1/2 volume from 11,282 11,230 MD: 2.7 bbls 9-5/8 x 7 volume from 11,230 8000 MD: 75 bbls Total Cement to pump: 108 bbls Re-complete to Kuparuk Well: NS-23 PTD: 203-050 Slickline & Fullbore 10. D&T TOC. 11. Log Memory CBL from tag of TOC in tubing to ~6000 MD to identify TOC. 12. Conduct AOGCC witnessed MIT-T and CMIT-TxIA to 2500 psi. Ensure 24-hour notice provided for AOGCC. 13. Leave CBP, cement, and cement retainer in tubing to isolate Ivishak from Kuparuk perforations. E-Line 14. Perforate the Kuparuk per attached proposed schematic. Slickline 15. Set SSSV. Well Diagnostics & WIE 16. Update AKIMS and add biennial MIT-T and CMIT TxIA. Re-complete to Kuparuk Well: NS-23 PTD: 203-050 NS23 Current Schematic 7 Casing Annular TOC logged w/ USIT @ ~13,300 MD 9-5/8 Casing Annular TOC @ ~5170 MD (w/ 30% washout) Confining Shales between Kuparuk and Ivishak: 11,342 - 13,387 MD Re-complete to Kuparuk Well: NS-23 PTD: 203-050 Re-complete to Kuparuk Well: NS-23 PTD: 203-050 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Kuparuk Recomplete Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13,980 feet 13,040 feet true vertical 11,419 feet NA feet 11,282', Effective Depth measured 13,040 feet 13,079', 13,122'feet true vertical 10,603 feet 9,187, 10,636, 10,672 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2" L-80 13127 10,677 Tubing (size, grade, measured and true vertical depth) 7" T-95 11,230' 9,145' 2,148' (MD) Packers and SSSV (type, measured and true vertical depth) 7" HRQ SVLN See Above 1,992' (TVD) 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Northstar, Kuparuk Oil 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Operations Engineer Contact Phone: Burst 5,020psi Collapse 2,260psi 4,760psi 7,500psi 6,870psi 8,160psi 8,430psi 7,020psi Surface 11,419'13,980' 2,152' 11,517'Intermediate Production Liner 13-3/8" 7" 3,666' 11,517' 13,434' 10,944' NORTHSTAR UNIT NS-23 Plugs Junk measured measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-050 50-029-23146-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC CBL ran 4/25/23 emailed to melvin.rixse@alaska.gov on 4/25/23 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0312799 NORTHSTAR / NORTHSTAR OIL, KUPARUK OIL Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 193 Gas-Mcf 199 613 8624700 0 45660 NA N/A measured true vertical Packer MD 3,666' Size 3,190' 9,376' Length 858' Casing Representative Daily Average Production or Injection Data 9-5/8" 9-5/8" ZXP, 7" S-3, 7" ZXP 323-051 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 50914 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Brenden Swensen brenden.swensen@hilcorp.com 907-748-8581 Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:04 pm, May 19, 2023 Digitally signed by Brenden Swensen (005774) Date: 5/19/23 12:50:49 PM Brenden Swensen (005774) KUPARUK OIL WCB 12-5-2024 DSR-5/22/23 RBDMS JSB 072523 Well Name Rig API Number Well Permit Number Start Date End Date NS-23 Slickline / Fullbore / Wellhead 50-029-23146-00-00 203-050 3/8/2023 4/27/2023 3/26/2023 Well Support: AOGCC witnessed MIT-T and CMIT-TxIA. Witnessed by Austin McLeod. MIT-T passed to 1576 psi. CMIT passed to 2742 psi on tubing and 2706 on IA. 3/29/2023 Well Support: WELL S/I ON ARRIVAL. (d&t toc, state witness). RAN 2.83" CENT W/ 1-3/4" SAMPLE BAILER TAG TOC @ 12,347' SLM (recover pieces of foam wiper ball & approx. 1.5 cup cement). WELL LEFT S/I ON DEPARTURE. Slickline: RAN 2.83" CENT W/ 1-3/4" SAMPLE BAILER TAG TOC @ 12,347' SLM (recover pieces of foam wiper ball & approx. 1.5 cup cement) 3/8/2023 Hilcorp Alaska, LLC Weekly Operations Summary Slickline: WELL S/I ON ARRIVAL, DSO NOTIFIED. PULLED 7" FXE (serial: HNS-4) FROM 2,117' SLM (2,148" MD), ALL PACKING & PINS RECOVERED. 3/9/2023 Slickline - CONTINUE FROM 3-8-23 WSR. STBY FOR LRS TO FILL OPEN TOP TANKS PRIOR TO LOADING WELL. Fullbore - Transfer 195 bbls crude from WCT to OTTs Fullbore: IA cement job for Kuparuk re-complete. Pump 109.5bbls 14ppg class G with HES offhore skid. Displace cement with LRS pump, 5bbl FW +422bbl NS crude to TBG punches at 13020'. Trap 2800psi on tbg. TOC in IA ~7827'. Resume pumping crude from tanks down NS19 flowline. Pump remaining fresh water & Cement wash-up fluids down NS 32 disposal well. Fullbore: Assist with filling UR with fresh water / Flush hardline to NS23 IA & Tbg, return lines to 19 flowline, OTT & washup tank 3/14/2023 3/13/2023 3/10/2023 Slickline - RAN HES PRESSURE / TEMP TOOL, 3.5" CENT & TAG R-NIP @ 13,036' SLM (13,063' MD) FOR 27' COR. RAN MAXFIRE W/ SC CBP & SET @ 13,013' SLM (13,040' MD), LRS TESTED TUBING TO 1500psi (pass). RAN HES MAXFIRE, TUBING PUNCH (21 - .45" holes) & PUNCHED HOLES FROM 12,993' SLM (13,020' MD) TO 12,988' SLM (13,015' MD). WELL S/I ON DEPARTURE, DSO NOTIFIED. END TICKET. Fullbore - Transfer 180 bbls crude from WCT to OTTs / Load tbg with 452 bbls crude. PT Tbg to 1500 psi with 2.1 bbls crude. Good test--lost 14 psi in 5 min. Circ well to crude with 305 bbls crude down tbg taking returns up IA to NS 19 FL Flush hardline with 4 bbls neat meth. AOGCC witnessed MIT-T and CMIT-TxIA. Witnessed by Austin McLeod. MIT-T passed to 1576 psi. CMIT passed to 2742 psi on tubing and 2706 on IA. AOGCC witnessed cement tag and passing 2500 psi MIT-T and combo are COA on Sundry 323-051. -WCB WELL S/I ON ARRIVAL. (d&t toc, state witness). RAN 2.83" CENT W/ 1-3/4" SAMPLE BAILER TAG TOC @ 12,347' SLM ( Well Name Rig API Number Well Permit Number Start Date End Date NS-23 Slickline / Fullbore / Wellhead 50-029-23146-00-00 203-050 3/8/2023 4/27/2023 Hilcorp Alaska, LLC Weekly Operations Summary Slickline: SET 5.963" RQ-FXE-SSSV IN HRQ-SVLN @ 2,148' MD - (3 set std pkg, 2nd lkdwn installed, sn: HNS-2, 93" oal). WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS. 4/25/2023 Slickline: RAN HES CBL, 40 ARM CALIPER, PRESSURE-TEMP SURVEY FROM TOP OF CEMENT @ 12,328' BLM TO SURFACE (good data). PERFORATE TBG W/ HES MAXFIRE & 4-5/8" GEORAZOR 5 SPF, 60* PHASE 11,131' TO 11,111' ELMD. Correlated to SLB PDC log dated 21-Jun-2003. 4/26/2023 Slickline: PERFORATE TBG W/ HES MAXFIRE & 4-5/8" GEORAZOR 5 SPF, 60* PHASE 11,111' TO 11,091' ELMD PERFORATE TBG W/ HES MAXFIRE & 4-5/8" GEORAZOR 5 SPF, 60* PHASE 11,091' TO 11,071' ELMD PERFORATE TBG W/ HES MAXFIRE & 4-5/8" GEORAZOR 5 SPF, 60* PHASE 11,071' TO 11,062' ELMD Correlated to SLB PDC log dated 21-Jun-2003 CONDUCT SBHPS PER PROGRAM (see log) PURGED 3 GAL HYDRO DOWN EACH BALANCE AND CONTROL LINES ATTEMPTED TO SET 5.963" RQ-FXE IN HRQ-SVLN @ 2,148' MD (brought back, all pins sheared) RAN 7" BRUSH, 4.65" GAUGE RING, BRUSH SVLN @ 2,148' MD FOR 25min 4/27/2023 Wellhead: Attempt to set 7" H BPV in tubing hagner, Could only get 1.5 LH Turns, Attempt to set 7" TWC with same result, Put heat on well then try again. 4/4/2023 Wellhead: set 6-3/8" CTS BPV, Nipple down tree, set CST dart in BPV, moved tree one bolt hole left to set up for producer piping, swapped wing with NS14, tested tree to 5000 psi for 10 mins, all tested good. remove CTS plug and BPV with dry rod. 4/24/2023 Slickline: R/U HES BRAIDED LINE UNIT. 4/2/2023 RAN HES CBL, 40 ARM CALIPER, PRESSURE-TEMP SURVEY FROM TOP OF CEMENT @ 12,328' BLM TO SURFACE (good data). PERFORATE TBG W/ HES MAXFIRE & 4-5/8" GEORAZOR 5 SPF, 60* PHASE 11,131' TO 11,111' ELMD PERFORATE TBG W/ HES MAXFIRE & 4-5/8" GEORAZOR 5 SPF, 60* PHASE 11,111' TO 11,091' ELMD PERFORATE TBG W/ HES MAXFIRE & 4-5/8" GEORAZOR 5 SPF, 60* PHASE 11,091' TO 11,071' ELMD PERFORATE TBG W/ HES MAXFIRE & 4-5/8" GEORAZOR 5 SPF, 60* PHASE 11,071' TO 11,062' ELMD CBL showed TOC in the IA at 7827' MD, which is better (shallower) than the planned 8000'. CBL results to AOGCC was a COA on Sundry 323-051. Permission was granted to proceed with perforating. -WCB Perf: 11,051 - 11,131', 4-5/8" 5 SPF 4/26/23 Per Hal CBL 4/25/2023 Note: Tbg restriction @ 7' md. Use R-Lock for SSSV. Do not run No-Go ring on lock. 13,015'-13,020' 11062'- 11131'O 4/26/2023 TOP OF CEMENT 7,827' MD per HAL CBL 4/25/2023 TUBING PUNCH 13,040'COMPOSITE BRIDGE PLUG 4-5/8"5 Hilcorp Alaska, LLC Ivishak perfs isolated by composite bridge plug.I 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Kuparuk Recomp 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?C.O. 739 Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13,980'11,419' 13,938' 11,382'N/A N/A Casing Collapse Conductor Surface 2,260 psi Production 4,760 psi Intermediate 7,020 psi Liner 7,500 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-440-7692 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Perforation Depth MD (ft): 13,434' See Schematic 858' See Schematic 4-1/2" and 7" 4-1/2' 13-3/8" 9-5/8" 3,666' 7"2,152' 11,517' 8,430 psi MD 8,160 psi 5,020 psi 6,870 psi 3,190' 9,376' 10,944' 3,666' 11,517' 11,419'13,980' Length Size Proposed Pools: TVD Burst NORTHSTAR / NORTHSTAR OIL PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312799 203-050 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23146-00 Hilcorp Alaska LLC NORTHSTAR UNIT NS-23 Tubing Grade:Tubing MD (ft): 11,282' / 9,187', 13,079' / 10,636', 13,122' / 10673', 2,148' / 1993' Perforation Depth TVD (ft):Tubing Size: 18.8# L80 and 32# T-95 13,127' 3/15/2023 9-5/8x7" ZXP, 7x4-1/2 S-3, 7x5 ZXP, 7" HRQ SVLN 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Aras Worthington aras.worthington@hilcorp.com Operations Manager m n P s 2 6 5 6 t Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Meredith Guhl at 11:02 am, Jan 27, 2023 323-051 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.01.26 13:51:42 -09'00' Torin Roschinger (4662) DSR-1/30/23 mgr Northstar, Kuparuk Oil DLB * AOGCC to witness slickline tag of (TOC ~13,000' MD) and MIT-T and CMIT- TxIA to 2500 psi * CBL results to AOGCC upon completion. email: melvin.rixse@alaska.gov -00 DLB 10-404 4100 X DLB 02/03/2023 MGR09FEB23GCW 02/10/23JLC 2/10/2023 2/10/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.10 12:05:08 -09'00' RBDMS JSB 021423 Re-complete to Kuparuk Well: NS-23 PTD: 203-050 Well Name:NS23 API Number:50-029-23146-00 Current Status:Operable Ivishak Gas Injector Rig:N/A Estimated Start Date:March 15, 2023 Estimated Duration:2 weeks Reg.Approval Req’d?Yes Regulatory Contact:Darci Horner 907-777-8406 (O) First Call Engineer:Aras Worthington 907-440-7692 (M) Second Call Engineer:Torin Roschinger 406-570-9630 (M) Current Bottom Hole Pressure (Ivishak):5200 psi @ 11,000’ ssTVD (est.) Maximum Expected BHP (Ivishak):5300 psi @ 11,000’ ssTVD Max. Anticipated Surface Pressure (Ivishak):4200 psi Gas Column Gradient (0.1 psi/ft) Current Bottom Hole Pressure (Kuparuk):2400 psi @ 9000’ ssTVD (est.) Maximum Expected BHP (Kuparuk):2450 psi @ 9000’ ssTVD Max. Anticipated Surface Pressure (Kuparuk):1550 psi Gas Column Gradient (0.1 psi/ft) History NS23 was drilled and completed as an Ivishak injector in 2003. The value of the well as an ivishak injector has depleted to the point where a re-complete as a Kuparuk producer is proposed. Objective Execute an IA cement job to get cement across the Kuparuk interval. Perforate and produce the Kuparuk. The proposed TOC the IA is ~8000’ MD which is ~3420’ TVD below the surface casing shoe. A full reservoir abandonment of the Ivishak is not proposed at this time because there may be a future desire to either go back to the Ivishak perforations or perform a CTD sidetrack to another Ivishak target. Post-job Evaluation o MIT-T and CMIT-TxIA o CBL to confirm the Top of Cement (TOC) Long-Term Integrity Monitoring o Biennial MIT-T and CMIT-TxIA o Monitor and Record WHPs daily -00 DLB Re-complete to Kuparuk Well: NS-23 PTD: 203-050 Procedural steps Slickline & Fullbore 1. Pull the SSSV. 2. Drift for CBP/Cement retainer to ~13,063’ MD (R-nipple of 3.437” ID). CBP and Retainer are both 3.44” max OD. 3. Tag the 3.437” XN nipple @ 13,063’ MD w/ appropriate sized drift (3.60” – 3.44”). Flag wire and correct depth to tubing tally. 4. Set 4-1/2” CBP (special order 3.44” OD for the 3.64” ID tubing) in the middle of the first full joint of tubing above the production packer (~13,040 MD*). 5. PT of tubing/CBP to 1500 psi to verify CBP set. Five-minute test, no more than 10% pressure loss. 6. Punch tubing in the middle of the first collar above the CBP. (~13,015’ – 13,020’ MD*). 7. Pump diesel down the tubing while taking returns up the IA, to confirm circulating rates and pressures through tubing punch. Circulate tubing and IA to diesel. (~722 bbls diesel surface-to-surface). 8. Set 4-1/2” Northern Solutions ball-drop-composite cement retainer (special order 3.44” OD for the 3.64” ID tubing) in the middle of the first full joint above the tubing punch (~13,000’ MD*) *Note: All depths reference tubing tally of 6/8/2003. Fullbore 9. Pump down production tubing with returns from the IA: ¾10 bbls FW + Surfactant ¾108 bbls 14-15.8 ppg Class G cement ¾Chase w/phenolic landing ball & two foam wiper balls ¾Chase balls w/ ~428 bbls diesel and look for indication of ball landing on-seat ¾Pump no more than 433 bbls total displacement after cement ¾If ball seats, apply no more than 2400 psi tbg pressure to verify seating (~500 psi over lift-pressure) ¾Bleed-off tubing pressure. Bleed no more than 2-bbls to see if retainer poppet holds pressure from IA to tubing (lift pressure). If it does not hold pressure, bump tubing pressure back up to lift pressure and lock in pressure w/ tree valves Note: expected lift pressure is ~1900 psi Cement Calculations ¾7” x 4-1/2” volume from 13,015’ – 11,282’ MD:30 bbls ¾9-5/8” x 4-1/2” volume from 11,282’ – 11,230’ MD:2.7 bbls ¾9-5/8” x 7” volume from 11,230’ – 8000’ MD:75 bbls Total Cement to pump: 108 bbls Slickline & Fullbore 10. D&T TOC. 11. Log Memory CBL from tag of TOC in tubing to ~6000’ MD to identify TOC. 12. Conduct AOGCC witnessed MIT-T and CMIT-TxIA to 2500 psi. Ensure 24-hour notice provided for AOGCC. 13. Leave CBP, cement, and cement retainer in tubing to isolate Ivishak from Kuparuk perforations. AOGCC to witness. email to AOGCC. Re-complete to Kuparuk Well: NS-23 PTD: 203-050 E-Line 14. Perforate the Kuparuk per attached proposed schematic. Slickline 15. Set SSSV. Well Diagnostics & WIE 16. Update AKIMS and add biennial MIT-T and CMIT TxIA. Re-complete to Kuparuk Well: NS-23 PTD: 203-050 NS23 Current Schematic 7” Casing Annular TOC logged w/ USIT @ ~13,300’ MD 9-5/8” Casing Annular TOC @ ~5170’ MD (w/ 30% washout) Confining Shales between Kuparuk and Ivishak: 11,342’ - 13,387’ MD Re-complete to Kuparuk Well: NS-23 PTD: 203-050 Re-complete to Kuparuk Well: NS-23 PTD: 203-050 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Brian Bixby Petroleum Inspector Well Name NORTHSTAR UNIT NS -23 Insp Num: mitBD8190619123252 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 1, 2019 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska LLC NS -23 NORTHSTAR UNIT NS -23 Src: Inspector Reviewed By: P.I. Supry 113z— NON-CONFIDENTIAL Comm API Well Number 50-029-23146-00-00 Inspector Name: Brian Bixby Permit Number: 203-050-0 Inspection Date: 6/182019 - Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well FI---NS---23 "'Type Inj Ec -TVD T 10650 - Tubing 4850 - 4850 4850 ' 4810 - 2030500 iType Test I SPT Test psi 2662 IA 1168 ' 2815 2774 2710 BBL Pumped: 3.4 BBLReturned: 3.4 OA 57 198 194 - 191 Interval I 4YRTSr P/F I P� Notes: Monday, July I, 2019 Page 1 of I ,,,A1//7 s9 THE STATE Alaska Oil and Gas °fALASKA Conservation Commission Witt �ITh GOVERNOR SEAN PARNELL 333 West Seventh Avenue c- Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 CpNNE � � S Mark Sauve t2,)\4t2,)\4Fax: 907.276.7542 S 1� G° ��U Petroleum Engineer D 3 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Northstar Field,Northstar Oil Pool,NSTR NS23 Sundry Number: 314-010 Dear Mr. Sauve: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 'C2/1 Daniel T. Seamount Commissioner DATED this - 6 day of January, 2014. Encl. • Ot.Lk 41 L. --L i V — STATE OF ALASKA ‘... J AN 0 7 2'w ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AO G CC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Water Wash 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number BP Exploration(Alaska),Inc. Development ❑ Exploratory ❑ 203-050-0 3.Address: Stratigraphic ❑ Service Q 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23146-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 458A ., NSTR NS23 . Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312799 • NORTHSTAR, NORTHSTAR OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13981 ' 11420 . 13973 11413 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 165 20"169#X-56 41-206 41 -206 Surface 3626 13-3/8"68#L-80 40-3666 40-3189.76 5020 2260 Intermediate None None None None None None Production 11478 9-5/8"53.5#L-80 39-11517 39-9375.41 7930 6620 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 13629-13869 11112.22-11320.88 See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths 7"HES HRQ SSV 2148', 1992.45' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program ❑� BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑2 • 14.Estimated Date for 15.Well Status after proposed work: 1/20/14 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ [I] , WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Sauve Email Mark.Sauve( BP.com Printed Name Mark Sauve Title PE Signature Phone Date /7/......4„.......& 564-4660 1/7/2014 COMMISSION USE ONLY !�j Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 tl�O 1 0 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS MAY 10 2014 Spacing Exception Required? Yes El No 117_1 Subsequent Form Required: / 0 — 4 D APPROVED BY Approved b,/ / COMMISSIONER THE COMMISSION Date: / /1 /9 ' 1 ✓�C/� ® Form 10-403 Rev �iali d T/2010 r Approved applicNtrLthe date of approval.40e../// Submit in Duplicate k/. ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V1.1,DBR,LHD 11/05/13) General Information Well Name: NS23 Well Type: Natural Flow Producer Activity Description: Solvent Well Activity Classification: Conventional 4 Field/Reservoir: Northstar Cost Code/AFE: ANSINJEC WETS Job Type: Inj WW-Water Wash 12 Month Avg IOR,bopd: 30 AWGRS Job Scope: PROFILE MODIFICATION Estimated Cost, $M: _ Sundry Form 10--403 Reqd? Yes Sundry Form 10-404 Required? Yes Other regulatory requirements? No Base Management Engr: Mark Sauve Contact numbers: 564-4660(w), 748-2865 Im), 336-6128(h) Well Intervention Engr: Contact numbers: Lead BM Engineer: Mark Sauve Contact numbers 564-4660(w), 748-2865(m), 336-6128(h) Date Created: � 1/6/2014 Revisions(date,who,what changed): Current Well Status Information Current Status: Operable Recent Well Test or Injection Rate and Pressure: 1/2/14: 48.8 MMSCFD 04917 psi WHP. Recent H2S (date,ppm) 8/18/13 0 If inoperable or under evaluation, why? Datum depth,ft TVDss,MD 11,100 TVDSS Maximum Deviation(angle and depth) 42 10,324 Reservoir pressure,psig 5,200 Minimum ID(depth) 3.260'in RN nipple®13,113'MD Reservoir temperature,F 250 Last downhole operation(date,operation) Water wash stimulation pumped on 4/16/13. Shut in wellhead pressure 4,100 Most recent TD tag, (date,depth,toolstring OD) Tagged 13,929'ELMD w 2.875"dummy gun on 6/20/03 Known mechanical integrity problems(specifics) Comments,well history, NS23 is a relatively trouble-free gas injection well in the mid-field area of the Northstar reservoir. NS23 is the#6 gas injection well(by rate)at Northstar and , background information,etc: has responded favorably to water washes in the past. Well Intervention Details Suspected Well Problem: Declining well injectivity Specific Intervention or Well Objectives 1 Stimulate perfs and improve gas injectivity. 2 3 Key risks,critical issues: Mitigation plan: 1 2 3 Summary Step# Service Line Activity 1 F Pump fresh water/diesel/xylene wash as per program 2 Ops Allow water to soak 24 hours before putting well back on injection. 3 Detailed work scope(If no recommended practice or standard procedure exists for the intervention type, a well specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) Expected Production Rates: BOPD MMSCFD BWPD FTP(psi): Choke setting: Post job POP instructions: POP well with gas lift as soon as possible post job. Attachments- include in separate excel worksheets Required attachments: Current wellbore schematic As needed depending on type of work: Perforating form,logging form,well test chart, annotated mini log, annotated log section, tubing/casing tallies,wellhead info,etc Approvals Base Mgmt Approval: Date: Wells Approval: Date: TREE• ABB-VG1 7 8 SKS SAFETY MOTEL WNL PM/WM A SS3K""1 VAZIL HEAD- ABB v0I1518'%ALTO OWL 8 WS I isl S2 3 JOMIT OF 11111/11FT 1CR-1111 vAY TOP IC ACJICISS A CT JA TOR- BA‹F_R T T LINER JUST BELOW T1* T WING.".• KS 4,EK, • 58 BF ELEV- 39 5';CB 15 81 KOP• 284' lArs.Anglo- 12' 1 co ze I 2984" MD [ 2145' F-7 320 PIRO SV •l TVD• 105iar Own - I3CAL OY.925 P-110 VARA TOP OC 03'SS 113-le"CSG,REA,L-80 BIC JD•1211? MAU Minimum II3 a 3.260"Cp 13117 4-112"HES RN NIPPLE 11230' Hr X 41,7X0.13 Isar r TOG,321 T.98 VAI TORHC D.8 Car --I 11230' I/ JOINTS 4.1/2'131CR(owe safety rots) il2e7 1-19-Sql"X r BKRZY3,14711.1P,113.820' I 1/— !TOP OF 7'LP H 111262' T I 11304 }4-&?X r SKR FLEX L OO(*CA 0 9.5,fr CSG,51 NV L-80 8M‘C --I 1151T tAl 8 535' 13013' 1-14•1/2'PES R KW,13•3437" I 1307V F-17"X 4-1/7 BKR S-3 PERM RXR R3.150' I ff---1 1 31CCT H4-1/2'KESRNP,113.3A3TI r Fp"1/2'HES t o.121,7 MAW a.11:4 131fl' r X 5'BKR ZX Pi Wi TOP CKR,0•7 1 41/2 1BC.,1881,L-80 VAIIR TOR Mara. — 0 129 411.ID•3880' 13121' 2' F G8ING MULES-0E10 1850" I Joerrs4.1a-130204N 80,01t nabol \ 1 3145' 1-17-x 5"8.02 FLEX L00(402,13-7 I 7'LNR.290.1-80 MYER 51 I, 13.134' I 315( I-15-x 4 V?50,8)•39W I 03133 WI,D.ft 18.1" NOTE T CS 4'ABOVESAG FIVER RA1D4 SUMMARY REF LOG LIAO al 08137/03 WAN GROCCL OW 1.433 A810.8 AT TOP iliERF- 31 dap 11182E . Flew to ProittaralE to nalannel pall Ws SE St r einzAvAL trot Op. z DATE 2.7/8' 8 13829• 138133 0 01XCI3 4.1 r2-Lota.¶2181.1-80 VAA•ACE IC 01 S2 431,ID•1964' 476 A DATE REV BY COIRINEKITS DATE RS/BY COMENTS 04017THSTAR • 4714743 UNIT CON PLET1ON WEI 4S21 I 1/(I7529 8291 NEW F014,447 A 5.0 STH POET 41-1.23308.03 1 2/C4)A W1t K1 RN HIRE CORRECTID1K API Kb 50-029,,73 148-00 11/275.17 VIFFIROC WEL 1...HDALOCA TION CORFEC 1154S SEC 1 1 1184.R1 1E 12439 FSL 89.41 031800 RCP SV FIN NP COPI2(01,C603) 17r11 1.41A0 ADDED SSSV SAFETY P8)TE 1 EP Exploration 14144414 a 1 • • bP 0 Minilog(�f�5or Well Techlog Project NORTNETAR NS23 - LAURA..LARSON SoMe.1.500 l s5 6!15/2012 Well-NS23 Injector 101:600202314600 001100:3653 s 050.7.15 SPUD 2a1.2003-04-0200:0000 Counts US Siert norm:P023 6avaten datum 10 t:603334669 Corrol.t00 data:2003-00-22 00:00:00 PION:NORTN6000 Long nacre:NORTNSTAR NO 23 Total Meth:1P61 10006ude:•138.6913176 Status: State:AIaI Con!Mat.systens 111023 AR Ut6ude.70. OO.tator.6*0* Conies,6►2A 01 ata ~ TVDSS MD a g.w.F OE (FEET) (RI PE Notes 6E5 WO DEN sots it. ,1:500 1'500 9c w na`YgR ,_ ' SDE w ..... ... "YOSS .�. SWT Pox T .._ GR!! a [P 4 OSS 0(.... 1 1 i7Y90b0 „nag t id I 1 ;u6 PtPP _ _ .t. ,_1 ..$ .:, 4; s3 • i 4, , .,,,„,.. n,n. • as 5-13909 V • 11500 .1 1 X13950 1110 ' • 11111 ' '^ N E e o o e e I I I I I li Zio'ilb"o8og8✓rcl o E 0 0 0 0 0 �L IIIII ... m w I I I I k R,t 8$g R�ry_m g 'Ai $ — — — — I I I I m Nn n n n mil oleloEo o olx o n — — — - - 1 1 1 1 1 88888888.8880 X 5 8, g 1 1 1 1 1 '888888g$g888g8g88 3 �g n n n oo c d I I I I I $° p g'Pa�3SP6$; E i - — — — — 1 1 1 1 1 N ` o m m Nr = O - - — — — Z 1 I 1 I Z m 1LLwN_ E` x a . m s o I I I I I w sNNtlIRR8R�88$� > O_L v o a O o (° o. an I I I I m I cu mm c , c 1 1 1 1 1 R 88$°;S;R 8 R 8.888$§ 'a • 'Q O DY E — - — — '-' E 1 1 1 1 1 $ .O 5 Z d O I ' - y c HH E .�a'LL — a 1 d _ re _ o ' 1 1 1 1 1 em8QQQpp5R�y� �n O ° S,1 .,,W r _ n 5 rv° ;!,1 ,35 7,,!!t e, E d _ — - — 1 1 1 1 1 $ 3 5 _ 1 1 1 1 1 a sg I.- _- - _ a 9 ._I I I2I I 0 LL ` of I ISI I � oLL E ¢ rc� lal Irl I— E.1: . d m ti E g I;,a b ICI 1.1 I _ Z v, JI-�m F 9 ; - - r - 1 eels) 121 I = _ 3 ao 3 3''C w E m m l 4I Hl IgIoI I a -' I a',a,rc,a: 1 I I — — — — — ' - �Itil�lel�'I� e P. U gg d m 3 I 0 a $ o E CL a $p 1,) -Z:;'. . e; :s ; a k g B m K + a $ _ _ a = 3Y � 3a` �g I a ED. n LL E l l § ! = 1111 g4 1,,i ; t _ _ ' U I' __..._._ .. O Subsea(Wet Tree-Semi Submersible, Intervention Vessel) or Offshore Under-balanced ❑ Well rate15 mboed (or Operations(Snubbing) 90 mmscfd') or ❑ Multiple challenges, associated with high uncertainty (low predictability) and low Incremental added / manageability relating to a complex combination of well integrity, reservoir / wellbore restored production ? 5 conditions,production chemistry/flow assurance challenges. mboed(30 mmscfd')." O Technology/Technique new to Industry. ❑ Activity costs as per Regional VP Resource ❑ Well Activity performed on a Tier 1 or Tier 2 well, defined in GWO Wells Classification Delegation of Authority (UP 4.1-003) (DoA)_ Conventional 2 Complexity Criteria Conventional 2 Production/ Regional DoA Criteria ❑ Single or multiple element integrity test failures with identified moderate potential to ❑ Well rate ..3 mboed and impact or be impacted by the Well Activity; e.g. acid treatment/flowback in a well with 15 mboed (or 18 and 90 corroded tubing_ mmscfd') or Incremental ❑ Highly dynamic or poorly understood reservoir or wellbore conditions or complex added /restored production production chemistry challenges which may involve additional (beyond local norm) ?f-1 mboed and -=5 mboed measures to effectively manage the impact on the planned Well Activity. (6 and 30 mmscfd')." ❑ Challenging wellbore trajectory which may involve additional (beyond local norm) ❑ Activity costs as per measures to effectively manage the impact on the planned well intervention. Regional Base ❑ Offshore Platform Rig (Dry Tree), Offshore Jack-up Rig (Dry Tree), Offshore Hydraulic Management Manager Workover Unit(Over-balanced operations), Land Drilling Rig. Delegation of Authority ❑ Technology/Technique new to BP. (DoA) Conventional 3 Complexity Criteria Conventional 3 Production/ Regional D0A Criteria ❑ Single element well integrity failure is known to exist or uncertain integrity status with ❑ Well rate 1 m boed and potential to impact or be impacted by the planned activity e.g. production log on well with 3 mboed (or 6 and 18 no Well Activity history but report of failed tree valve. mmscfd`) or Incremental ❑ Dynamic but well understood reservoir or wellbore conditions with well understood added/restored production production chemistry issues (e.g. hydrates, scale, wax, asphaltenes). Addressed by - 0.25m boed and . established local work measures (and proven track record) to effectively manage the mboed (1.5 and 6 impact on the planned Well Activities. mmscfd')." ❑ Well trajectory access issues covered by established local work measures (and proven Activity costs as per track record)that effectively manage the impact on the planned Well Activities. Regional Base ❑ Land operations with a Hydraulic Workover Unit(Over-balanced operations) Management Team Lead Delegation of Authority ❑ H:S concentration in reservoir/wellbore fluids > 10 ppm, partial pressure H25 > 0.05psia (DioA) or iron sulfide scale present(unless SoP exists). ❑ Technology/Technique new to Region/Team. ❑ Hazardous Materials in use during Well Activities or generation of hazardous materials during Well Activities, including corrosive (acids and caustics), toxic, cryogenic and flammable materials,explosives and radioactive sources/materials. (unless SoP exists). ❑ Simultaneous Operations ISIMOPS): Well Activity may impact or be impacted by other work in the immediate vicinity e g a Well Activity conducted adjacent to a new well commissioning operation. ❑ Production Facility Impacts: Either safety and operational risk impacts to or resulting from the production facility (e.g_ returned fluids, pressures, etc. are likely to cause facility impacts,or facility shutdown,start-up,etc.are likely to impact the well activity). Conventional 4 Production/ Conventional 4 Complexity Criteria Regional DoA Criteria ❑ Single element integrity "anomaly'" is known to exist and being managed within existing ❑ Well rate t1 mboed (or 6 acceptance criteria but not expected to directly impact or be impacted by the planned mmscfd') or Incremental Well Activity; e.g. slickline gauge run on a well with annulus sustained casing pressure added/restored production anomaly. k.0.25mboed/12 months ❑ Static or benign reservoir or wellbore conditions with no significant production chemistry (1.5 mmscfd")." issues which might impact the planned Well Activity. ❑ Activity costs as per ❑ Well trajectory poses no access issues that might impact the planned Well Activity. Regional PE Delegation of ❑ Non-rig(Land and Offshore), Land Service Rig/Pulling Unit(unless SoP exists). Authority IDoAL Aa references to gas production refer to commercial gas only "Added/restored production refers to average over following 12 months a) -oco 00000th cu to ao co co co co CA O X J J J J J a) Q O O O O 0 0 0 co CA N O N CO O Cr2 (0 O U) CO Ch O) Cr U N I� CO N _ 1 0 0 0 0 0 0 0 Co Co coco N O • N a- .4- co O cc) O m co 0o I� lC) cn N _O N.- to m O Cr d' co c0 Q N O a- O M O O Q ~ - coo , O O co • N C7 e- C) to CA CU d) EEa) C N- to O 1 O Ncc)• m O �t co Oto O N co co, Q N CO co co Cr) � J n 0CNI CO 1- r a0 N A) O C) CO V Q v c7.) C� v " Cr) • a- a- 0 0 0 0 Co CCcCtn CO rn a) 4*• J CO CC) co 000 F- N d) 4tN M CO cd 4 Cl) CO 0)• N - r U) r e N oo r-- M 4 CA 4 • to to co N C O c CD O 0 0 J N M z O O ~ 1 co U ✓ 0 CLCLO lai Z Z Z W W O fx m m O Z Z D D D Packers and SSV's Attachment ADL0312799 Well Facility Type MD Top Description TVD Top NS23 SSSV 2148 7" HES HRQ SSV 1992 NS23 PACKER 11282 7" Baker ZXP Packer 9187 NS23 PACKER 13079 4-1/2" Baker S-3 Perm Packer 10636 NS23 PACKER 13122 4-1/2" Baker ZXP Packer 10672 NS23 PACKER 13122 4-1/2" 18.8#L-80 10672 RECEIVED STATE OF ALASKA AKA OIL AND GAS CONSERVATION COMM ION MAY 0 7 2013 REPORT OF SUNDRY WELL OPERATIONS G 1. Operations Abandon 11 Repair Well LI Plug Perforations 11 Perforate U Other Wa te r Wash Performed: Alter Casing ❑ Pull Tubing Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator ✓ 4. Well Class Before Work: / 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ 203 -050 -0 3. Address: P.O. Box 196612 Stratigraphid Service 5 6. API Number: ✓ Anchorage, AK 99519 -6612 50- 029 - 23146 -00 -00 7. Property Designation (Lease Number): ,/ 8. Well Name and Number: ADL0312799 NSTR NS23 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted NORTHSTAR, NORTHSTAR OIL 11. Present Well Condition Summary: / Total Depth measured 13981 feet Plugs measured None feet true vertical 11419.58 feet Junk measured None feet Effective Depth measured 13973 feet Packer measured See Attachment feet true vertical 11412.53 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 165 20" 169# X -56 41 - 206 41 - 206 4260 2590 Surface 3626 13 -3/8" 68# L -80 40 - 3666 40 - 3189.76 5020 2260 Intermediate None None None None None None Production 11478 9 -5/8" 53.5# L -80 39 - 11517 39 - 9375.41 7930 6620 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 13629 - 13869 feet True Vertical depth 11112.22 - 11320.8E feet SCANNED JUL 10 2,0 13 Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer 7" HES HRQ SSV 2148 1992.45 SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: ✓ Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service 5 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPLI GSTOR ❑ WINJ ❑ WAG ❑ GINJ 5 ✓ SUSP ❑ SPLUGE] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313 -131 Contact Nita Summerhays Email Nita.SummerhaysCc�BP.com Printed Name Nita Summer h s Title Petrotechnical Data Technician Imo/ , / Phone 564 -4035 Date 5/7/2013 Signatur- �� / %� /x. / /Li /��- vi- F RBDMS MAY - 8 201 7 /f 4/3 r . / Form 10 -404 Revised 10/2012 Submit Original Only • • • Daily Report of Well Operations ADL0312799 ATMVFTYDATE a SUMMARY o • • • emp= oven rea men mprove njec ivi Pumped 5 bbls 60/40 meth, 80 bbls 50/50 diesel /xylene, 3 bbls 60/40 meth spacer. Loaded Tbg with 530 bbls freshwater w/ F -103 surfactant. Freeze protected Tbg with 15 bbls 60/40 meth. Final WHPs 1150/47/8 4/16/2013 Well Tender to POI FLUIDS PUMPED BBLS 23 METH 80 DIESEL/XYLENE 530 FW W/F -103 633 TOTAL Casing / Tubing Attachment ADL0312799 Casing Length Size MD TVD Burst Collapse CONDUCTOR 165 20" 169# X -56 41 - 206 41 - 206 4260 2590 LINER 2152 7" 29# L -80 11282 - 13434 9187.01 - 10943.8 8160 7020 LINER 858 4 -1/2" 12.6# L -80 13122 - 13980 10672.3 - 11418.7 8430 7500 PRODUCTION 11478 9 -5/8" 53.5# L -80 39 - 11517 39 - 9375.41 7930 6620 SURFACE 3626 13 -3/8" 68# L -80 40 - 3666 40 - 3189.76 5020 2260 TUBING 11192 7" 32# T -95 38 - 11230 38 - 9145.25 10760 9730 TUBING 1897 4 -1/2" 18.8# L -80 11230 - 13127 9145.25 - 10676.6 13380 13830 • • • • • Packers and SSV's Attachment ADL0312799 SW Name Type MD TVD Depscription NS23 SSSV 2148 1935.9 7" HES HRQ SSV NS23 PACKER 11282 9130.46 7" Baker ZXP Packer NS23 PACKER 13079 10579.36 4 -1/2" Baker S -3 Perm Packer NS23 PACKER 13122 10615.75 4 -1/2" Baker ZXP Packer ' TREE = ABB -VGI 7" 6. SA NOTES: WELL REQUIRES A SSSV. ***5 WELLHEAD = ABB -VGI 13 -5/8" MULTIBOWL 6.5 NS23 JOINTS OF 18.8 # /FT 13CR -95 VAM TOP HC ACROSS ACTUATOR = BAKER THE 7" LINER JUST BELOW THE 7" TUBING. *" KB. ELEV 56.55' BF. ELEV = 39.5' (CB 15.8') KOP= 284' Max Angle = 42 @ 10324' Datum MD = 12984' I I 2148' I- 7" 32# HRQ SVLN , ID = 5.963" OD l Datum TVD = 10500' SS INCALOY -925 P-110 VAM TOP HC 113 -3/8" CSG, 68 #, L -80 BTC, ID = 12.415" H 3666' Minimum ID = 3.260" @ 13113' 4-1/2" HES RN NIPPLE 11230' I-17" X 4 -1/2" XO, ID = 3.958" I 7" TBG, 32# T -95, VAM TOP HC. ID = 6.094" 11230' I/ 5 JOINTS 4 -1/2" 13CR (see safety note) I 11282' H9 -5/8" X 7" BKR ZXP HR LTP, ID = 6.20" I TOP OF 7" LNR H 11282' II T 11304' H 9 -5/8" X 7" BKR FLEX LOCK HGR, ID = 6.20" I 9 -5/8" CSG, 53.5 #, L -80 BTM -C --I 1151T I ID = 8.535" I 13063' I-{ 4-1/2" HES R NIP, ID = 3.437" 13079' 1-17" X 4 -1/2" BKR S -3 PERM PKR, ID = 3.56" I I 13102' I--14-1/2" HES R NIP, ID = 3.437" 13113' 1-14-1/2" HES RN NIP, ID = 3.260" (13097' ELMD) 13122' 1-1 7" X 5" BKR ZXP LNR TOP PKR, ID = ? I 4 -1/2" TBG, 18.8 #, L -80 VAM TOP HC — 13127' 0129 bpf, ID = 3.640" I 13127' 1-14-1/2" SELF ALIGNING MULESHOE, ID = 3.850" I 5 JOINTS 4 -1/2" 13CR (see safety note) 13145' I -17" X 5" BKR FLEX LOCK HGR, ID = ? 7" LNR, 29 #, L -80 HYDRIL 511, H 13434' 13154' H 5" X 4-1/2" XO, ID = 3.958" I .0383 bpf, ID = 6.184" NOTE: THIS IS 4' ABOVE SAG RIVER PERFORATION SUMMARY REF LOG: LWD on 05/07/03 TIE-IN LOG: GR/CCL on 06/21/03 ANGLE AT TOP PERF: 31 deg @ 13629' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn /Sqz DATE 2 -7/8" 6 13629 - 13869 O 06/25/03 PBTD H 13938' ELM 4 -1/2" LNR, 12.6 #, L -80 VAM -ACE -1 13980' �� 0.0152 bpf, ID = 3.958" i•�∎ ∎ ∎ •.• DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 07/07/03 EMF INIT COMPLETION WELL: NS23 11/07/05 BJM NEW FORMAT & XO DEPTH PERMIT No: 2030500 12/02/05 WRR/TLH RN NIPPLE CORRECTION API No: 50- 029 - 23146 -00 11/27/07 WRR/PJC WELLHD /LOCATION CORRECTIONS SEC 11, T13N, R13E, 1269' FSL & 647' FEL 03/18/09 RCT /SV RN NIP ID CORR (03/05/09) 02/17/11 MB /JMD ADDED SSSV SAFETY NOTE I BP Exploration (Alaska) • • *8. '\ //7; t THE STATE Alaska Oil and Gas [ � � "' ®„A LASKA Conservation Commission wR GOVERNOR SEAN PARNELL 333 West Seventh Avenue P' Anchorage, Alaska 99501 -3572 Main: 907.279.1433 1 �fl4 sumo Fax: 907.276.7542 Mark Sauve MAR L Ul Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 V Anchorage, AK 99519 -6612 Re: Northstar Field, Northstar Oil Pool, NS23 Sundry Number: 313 -131 Dear Mr. Sauve: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster gym`,/ Chair DATED this/ d f March, 2013. Encl. 1 1 a,ew • • I lk' CiS 1- s 3( I " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations❑ Perforate ❑ Pull Tubing ❑ Time Extension El Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Water Wash 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 203-050-0 • 3. Address: Stratigraphic ❑ Service 6. API Number. P.O. Box 196612, Anchorage, AK 99519 - 6612 50 -029- 23146 -00 -00 . 7. If perforating: 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? 458A . NSTR NS23 . Will planned perforations require a spacing exception? Yes El No El , i ° 9. Property Designation (Lease Number): 10. Field /Pool(s): r ADL0312799 NORTHSTAR, NORTHSTAR OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13981. 11420 . 13973 11413 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 165 20" 169# X -56 41 - 206 41 - 206 Surface 3626 13 -3/8" 68# L -80 40 - 3666 40 - 3189.76 5020 2260 Intermediate None None None None None None Production 11478 9 -5/8" 53.5# L -80 39 - 11517 39 - 9375.41 7930 6620 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13629 - 13869 11112.22 - 11320.88 See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths 7" HES HRQ SSV 2148', 1992.45 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Development El Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ Q - WAG ❑ Abandoned ❑ Commission Representative: GSTOR El SPLIJG El 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Sauve Email jv1ark.SauvenBP.corn Printed Name Mark Sauve Title PE Signature Phone 564 -4660 Date 3/12/2013 , , , ,,; ( 4 , COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 1 2 ✓ -- ( "1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RRDMS MAR 21 20 Spacing Exception Required? Yes ❑ No Subsequent Form Required: / �� D // v APPROVED BY Approved by: / , COMMISSIONER THE COMMISSION Date: 3 _ 3 111 4;9 tl) dI]IN 1-4 R v 1 Approved application is valid for 12 months from the date of approval. Submit in Du licate ; k AL ZL F3 /I „„.e /944 Version/ .1 04/28/2010 Fullbore Pumping Design Template Well Name NS -23 Job Scope Solvent Treatment No Record, H2S (ppm /date) WBL Cat IOR 5000 Max Pumping Pressure (psi) Well Type GI AFE ANSINJEC • Main Fluid Type Date 3/14/2013 IOR 100 • 600 Main Fluid Volume (bbls) Engineer Mark Sauve Phone 564 -4660 Methanol (60/40) Freeze Protect Type Job Objective 10 Freeze Protect Volume (bbls) If Applicable Recent Tbg Fluid Level (ft) Improve injectivity by dissolving salts and possibly asphaltenes in the • If Applicable Recent IA Fluid Level (ft) tubing and formation. Diesel /Xylene washes have been used If Applicable Recent OA Fluid Level (ft) successfully in the past on the NGI/WGI /AGI gas injectors to improve If Applicable Expected Tbg Fill Up Volume (bbls) injectivity. If Applicable Expected IA Fill Up Volume (bbls) If Applicable Expected OA Fill Up Volume (bbls) 438 Wellbore Volume to Perfs (bbls) Fullbore Pumping Schedule 5200 Anticipated Bottom Hole Pressure (psi) Pump Volume Rate Max 1 Select 1 Tubing /Casing within Pressure Limits? Stage Fluid Type Into (bbls) (bpm) Pressure Size Burst/Collapse 80% Burst/Collapse Tubing Burst (psi) 7 10,760 8,608 I Pre -Flush I I Methanol (60/40) I Tbg 10 51 5000 Tubing Collapse (psi) 7 9,730 7,784 Casing Burst (psi) 4 5 8,430 6,744 I Solvent 1 I Select Fluid Type 1 Tbg 100 ( 511 50001 Casing Collapse (psi) 4.5 7,500 6,000 1 Load 1 1 Select Fluid Type 1 Tbg 1 6001 I 5 1 2500 Select Input Depth • Integrity Issues? No unknown 1 Freeze Protect 1 1 Methanol (60/40) 11 Tbg 1 101 1 51 1 2500 No Input Depth 1 Select Stage 1 Select Fluid Type 11 Select 1 1 1 I 1 1 1 No Tubing Caliper? Burst/Collapse ratings may need to be derated based on tubing condition Select Production Packer within Pressure Limits? Detailed Pumping Procedure Rated Packer dp Max Anticipated dp at Packer 1 10 bbls 60/40 meoh spear 2 100 bbls 50/50 diesel /xylene I Not Necessary 1 Hold Pressure on Other Strings? 3 600 bbls of fresh water with 0.02% F -103 surfactant Tubing (psi) 4 10 bbls 60/40 meoh IA (psi) 5 RDMO. Return well to gas injection OA (psi) 6 - i • • Fullbore Pumping Program for Field Well Name NS -23 Job Scope Solvent Treatment Well Type GI AFE ANSINJEC Date 3/14/2013 IOR 100 Engineer Mark Sauve Phone 564 -4660 H2S �- Job Objective Improve injectivity by dissolving salts and possibly asphaltenes in the tubing and formation. Diesel /Xylene washes have been used successfully in the past on the NGI/WGI /AGI gas injectors to improve injectivity. Fullbore Pumping Schedule Stage Fluid Type Pump Into Volume (bbls) Rate (bpm) Max Pressure 1 Pre -Flush I Methanol (60/40) Tbg 10 1 1 5 I 5000 2 Solvent Select Fluid Type Tbg 100 ( 5 5000 I 3 Load I Select Fluid Type Tbg I 600 5 2500 4 Freeze Protect Methanol (60/40) Tbg 10 1 5 I 2500 I 5 I Select Stage Select Fluid Type Select Detailed Pumping Procedure 1 10 bbls 60/40 meoh spear 2 100 bbls 50/50 diesel /xylene 3 600 bbls of fresh water with 0.02% F -103 surfactant 4 10 bbls 60/40 meoh 5 RDMO. Return well to gas injection 6 Additional Details If Applicable Recent Tbg Fluid Level (ft) Integrity Issues? No unknown If Applicable Recent IA Fluid Level (ft) No Input Depth If Applicable Recent OA Fluid Level (ft) • • Freeze Protection - see PE manual for additional information Freeze Protect to 2500' TVD in GPB. Use 60/40 Meth Water for Injectors Use 5 bbl 60/40 Meth Water spear followed by dead crude for Producers Pipe Data (L -80 aim 2.375 4.60 2.38 2.00 1.90 11780.00 11200.00 0.00387 258.6 0.00548 182.5 2.875 6.50 2.88 2.44 2.35 11160.00 10570.00 0.00579 172.8 0.00803 124.5 3 188 6.40 3.19 2.81 2 68 1 1 1 1 1 . 0 0 11 11 1 00 0.00769 130 1 0.00987 101.3 3.500 9.30 3.50 2.99 2.87 10530.00 10160.00 0.00870 115.0 0.01190 84.0 4 500 12 60 4.50 3.96 3. 7500 00 8430.00 0 01522 65 7 0 01967 50.8 5.000 18.00 5.00 4.28 4.15 10490.00 9910.00 0.01776 56.3 0.02429 41.2 5 500 17 00 5.50 4.89 4.77 6280 00 7740.00 0.02325 43.0 0.02939 34.0 7.000 26.00 7.00 6.28 6.15 5410.00 7240.00 0.03826 26.1 0.04760 21.0 7.000 29 00 7.00 6 18 6 06 _ 7020.00 _ 8160 00 0.03715 26 9 0 04760 21.0 7.625 29.70 7.63 6.88 6.75 4790.00 6890.00 0.04592 21.8 0.05648 17.7 9.625 47.00 9 63 8.68 8.53 4760 00 6870.00 0 07321 13.7 0.08999 11.1 13.375 72.00 13.38 12.35 12.19 2670.00 5380.00 0.14809 6.8 0.17378 5.8 custom 6.000 4.000 0.01561 64.1 0.03497 28 6 Bursts OD GRADE WT Burst 3 1/2" 80 9.3# 10160 4 1/2" 80 12.6# 7500 5 1/2" 80 15.5# 7000 80 17# 7740 7" 80 26# 7240 80 29# 8160 95 29# 9690 110 29# 11220 7 5/8" 80 29.7# 6890 80 33.7# 7900 95 29.7# 8180 9 5/8" 55 36# 3520 55 40# 3950 80 40# 5750 80 43.5# 6330 80 47# 6870 80 53.5# 7930 95 47# 8150 10 3/4" 55 45.5# 3580 80 45.5# 5190 80 55.5# 6450 11 3/4" 95 60# 6920 13 3/8" 55 54.5# 2730 55 61# 3090 55 68# 3450 80 68# 5020 80 72# 5380 95 72# 6390 16" 80 84# 4330 18 5/8" 55 96.5# 2510 55 109.3# 2910 20" 40 94# 1530 55 133# 3060 Brine Design Notes Revised: 5/1/00 NaCI KCI CaCI NaBr Design Notes: 8.5 29 8.4 31 8.5 30 8.5 30 8.6 27 8.5 30 9.0 22 9.0 25 Design for -50 degrees from surface to 100', 10 degrees through permafrost (approx. 2500'). 8.7 26 8.7 27 9.5 10 9.5 20 Be careful using McOH /H2H for freeze cap - McOH may mix with brine and dilute 8.8 24 8.9 23 10.0 -9 10.0 14 Don't use Ca based fluids that may come in contact with the formation. 8.9 22 9.1 19 10.5 -36 10.5 6 Be careful using CaCI in IA - may dump on formation 9.0 19 9.3 15 10.7 -51 11.0 -2 Corrosion Inhibitor: mix 25 gal of NEEC EC1124 per 100 bbls brine 9.1 17 9.5 15 10.8 -57 11.5 -11 Note: Inhibitor has a 1 day half -life 9.2 14 9.6 33 10.9 -35 11.7 -16 Be careful allowing very cold diesel to contact KCI - could form a slush 9.3 11 11.0 -19 11.8 -19 • 9.4 9 11.5 36 11.9 -10 9.5 6 12.0 6 9.6 3 12.5 50 9.7 -1 12.7 63 9.8 -5 9.9 5 10.0 25 Crystallization Temperatures for Clear Brines i 40 KCI / CaCI # NaCI / } o - 4. - ■ / / NaBr L -20 . __ _ _ ___.. _ \ _ A • - ♦ - NaCI -40 -- - / -fir- CaCI \ •■ . KCI -60 -a-- NaBr r- 8.5 9.5 D•nslty, PPG 10 .5 11 .5 12.5 Casing Summary ADL0312799 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR Length 20" 169# X -56 41 206 TVD Top TVD Base 4260 2590 X -56 LINER 7" 29# L -80 11282 13434 8160 7020 L -80 LINER 4 -1/2" 12.6# L -80 13122 13980 8430 7500 L -80 PRODUCTION 9 -5/8" 53.5# L -80 39 11517 7930 6620 L -80 SURFACE 13 -3/8" 68# L -80 40 3666 5020 2260 L -80 TUBING 4 -1/2" 18.8# L -80 11230 13127 13380 13830 L -80 • TUBING 7" 32# T -95 38 11230 10760 9730 T -95 • • • Packers and SSV's Attachment ADL0312799 Well Facility Type MD Top Description TVD Top NS23 SSSV 2148 7" HES HRQ SSV 1992 NS23 PACKER 11282 7" Baker ZXP Packer 9187 NS23 PACKER 13079 4 -1/2" Baker S -3 Perm Packer 10636 NS23 PACKER 13122 4 -1/2" Baker ZXP Packer 10672 NS23 PACKER 13122 4 -1/2" 18.8# L -80 10672 TREE= ABB -VG! 7" 6. S NOTES: WELL REQUIRES SSSV. ***5 WELLHEAD = ABB -VGI 13 -5/8" MULTIBOWL 6.5 NS23 JOINTS OF 18.8 # /FT 13CR -95 VAM TOP HC ACROSS ACTUATOR = BAKER THE 7" LINER JUST BELOW THE 7" TUBING. *** KB. ELEV = 56.55' BF. ELEV =_ 39.5' (CB 15.8') KOP = 284' Max Angle = 42 @ 10324' Datum MD = 12984' I 2148' 1 1 7" 32# HRQ SV LN , ID = 5.963" OD I Datum TVD = 10500' SS INCALOY -925 P-110 VAM TOP HC 113 -3/8" CSG, 68 #, L -80 BTC, ID = 12.415" H 3666' Minimum ID = 3.260" @ 13113' 4 -1/2" HES RN NIPPLE /N I 11230' 1-17 " X4- 1 /2 "X0,ID= 3.958" I 7" TBG, 32# T -95, VAM TOP HC. ID = 6.094" 11230' (/ (see safety JOINTS 4 -1/2" 13CR � - I ( y note ) 1 1282' H I 11282' 9 -5/8" X 7" BKR ZXP HR LTP, ID = 6.20" TOP OF 7" LNR 11304' I-19-5/8" X 7" BKR FLEX LOCK HGR, ID = 6.20" I � � 9 -5/8" CSG, 53.5 #, L -80 BTM-C -I 11517' I--A ID = 8.535" ' , I 13063' H4-1/2" HES R NIP, ID = 3.437" l 13079' j-17" X 4-1/2" BKR S -3 PERM PKR, ID = 3.56" ' I 13102' H4-1/2" HES R NIP, ID = 3.437" I ' 13113' 1-14 -1/2" HES RN NIP, ID = 3.260" (13097' ELMD) I 4-1/2" TBG, 18.8 #, L -80 VAM TOP HC -I 13127' I- 13122' 1-17" X 5" BKR ZXP LNR TOP PKR, ID = ? .0129 bpf, ID = 3.640" I 1312T I-I4 -1/2" SELF ALIGNING MULESHOE, ID = 3.850" I 5 JOINTS 4 -1/2" 13CR (see safety note) / 13145' 1-1 7" X 5" BKR FLEX LOCK HGR, ID = ? I 7" LNR, 29 #, L -80 HYDRIL 511, 13434' 13154' 1-15" X 4 -1/2" XO, ID = 3.958" I .0383 bpf, ID = 6.184" NOTE: THIS IS 4' ABOVE SAG RIVER PERFORATION SUMMARY REF LOG: LWD on 05/07/03 TIE -IN LOG: GR/CCL on 06/21/03 ANGLE AT TOP PERF: 31 deg @ 13629' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn /Sqz DATE 2 -7/8" 6 13629 - 13869 0 06/25/03 C I PBTD I-J 13938' ELM I 4 -1/2" LNR, 12.6 #, L -80 VAM -ACE -I 13980' v 0.0152 bpf, ID = 3.958" I•••••• DATE REV BY COMMENTS DATE REV BY COMMENTS NORTHSTAR 07/07/03 EMF INIT COMPLETION WELL: NS23 11/07/05 BJM NEW FORMAT & XO DEPTH PERMIT No: 2030500 12/02/05 WRR/TLH RN NIPPLE CORRECTION API No: 50- 029 - 23146 -00 11/27/07 WRR/PJC WELLHD /LOCATION CORRECTIONS SEC 11, T13N, R13E, 1269' FSL & 647' FEL 03/18/09 RCT /SV RN NIP ID CORR (03/05/09) 02/17/11 MB /JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 12, 2011 TO: Jim Regg �7 P.I. Supervisor 7 / ( f 1( SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NS -23 FROM: John Crisp NORTHSTAR UNIT NS -23 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON- CONFIDENTIAL Comm Well Name: NORTHSTAR UNIT NS -23 API Well Number: 50- 029 - 23146 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr110627140521 Permit Number: 203 -050 -0 Inspection Date: 6/26/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NS -23 » T yp e Inj. G 'TVD 10647 • IA J 230 3007 2980 2980 - P.T.Dj 2030500 TypeTest SPT Test psi 2661.75 ' OA 510 745 723 725 Interval P/F P ' Tubing 5028 5029 5029 5030 Notes: 6.8 bbls pumped for test. No problems witnessed. Tuesday, July 12, 2011 Page 1 of 1 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 April 21, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Northstar by !RECENED ~~~a~~010 .laswca Evil ~ f gas t;ot+s. C%a~'m~ssiar ~nchoraoe Dear Mr. Maunder, p~,D~'v~' `~ NS-~3 Enclosed please find a spreadsheet with a list of wells from Northstar that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ~.~.. Date Northstar 4/20/2010 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NS05 2050090 50029232440000 1.7 na 1.7 na 10 4/30/2009 NS06 2021010 50029230880000 0.5 na 0.5 na 1.7 4/30/2009 NS07 2020770 50029230810000 1.1 na 1.1 na 5.3 4/30/2009 NS08 2020210 50029230680000 0.75 na 0.75 na 3.6 4/30/2009 NS09 2012190 50029230520000 1.2 na 1.2 na 3.4 4/30/2009 NS10 2001820 50029229850000 0.25 na 0.25 na 3 4/30/2009 NS11 2060360- 50029233030000 0.75 na 0.75 na 5.1 5/1/2009 NS12 2021100 50029230910000 1.2 na 1.2 na 3.2 5/1/2009 NS13 2010860 50029230170000 1.7 na 1.7 na 6.8 5/1/2009 NS14A 2052020 50029230260100 0.9 na 0.9 na 2.8 5/1/2009 NS16A 2061410 50029230960100 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 50029231130000 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 50029231020000 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 50029231220000 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 50029231180000 1.4 na 1.4 na 8.5 5/2/2009 NS21 2022180 50029231260000 1.7 na 1.7 na 4.3 5/2/2009 NS22 2022230 50029231280000 1.6 na 1.6 na 10.2 5/2/2009 NS23 2030500 50029231460000 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 50029231110000 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 50029231810000 na na 2.6 5/2/2009 NS-26 2002110 50029229960000 at surface na na na na na NS27 2010270 50029230030000 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 50029232480000 1.5 na 1.5 na 8.1 5/3/2009 NS30 2052070 50029232930000 0 na 0 na 4.3 5/3/2009 NS32 2031580 50029231790000 na na 1.7 5/3/2009 NS33A 2081890 50029233250100 Sealed conductor na na na na NS34A 2080170 50029233010100 0 na 0 na 2.2 5/3/2009 'Not measured due to rig proximity. • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 • May 26, 2009 ~'~~ ~~~'~ I~~k ail ~t ~ ~~~~ ~~~~~~~~ion ~~~~r Mr. Tom Maunder ~ ~~,~ Alaska Oil and Gas Conservation Commission ~ .~ ~ 333 West 7t" Avenue ~'"~ ,,~, Anchorage, Alaska 99501 t~~. ~j '' Subject: Corrosion Inhibitor Treatments of Northstar ``~ Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of wells from Northstar that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~ ~~ Andrea Hughes BPXA, Well Integrity Coordinator ~~~~y~. F` r j~f~I BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ~~ "'~\ Date Northstar • 5/26/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NS05 2050090 1.7 na 1.7 na 10 4/30/2009 NS06 2021010 0.5 na 0.5 na 1.7 4/30/2009 NS07 2020770 1.1 na 1.1 na 5.3 4/30/2009 NS08 2020210 0.75 na 0.75 na 3.6 4/30/2009 NS09 2012190 1.2 na 1.2 na 3.4 4/30/2009 NS10 2001820 0.25 na 0.25 na 3 4/30/2009 NS11 2060360 0.75 na 0.75 na 5.1 5/1/2009 NS12 2021100 1.2 na 1.2 na 3.2 5/1/2009 NS13 2010860 1.7 na 1.7 na 6.8 5/1/2009 NS14 A 2052020 0.9 na 0.9 na 2.8 5/1/2009 NS16 2061410 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 1.4 na 1.4 na 8.5 5/2/2009 NS21 2022180 1.7 na 1.7 na 4.3 5/2/2009 NS22 2022230 1.6 na 1.6 na 10.2 5/2/2009 NS23 2030500 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 * na * na 2.6 5/2/2009 NS27 2010270 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 1.5 na 1.5 na 8.1 5!3!2009 NS30 2052070 0 na 0 na 4.3 5/3/2009 NS32 2031580 * na * na 1.7 5/3/2009 NS34 2080170 0 na 0 na 2.2 5/3/2009 *Not measured due to rig proximity. L JUN 0 1 1009 • • _ ..~._ ;~~ °- -~ MICROFILMED 03/01 /2008 DO NOT PLACE ~.._ ~ ,~ ~~; ,.~ ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\C~rPgs_Inserts\Microfilm Marker.doc . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor '/) '~tt1 LblhlO'7 DATE: Monday, August 06,2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) mc NS-23 NORTHST AR lJ"NIT NS-23 FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: <ÇO P.I. Snprv ~~ Comm NON-CONFIDENTIAL Well Name: NORTHSTAR UNIT NS-23 Insp Num: mitLG070729133748 Rei Insp N um: API Well Number: 50-029-23146-00-00 Permit Number: 203-050-0 Inspector Name: Lou Grimaldi Inspection Date: 7/28/2007 Packer Depth i 10636 / !" IA i .,------------,7f'- ! I 2659 ': OA i I I / Tubing ¡ Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I I - ! Well i NS-23 ¡Type Inj. I G ! TVD P.T. I 2030500 TypeTest I SPT : Test psi -- 100 3000 i 29~ 639i~0 i I 4990 I 4990 I I 2990 432 -t---- 630 ~~__. I Interval 4YRTST P/F p 4979 4990 Notes: Good test. No issues. {tldG::r- 'TV!) Cttlc"J;;ëkç 10, Go41' ¡--. . -. {l .L t-rò,v\. d,(!'t'd-l<~1 <;¡,\j' I..H'] 7 Ai0'il- ít' (f?/t+- R PO r+-- of-- 'XW.V'-::¡ ~-2lt ðf('rclt-v!.\t..S S'CANNED AUG 0 8 2007 Monday, August 06, 2007 Page 1 of 1 ~ aõ\..< ~ V~ "- ~ Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, July 20, 2007 2:34 PM To: 'aogcc_prudhoe_bay@admin.state.ak.us' Subject: FW: Northstar MITs due Attachments: Norths~S-23_ TIO_pressures_2007-0720.pdf; Northstar_NS-29_ TIO_pressures_2007-0630.pdf ,,2./Z1t¡ 1 ~ 1Ò ~ 01 . . Based on TIO pressures for NS-29 and NS-23 (attached), I have granted an extension of MITs (dÜe 7/23 aned 7/24, respectively); should expect a call from them rescheduling MITs sometime next week. Jim Regg ~p:?~050 AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: N5U, ADW Well Integrity Engineer [mailto:N5UADWWellIntegrityEngineer@BP.com] Sent: Friday, July 20, 2007 2:22 PM To: Regg, James B (DOA) Cc: N5U, ADW WI Tech; N5U, ADW Well Integrity Engineer Subject: RE: Northstar MITs due Jim, Thank you for understanding our situation. We will schedule the tests with the slope inspectors for after 7/27 but no later than 8/3. I have attached the requested 90-day TIO plot for NS23. Please call with any questions or concerns. Thank you, SCANNED AUG.~ 6 2007 Andrea Hughes From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, July 20, 2007 11:33 AM To: N5U, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: Northstar MITs due Tried calling a couple times this morning; no answer and there was no roll over to voice mail. Spoke with Inspector this morning after he had been contacted about likely delays to Northstar NS-29 (due 7/23) and NS-23 (due 7/24). Understand that there is some wireline work ongoing that is creating the delay since you need the WLU to put TTP in the wells. Understand that there is a possibility that these MITs might be done Monday. That would not work for us since Monday is change-out. Held over a 2nd inspector on the Slope this week to allow us to catch Northstar and other outliers; unfortunately Northstar could not be done because of ops on the Island. 7/20/2007 1. at:; ~ "- v 1. £.. I am not waiving witness of MITs for the~wells, but can give you an extension so th¥an be scheduled sometime between 7/28 and 8/3 when we will again have 2 inspectors available. Please send a 90-day TIO plot for NS-23; I already have that data for NS-29. Call me if you have any questions; please contact Inspectors at 659-2714 to schedule MITs. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 7/20/2007 ~ ...;l-/-t?7 .. STATE OF ALASKA A ALASØ'OIL AND GAS CONSERVATION COMM~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 evation (ft): 56.55KB (. Designation: ADLO-312799 Condition Summary: /~ fitJ 11,I,P1 ~ feet 11420 feet Total Depth measured true vertical Effective Depth 13973 11413 measured true vertical Casing Length 3621' 11474' 132' 858' 1985' 2033' Size 13-318" 68# L-80 9-5/8" 53.5# L-80 7" 26# L-80 4-1/2" 12.6# L-80 7" 29# L-80 7" 29# L-80 Surface Production Liner Liner Liner Liner Perforation depth: Measured depth: 13259 - 13264 True Vertical depth: 10790 - 10794 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. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Contact Robert Younger Printed Name Robert Younger Signature Plug Perforations Perforate New Pool D Perforate D 4. Well Class Before Work: Development D Exploratory Stratigraphic D Service feet feet MD 45' - 3666' 43'-11517' 13302' - 13434' 13122' - 13980' 11317' -13302' 11282' -13315' 7" 32# T-95 4.5" 18.8# L-80 4-1/2" Baker S-3 Perm Packer 4-1/2" Top Packer Stimulate Other../ Acid Wash WaiverD Time ExtensionD Re-enter Suspended Well D 5. Permit to Drill Number: 203-0500 ( D o 6. API Number: 50-029-23146-00-00 / 9. Well Name and Number: NS23 -- 10. Field/Pool(s): Northstar Field/Northstar Oil Pool ' Plugs (measured) none Junk (measured) nonR E C E IVE D N 3 1 2007 TVD 45' - 3190' 43' - 9386' 10842' - 10958' 10686' - 11433' 9226' - 10842' 9198' - 10853' Alaska Q:jL~ Cons. C¡¡OOflÎS4ÌM! 4930lmdwrage 2270 7930 6620 7240 5410 8430 7500 8160 7020 8160 7020 41' - 11230' 11230' -13127' 13076' 13122' SCANNED ß"~ n> ~ Tubing Pressure 4781 4839 Development D Service 0 Representative Daily Average Production or Injection Data Gas-Mcf ..... Water-Bbl Casing Pressure 45825 58456 15. Well Class after work: ExploratoryD 16. Well Status after work: Oil D Gas D WAG D GINJ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. D WDSPL D Title Production Engineer RBDMS BFl .",\,.,,. 'Î#,p~ 564-5392 nn' :'>';n:·;1{it_jf~l¡\j Dr.. -. : - L ~ ij. l? ~I=I i (I 1 20D7 kði\ -01 Submit Original Only Date 1/26/2007 t·~ . ,.." . . NS23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY == 4100/43/277 ***Acid Treatment*** Pumped 5bbls meth, 86bbls 12% DAD 900bbls seawater, 5bbls meth down tubing. Well brought on injection. FWHP's == 1300/7/vac FLUIDS PUMPED BBlS 10 METH 900 SEA WATER 86 12% DAD ACID 996 TOTAL '~ ~1fffi\JŒ ..-¡ -~.. ¡rrL, fE\ n m \~ rY( ~ (,D,) t.' / r \ I L In \ ru ) I h \ /', \ _0 or "0' I,,,,. LJ '-::2 ;'.J \....1 "+__,,- U \.:,¡; U ....1 / t / ! / ¡ / SARAH PALIN, GOVERNOR AI/AS&.& OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Carolyn Kirchner Production Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 SCANNED JAN 1 '1 2007 Re: Northstar Field, Northstar Oil Pool, Well Name: NS23 Sundry Number: 307-004 '-,.-~_.,' .'.... Dear Ms. Kirchner: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~ DATED this J1caay of January, 2007 Enc!. do<3-óS-O ..--, ¡YJ } 1 rmP f STATE OF ALASKA /-n"1?? (ft vr' v A~~~~~~ G:~~~S~~V~~~N ~~~~ð-J~L6Y(J RECEIVED 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Development 0 Stratigraphic 0 .... Abandon U Alter casing D Change approved program 0 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Perforate U Wai~ 0 4 ZOO~ther ld Stimulate D Tir;(l~ E~e~i9~~ Acid Wash AlaSKa un s Con ;", ";" Re-enter Suspended Wel . S. Comml:),>IU;; 5. Permit to Drill ilÆberoge Exploratory 0 203-0500..1 1. Type of Request: Suspend U Repair well D Pull Tubing 0 Anchorage, AK 99519-6612 7. KB Elevation (ft): Service ~ 6. API Number: 50-029-23146-00-00/ 8. Property Designation: 11. Total Depth MD (ft): 13981 Casing Liner Liner Liner Liner Production Surface Perforation Depth MD (ft): 13259 - 13264 ' Packers and SSSV Type: 56.55 KB ¡ 9. Well Name and Number: NS23 II ADLO-312799J 10. Field/Pools(s): Northstar Field Field / Northstar Oil Pool Pool ,/ PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 11419.58 Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 13973 11412.53 None Length Size MD TVD 2033' 7" 29# L -80 11282' 13315' 9198' 10853' 1985' 7" 29# L -80 11317' 13302' 9226' 10842' 858' 4-1/2" 12.6# L-80 13122' 13980' 10686' 11433' 132' 7" 26# L -80 13302' 13434' 10842' 10958' 11474' 9-5/8" 53.5# L-80 43' 11517' 43' 9386' 3621' 13-3/8" 68# L-80 45' 3666' 45' 3190' Perforation Depth TVD (ft): Tubing Size: Tubing Grade: 10790.11 - 10794.46 4.5" 18.8# L-80 7"32# T-95 7" Top Packer 4-1/2" Baker S-3 Perm Packer 4-1/2" Top Packer Packers and SSSV MD (ft): 11282 13079 13122 o 0 13. Well Class after proposed work: Exploratory 0 Developm ent 0 12. Attachments: DescriDtive Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Junk (measured): None Burst 8160 8160 8430 Collapse 7020 7020 7500 7240 5410 7930 6620 4930 2270 Tubing MD (ft): 11230' - 13127' 41 '-11230' Service ~ 15. Well Status after proposed work: Oil 0 Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ ~ WINJ 0 WDSPL 0 Prepé:\II:U uy l:Iâry Preble 5b4-4~44 1/17/2007 Date: Contact Carolyn Kirchner Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name" Carolyn Kirchner Title ACT East PE Signature (OlYÚLt+-. J'tL< v"- rhone 564-4862 t COMMISSION USE ONLY Date 1/3/2007 Conditions of approval; Notify Commission so that a representative may witness Plug Integrity 0 Other: Sundry Number: 3ð7-o0'Ý BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 RBDMS 8Ft JAN 1 (; 20D7 Subsequent Form Required: ~Q~ Approved by: APPROVED BY THE COMMISSION Form 10-403 Revised 11/2004 Date: /-/z"ol' Submit in Duplicate No portion of the belovi"ork should be peñormed w/out fir~aking time to ensure No Accidents, No harm to People, and No damage to the Environment To: Clark Olsen/Jerry Bixby - Well Operations Supervisor December 15, 2006 From: Bob Younger & Carolyn Kirchner - Northstar Production Engineer Subject: NS23 AcidlWater Wash AFE NSFLDWL23 Est. Cost: $50 M lOR: Est 100 BOPD Please perform an acid/xylene treatment with 12% DAD acid on NS23: Type lOR PR N DSWL AFE Job Description Priority Comments/Other o 100 NS23 NSFLDWL23 Pump Acid and Water Current Status: Injector Max Inclination: 41.6° at 10,324' md; 30° at Perfs Max Dog Leg: 6.1 deg/100' at 1,593' md Minimum 10: 3.26" @ 13,113' md, 4.5" RN Nipple w. No-Go Last TO tag: 07/13/03: Tagged TO @ 13,912' SLM Last Downhole Op: 07/13/03: IPROF w. warm back passes from 13,900' - 12,900' md Latest H2S value: None anticipated Recent signs of decreasing injectivity have prompted the need for an acid treatment to help clear any scale that has built up in NS23. Due to success in past years with acid treatments, a 12% DAD Acid wash (includes 20% xylene) is recommended. Procedure 1. Mobilize pumps, tanks and acid transport to Northstar. 2. Order out volume of seawater and methanol. 3. RU pumping equipment. 4. Hold PJSM. 5. Preheat seawater 80°F. The heating of these displacement fluids will eliminate the need to hold backside pressure on the wells during treatment. 6. PT Dowell surface lines to 5000 psi. 7. Pump the following treatment at maximum rate or 3500 psi max pressure. a) 86 bbls 120/0 DAD Acid b) 900 bbls Seawater (To displace acid away from well bore) c) 5 bbls Methanol (spacer between water and gas) C:\Documents and Settings\preblegb\Local Settings\Temporary Internet Files\OLKBC\NS23 Acidizing Procedure 12-15-06.doc Ar ,/ . ! No portion of the below work should be peñormed w/out fir~aking time to ensure No Accidents, No harm to People, and No damage to the Environment 8. Slowly open injection choke. Step the injection pressure from 4000 psi to full injection pressure over a 4 hour period. 9. RD Schlumberger. 10. Two days after well is cleaned up and stabilized, perform a closure test on the SSSV. Fluid descriptions: 80:20 DAD Acid (12% HCL) to contain: 0.60/0 A261 Corrosion Inhibitor 4 ppt A 179 Corrosion Inhibitor 8 ppt A 153 Corrosion Inhibitor 0.50/0 W54 Non-Emulsifier 0.20/0 F103 Surfactant 20 ppt L58 I ron Control 0.5% W60 Anti-sludge 20% Xylene Note: Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. Note: Please have Schlumberger send a digital copy of the post job report (including a digital, ASCII or EXCEL, copy of the pumping rates and pressures) to Robert. Y ounger@ bp.com. Procedure Contacts: Bob Younger WK: 564-5392 HM: 677-2599 Cell: 830-4920 C:\Documents and Settings\preblegb\Local Settings\Temporary Internet Files\OLKBC\NS23 Acidizing Procedure 12-15-06.doc ;),< \ ( '\ d"- . ,Hl/'-- ,,--~.) ,,0,,;'1" '\ DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 Permit to Drill 2030500 Well Name/No. NORTHSTAR UNIT NS-23 Operator BP EXPLORATION (ALASKA) INC >f"} L\..¿ 2 f4,~ ~ :s AP No. 50-029-23{46-00-00 MD 13981 ,...-- TVD 11434 - Completion Date 6/22/2003 Completion Status 1 GINJ Current Status 1 GINJ UIC Y ------ -- - - - --- --- - - ---- REQUIRED INFORMATION Mud log Yes Samples No Directional Survey Yes -~._---------- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, CCl, GYRO, DIR, PWD, RES, NEU, DEN, AIT, DT/BHC, Well Log Information: (data taken from logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No I ; I I I i1:ã9 Cement Evaluation 5 Col Interval OH / Start Stop CH Received Comments ------ - r.»- 1 0520 13350 ð:err 5/12/2003 ! ~b D I fRPt I I£D n ! J.Rpt ~/ 1b9- !4 i i i ED C Lis i W-- C Pds åY".fC Pds A Mud log is required to be submitted. This record automatically created from Permit to Drill Module on: 3/26/2003. Directional Survey Directional Survey DircctiQnal SllrVl'~Y Directional Survey þFfóration ~\Ñ~- 0 13981 Open 6/13/2003 Anadrill 0 13981 Open 6/13/2003 Anadrill 0 139ª:! Ope!L..ßJJ ?/2003.-ßr 0 13981 Open 6/12/2003 BP 5 Blu 11 040 13333 Case 5/28/2003 Perforating Record 4.5" HSD, 12PF, 5' 5 Blu 10340 13212 Case 5/28/2003 Depth Determination, Sample Bailer w/CCl & GR 5 Blu 10340 13212 Case 5/28/2003 Depth Determination, Sample Bailer w/CCl & GR 266 12972 Open 9/29/2003 25 Final 11094 13944 Open 9/29/2003 Vision Density Neutron 25 Final 11 094 13936 Open 9/29/2003 Vision Density Neutron - TVD 25 Blu Final 11094 13944 Open 9/29/2003 Vision Density Neutron 25 Blu Final 11094 13936 Open 9/29/2003 Vision Density Neutron - TVD ---- ------- - - - - - - - Casing collar locator Gamma Ray ¿iJoJ....r '1 ~" fi'h....'{.V--j 'Û~",~, 12097 LIS ,^-, ir.l.ätlorr 12097 ~ron 12097.--Néi.Jtron r log 'hJg ,...Neutron ~utron DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 Permit to Drill 2030500 Well Name/No. NORTHSTAR UNIT NS-23 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23146-00-00 MD 13981 TVD 11434 Completion Date 6/22/2003 49 C Pds 12097 I nd uction/Resistivity ~ C Pds 12097 I nd uction/Resistivity Completion Status 1GINJ 25 Final I nd uction/Resistivity 25 Final 25 Blu Final 25 Blu Final ~ ! Lòg ~/ ~/ !~ ¡ I nd uction/Resistivity ~~rt: Final Well R See Notes Col i i Log i j b"-rlluÀ 5 Col Cement Evaluation ".---- -" Well Cores/Samples Information: Name Interval Start Stop Sent Received ADDITIONAL INFORMATION Well Cored? yQ Chips Received? ,- Y / N Daily History Received? Formation Tops Analysis Received? ~ Comments: Compliance Reviewed By: ~ Current Status 1 GINJ UIC Y ------- -------- --- - 201 13919 Open 9/29/2003 Vision Resistivity Borehole Corrected 201 13908 Open 9/29/2003 Vision Resistivity Borehole Corrected - TVD 201 13919 Open 1/13/2004 Vision Resistivity Borehole Corrected 201 13908 Open 9/29/2003 Vision Resistivity Borehole Corrected - TVD 0 0 10/21/2003 201 13981 Case 1 0/21/2003 Rig Monitoring - in Well History File w/End of Well Report 10520 13350 Case 1/13/2004 Cement Bond Log, USIT/SDL T -------- - Sample Set Number Comments ~/N ~N ------------- --- ------- ---- ----- Date: g ßù"C}- I~~ :F----· I STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 Repair WellD PluQ PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 4. Current Well Class: Development D Exploratory 0 Stimulate Œ] OtherD WaiverD Time ExtensionO Re-enter Suspended WellO 5. Permit to Drill Number: 203-0500 6. API Number 50-029-23146-00-00 56.55 8. Property Designation: ADL-312799 11. Present Well Condition Summary: Stratigraphic D Service ŒJ 9. Well Name and Number: NS23 10. Field/Pool(s): Northstar Field / Northstar Oil Pool Total Depth measured 13981 feet true vertical 11434.0 feet Effective Depth measured 13973 feet true vertical 11426.9 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse Liner 2033 7" 29# L-80 11282 - 13315 9197.6 - 10853.3 8160 7020 Liner 2 7" 26# L-80 11315 - 11317 9224.2 - 9225.8 7240 5410 Li ner 1985 7" 29# L-80 11317 - 13302 9225.8 - 10841.9 8160 7020 Liner 858 4-1/2" 12.6# L-80 13122 - 13980 10686.3 - 11433.1 8430 7500 Liner 132 7" 26# L-80 13302 - 13434 10841.9 - 10958.2 7240 5410 Production 11474 9-5/8" 53.5# L-80 43 - 11517 43.0 - 9386.4 7930 6620 Surface 3621 13-3/8" 68# L-80 45 - 3666 45.0 - 3189.8 4930 2270 Perforation depth: Measured depth: 13259 -13264,13628.5 -13688.5, 13688.5 -13748.5,13748.5 -13808.5,13808.5 -13868.5 True vertical depth: 10804.32 - 10808.68, 11126.2 - 11177.84, 11177.84 - 11229.9, 11229.9 - 11282.26, 11282.26 - 11334.asR E C E IVE D Tubing (size, grade, and measured depth): 7",32#, T-95 @ 41 - 11230 4-1/2" 18.8# L-80 @ 11230 13127 12. Stimulation or cement squeeze summary: Intervals treated (measured): 13259 -13869 Treatment descriptions including volumes used and final pressure: 86 Bbls 12% DAD Acid @ 3700 psig Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure -49.3 0 1016 -43.5 0 180 RiIJß BFl SEP 2 1 2004 Alaska Oil & Gas Cons. Commiss Anchorage SfP 2 1 1ß3~; Packers & SSSV (type & measured depth): 4-112" Baker S-3 Perm Packer 4-1/2" Liner Top Packer 7" Liner Top Packer @ @ @ 13079 13122 11282 13 Prior to well operation: Subsequent to operation: Oil-Bbl o o Tubing Pressure 5065 4841 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: OilD GasD DevelopmentD Service ŒJ Signature Garry Catron Garry Catron iJ~~~ WAG D GINJŒ) WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 304-321 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Production Technical Assistant Form 1 0-404 Revised 4/2004 O~\G\N^l Phone 564-4657 Date 9/16/04 J; ~ (' NS23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/24/04 ACID TREATMENT: PUMP DOWN TBG - 86 BBLS 12% DAD ACID (20% XYLENE), DISPLACED WI 900 BBLS FILTERED SW (85 DEG), FOLLOWED BY 5 BBLS NEAT METH. NOTE: HAD TO SHUT DOWN PUMPING AT 53 BBLS ACID AWAY TO REPAIR LEAK (30 MIN). OPS TO PUT WELL ON INJECTION (4000 - 4400 PSI OVER TWO HOURS). FLUIDS PUMPED BBLS 86 12% DAD Acid (20% Xylene) 900 Sea Water 5 Neat Methonal 991 TOTAL Page 1 ."~ c::.-~ '--'\ ['~'-,:J [-~ ~ II ß\ 1 i ~ Q¿ U-uL ~ f~' r"? ! I' J I L__ ',.:;::) lr ~\ rlL1 ~\ ~~!1 Æ\ IJl:J u\j \..:_~ l_ ~ w d 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 FRANK H. MURKOWSKJ, GOVERNOR A.IIA.~KA. OIL AND GAS CONSERVATION COMMISSION August 20, 2004 Michael Francis BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ~o3~ OS'D Re: Northstar NS23 304-321 Dear Mr. Francis: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM ~~~23rd day following the date of this letter, or the next working day if the 23rd day Ì'/ a holiday or weekend. ( !\)'~ ~_1'"i.!S: Norman Chairman Enclosure '''1'::' bp ;~ .'. ,\~t.'~I. -......~ ~...- ~.,- ~..-- ..~ ~...... .~~~~~\- "~ BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 13,2004 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, AK 99501 RECEIVED AUG 1 72004 Alaska Oil & Gas Cons. Commission Anchorage Dear Winton: Re: Sundry Notice for NS23 to Acidize/Water Wash (Ivishak) BP Exploration Alaska, Inc. proposes to acidize and water wash the NS23 well. /' NS23 injectivity has declined. The acid is designed to attack any solids (pipe / scale, hydrogen sulphide, etc.) that may have accumulated in the perforation tunnels. The water should attack any salt that has accumulated since injection start-up. The procedure includes the following major steps: . Bullhead HCI based acid treatment and displace with water. //' . Return well to gas injection Sincerely, II /J~ Mi~e~~s:~ L-, Senior Petroleum Engineer BPXA, ACT, Northstar ORIGI~IAl- 1. Type of Request: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: \JUGI\- ~{lq I "L004 ( STATE OF ALASKA ( If7j 8'1 /, 19.- ALASKA OIL AND GAS CONSERVATION COMMlsSlo~C:~E'VED APPLICATION FOR SUNDRY APPRCWtt: . 4 20 AAC 25.280 AU G 1 7 100 n ð.It- ~ CommisSiQn Operation Shutdown 0 PerforateD A\aska Oi\ & \IMIWIf~' :L\nnular DisposalD Plug Perforations 0 StimulateOO Time Exfm6~ OtherD Perforate New Pool D Re-enter Suspended WellO 5. Permit to Drill Number: 203-0500 / Suspend 0 Repair Well 0 Pull Tubing 0 4. Current Well Class: BP Exploration (Alaska), Inc. Exploratory 0 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.55 KB 8. Property Designation: ADL-312799 11. Total Depth MD (ft): 13981 Casing Development 0 Length /1 Stratigraphic 0 Service ŒJ 9. Well Name and Number: NS23 / 10. Field/Pool(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 13973 11370.4 Size MD TVD 6. API Number I 50-029-23146-00-00 Total Depth TVD (ft): 11434.0 Junk (md): None Collapse Liner 2033 Liner 2 Liner 1985 Liner 858 Liner 132 Production 11474 Surface 3621 Perforation Depth MD (ft): 13259 - 13264 13629 - 13688.5 13689 - 13748.5 13749 - 13808.5 13809 - 13868.5 Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer 4-1/2" Liner Top Packer 7" Liner Top Packer 12. Attachments: Description Summary of Proposal ŒI Detailed Operations Program 0 Plugs (md): None Burst 7" 29# L-80 7" 26# L-80 7" 29# L-80 4-1/2" 12.6# L-80 7" 26# L-80 9-5/8" 53.5# L-80 13-3/8" 68# L-80 Perforation Depth TVD (ft): 10804.3 10808.7 11126.2 11177.8 11177.8 11229.9 11229.9 11282.3 11282.3 11334.9 tOD bottom tOD bottom 11282 13315 9197.6 10853.3 8160 7020 11315 11317 9224.2 9225.8 7240 5410 11317 13302 9225.8 10841.9 8160 7020 13122 13980 10686.3 11433.1 8430 7500 13302 13434 10841.9 10958.2 7240 5410 43 11517 43.0 9386.4 7930 6620 45 3666 45.0 3189.8 4930 2270 Tubing Size: Tubing Grade: Tubing MD (ft): 4.5 " 18.8 # L-80 11230 13127 7 " 32 # T-95 41 11230 Packers and SSSV MD (ft): 13079 13122 11282 BOP Sketch 0 13. Well Class after proposed work: ExploratoryD DevelopmentD Service ŒI 14. Estimated Date for CommencinQ Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature August30,2004 15. Well Status after proposed work: / Oil D GasO // PluggedO WAG D GINJŒ] WINJ Abandoned 0 WDSPLD Prepared by Garry Catron 564-4657. Date: Title Phone Contact Michael Francis Petroleum Engineer 564-4240 Michael Francis _ ~~ Ð J<~'_r..) ¡',b: . Commission Use Only 8/16/04 Sundry Number: 3D,/.. '3~1 Conditions of approval: Notify Commission so that a representative may witness Other: BOP TestO Mechanciallntegrity Test D Location Clearance D RBDMS Bfl AUG 2 3 100'~ BY ORDER OF rL i Ú/ THE COMMISSION Date: 'l_'Z.ð IJ 7 n R \ G , t\l A L_ SUBMIT IN DU LlCATE TREE: ABB-VGI 7" 6.5ksi .' WELLHEAD: ABB-VGI 13-5/8,,·1 Multibowl 6.5ksi NS23 13 3/8", 68#/ft, L-80, BTC @ 3666' MD ..4 7", 32#/ft, T -95, Vam Top HC Tubing 106.094" .. Tubing Drift 5.969" Capacity: 0.0361 bbllft 4 Joints of 4-1/2" 18.8#/ft 13CR-95 Vam Top HC across the 7" liner top and between the 7" T-95 and 4-1/2" L-80 tubing ~ ¿. 9-5/8" 53.5# L-80 BTM-C @ 11517' MD 4.5" R NIPPLE (3.437" 10) ,18.8# 9CR-80 wI Vam Top HC @ 13063' MD ~ 4.5" R NIPPLE (3.437" 10) ,18.8# 9CR-80 w/Vam Top HC @ 13102' MD 4.5" RN NIPPLE, (3.265" No-Go) -------: 18.8# 9CR-80 ~ w/ Vam Top HC@ 13113' MD 7", 29#/ft L-80, Hydril 511 @ 13434' MD Note; This is 4' above Sag River. if PERFORA TION SUMMARY REF LOG: LWD (5/7/03) [Tie-in Log:GRlCCL (6/21/2003)] ANGLEATTOPPERF: Note: Refer to Production DB for historical perf data Initial Perf - Charge: 2906 Power Jet, HMX; Penetration: 27"; Hole: .36"; A1ase:60 deg SIZE SFf INTERV AL MD INTERV AL lVD Opn/Sqz DA TE 2.875 6 13629'-13869' 11126'-11335' Opn 6/25/2003 PBTO @ 13973' MO TO @ 13980' MD L OATE 3/21/03 7/7/03 REV. BY FH EMF COMMENTS ~S23 Proposed Add Perfs ~ ( 'RIGINAL KB. ELEV = 55.3' IŒ-BF. ELEV = 39.5' BF ELEV = 15.8' 7",32# HRQ SVLN @ 2148' MD (Incaloy-925 P-110 Vam Top HC) 5.963" 10 6.8PPG DIESEL FREEZE PROTECTION AT +/- 4022' TVD (4726'MD) ~ ,/ ~ - 7" LINER TOP @ 11282' MD 4 1/2",18.8#/ft; L-80 Vam Top HC ......- TUBING 10: 3.640" Tubing Drift: 3.515" . CAPACITY: 0.0129 bbllft -;;- - 7" PACKER, @ 13079' MO, 10650'TVD .- 4.5" 12.6# (3.958" ID)13CR-80 WLEG, @ 13124' MO ~------- E 4.5" LINER TOP @ 13122' MO ... o E-Line PBTO 13938' 1 4.5" 12.6#, L-80 Vam Ace Northstar WEL~ : NS23 API NO: 50-029-23146-00 BP Exploration (Alaska) ö Date: 01-09-2004 Transmittal Number:92634 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data is being sent separate because of the confidential nature. If you have any questions, please contact me in the PDC at 564-4091 BJ3 "'153 NS32 '9.Q3-'C£D NS23 )o)-f91 NS27 12-02-2003 SCH Log Run Top Depth Bottom Depth Log Type ULTRA SONIC IMAGING 1 500 3858 TOOL; SW Name Date Contractor 05-06-2003 SCH 10520 13350 CEMENT BOND LOG; 12-01-2003 SCH 1 9996 11107 MEMORY COLLAR LOG; ......<:::- .... c---.. ··~l~i~~\)\..C' ~"CN'~ Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Ken Lemley MB3-6 Attn: Ester Fueg MB3-6 Attn: Jason Smith (Murphy Exploration) Attn: Howard Okland (AOGCC) Attn: Kristin Dirks (DNR) Attn: Doug Choromanski (MMS) RECEIV'ED J.\N 1 3 2004 AJaska Oil & Gas CAns. Comrnilion Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 C)CJ3 -oEð bp , Date: 01-09-2004 Transmittal Number:92634 J " ~q7 f" BPXA WELL DATA TRANSMITTAL Please replace the MWD data delivered to you previously with this set of data. There was a depth shift change so new data had to be printed, sorry for any inconvenient this may have caused. This data is being sent separate because of the confidential nature. If you have any questions, please contact me in the PDC at 564-4091 ..... --~~.J'~ ~~ \.Q (J)¿ ~A') Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Ken Lemley MB3-6 Attn: Ester Fueg MB3-6 Attn: Jason Smith (Murphy Exploration) Attn: Howard Okland (AOGCC) Attn: Kristin Dirks (DNR) Attn: Doug Choromanski (MMS) RECEIVED ~.\N 13 2a04 Alaska Oil & Gas CAms. CorIuJ1Iion An,.. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 bp Date: 10-20-2003 Transmittal Number:92626 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailingtojohnsojh@bp.com Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type ¿ø-)/D NS12 06-07 -2002 SPERRY 1 201 3647 MUD LOG; END OF WELL REPORT; r NS16 06-28-2002 SPERRY 1-4 201 12424 MUD LOG; END OF WELL REPORT; &cB-jd fl0!9-1ld'l NS17 08-24-2002 SPERRY 1-6 201 18396 MUD LOG; END OF WELL REPORT; SPERRY 201 14063 MUD LOG; END OF WELL REPORT; t)ŒtâêS1 NS 19 10-29-2002 1-4 ~-)&3' NS20 09-26-2002 SPERRY 1-5 201 18531 MUD LOG; END OF WELL REPORT; ()D NS23 03-31-2003 SPERRY 1-5 201 13981 MUD LOG; END OF WELL REPORT; 903-0- ._.~~~\~~~~~~ Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center RECEIVE:]) OCT 2 '1 2003 Ale~kav¡'; ft GH~ ({Inc. <.;(¡mm¡8~ion l\n~hor~.~8 Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Howard Okland (AOGCC) Attn: Jason Smith (Murphy I;xploration Alaska), Inc Attn: Kristin (DNR) Attn: Doug Choromanski (MMS) Petrotechnical Data Center LR2-] 900 E. Benson Blvd. PO Box] 96612 Anchorage, AK 995] 9-66] 2 ~~~\\\~ bp Date: 09-26-2003 Transmittal Number:92619 RECEIVED BPXA WELL DATA TRAN'§M1'i~l)l Aluk8 O¡-; 6. 1.Ji',1;j ~OI1S. commiMlion Anchof8ge Enclosed are the materials listed below. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailingtojohnsojh@bp.com Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type N06 05-19~2002 SCH 1-6 266 13857 VISION RESISTIVITY BOREHOLE CORRECTED LOG; MEASURED DEPTH; COMPOSITE FINAL PRINT; N06 05-19-2002 SCH 1-6 266 13857 VISION RESISTIVITY BOREHOLE rf/\D\ CORRECTED LOG; TRUE VERTICAL DEPTH LOG; COMPOSITE FINAL PRINT; N06 05-19-2002 SCH 1-6 266 13857 VISION DENSITY NEUTRON; TRUE 9 VERTICAL DEPTH LOG; COMPOSITE FINAL PRINT; N06 05-19~2002 SCH 1-6 266 13857 VISION DENSITY NEUTRON; MEASURED DEPTH LOG; COMPOSITE FINAL PRI~T!... NS23 04-02~2003 SCH 1-6 270 13944 VISION DENSITY NEUTRON; ...-:>- TRUE VERTICAL DEPTH LOG; rß-J.JS23 04-02~2003 SCH 1-6 270 13944 VISION DENSITY NEUTRON; &rß NS23 MEASURED DEPTH LOG; 04-02-2003 SCH 1-6 270 13944 VISION RESISTIVITY BOREHOLE CORRECTED LOG; MEASURED DEPTH; COMPOSITE FINAL PRINT; NS23 04-02-2003 SCH 1 ~6 270 13944 VISION RESISTIVITY BOREHOLE CORRECTED LOG; TRUE VERTICAL DEPTH LOG; COMPOSITE FINAL PRINT; N06 05-19-2002 SCH 1-6 266 13857 LDWG DATA; CD ROM 1EA; . ?( 1!)D9,- NS23 05-10-2003 SCH 1-6 266.5 12972 LDWG DATA; CD ROM 1E ; JéJ0C¡1 RECEIVED SEP 29 2003 Alaska Oii & Gas Cons. Comm_n Ancnørsge Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 K~~\~\~ BPXA WELL DATA TRANSMITTAL ~n\~ ~<...0 h¿~e~ Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Howard Okland (AOGCC) Attn: Jason Smith (Murphy Exploration Alaska), Inc Attn: Kristin (DNR) Attn: Doug Choromanski (MMS) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Date: 09-26-2003 Transmittal Number:92619 S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner DATE: July 24, 2003 r; '\/10\\J·:§UBJECT: Mechanical Integrity Tests THRU: Jim Regg \~úl~i 1 I- '- BPX P.I. Supervisor l \. Northstar Northstar 23 FROM: John Crisp Petroleum Inspector Northstar NON· CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well NS 23 Type Inj. N TV.D. 10650 Tubing 4028 3999 3997 3992 Interval P.T.D. 2030500 Type test P Test psi 3000 Casing 0 3000 2954 2920 P/F Notes: OA pressure 0 thru out test. Well shut in for MIT. Well is gas injector. 8 bbl's pumped for test. Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well P.T.D. Notes: Well P.TD. Notes: Well P.TD. Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING I f Type Inj. Type test T.V.D. Test psi Tubing Casing Interval P/F Type Inj. Type test TV.D. Test psi Tubing Casing Interval P/F Type Inj. Type test TV.D. T est psi Tubing Casing Interval P/F Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details I travelled to BP's Northstar Island to witness the initial post injection MIT on NS 23. The Island experienced an EMS the night before my arrival to witness the MIT. Production & Injection was being brought back on slowly. I requested to witness the MIT on 23 while the well was shut in. No problems witnessed. M.I.T.'s performed: 1 Attachments: Number of Failures: º Total Time during tests: 8 hrs. cc: M IT report form 5/12/00 L.G. MIT Northstar 07-24-03 JC1.xls 7/28/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. NS/ NS/NS 07/24/03 Roland Johnson John Crisp Packer Depth (TVD-ft.) Well NS-23 Type Inj. G TVD 10,650' Tubing PTD. 203-050 Type test P Test psi 2662.5 Casing Notes: Initial AOGCC Witnessed MITIA - Post injection startup. Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test MIT Report Form Revised: 06/19/02 Pretest 4,028 o 2003-0724_MIT _Northstar _NS-23.xls Initial 3,999 3,000 15 Min. 30 Min. 3,997 3,992 2,954 2,920 Interva P/F I P Interva P/F Interva P/F Interva P/F Interva P/F INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) 1. Status of Well o Oil 0 Gas 0 Suspended 0 Abandoned !HI Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1269' NSL, 647' WEL, SEC. 11, T13N, R13E, UM At top of productive interval 2647' NSL, 4187' WEL, SEC. 02, T13N R13E, UM X = 656138, Y = 6037622 10. Well Number At total depth 2775' NSL, 4279' WEL, SEC. 02, T13N, R13E, UM X = 656044, Y = 6037748 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Northstar Unit KBE = 56.55' ADL312799 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 4/2/2003 5/9/2003 6/22/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 13981 11434 FT 13973 11427 FT !HI Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, CCL, GYRO, DIR, PWD, RES, NEU, DEN, AIT, DT / BHC, CNL, LDL, CALIPER, SP, MRES CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 2061 20" 45' 36661 16" 43' 11517' 12-1/4" 112821 13434' 8-1/2" 13122' 13980' 6-1/8" '~ 23. CASING SIZE WT. PER FT. 169# 68# 53.5# 29" 12.6# 20" 13-3/8" 9-5/8" 7" 4-1/2" { STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well Gas Injection 7. Permit Number 203-050 8. API Number 50- 029-23146-00 9. Unit or Lease Name X = 659826, Y = 6031042 Northstar Unit NS23i 15. Water depth, if offshore 16. No. of Completions 39' MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2148' MD 1545' (Approx.) GRADE X-56 L-80 L-80 L-80 L-80 CEMENTING RECORD Driven 606 sx PF ILl, 492 sx Class 'GI 630 sx Econolite, 700 Class 'G' 315 sx Class IGI 120 sx Class 'GI AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-7/8" Gun Diameter, 6 SPF MD TVD MD TVD Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SUbR.~CE. No core samples were taken. r¿:iDj~jiTE:::~:Ú!:"c;: R8DMs " ' 9 1 "200'3 J VA IE'; B¡:-I. J U L to);'· ' i.1 ~~.F.D ,'1,1 ~,é - JUL R ¿\.2nMJ\\ ~ ,._~..¿ '! p" cfltlJ' ""","",""T'M<;>I'~""'O\,} 13629' - 13869' 11127' - 11335' 27. Date First Production July 4,2003 Date of Test Hours Tested Form 10-407 Rev. 07-01-80 25. TUBING RECORD DEPTH SET (MD) 11211' 11211' - 13127' SIZE 7",32#, T-95 HS 4-1/2", 18.8# /12.6#,T-95/9CR/13CR80 PACKER SET (MD) 13079' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4726' Freeze Protected with 280 Bbls of Diesel. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Injection, Shut-In PRODUCTION FOR Oll-BBl GAs-McF WATER-BBl TEST PERIOD CHOKE SIZE GAS-Oil RATIO Oll-BBl GAs-McF WATER-BBl Oil GRAVITy-API (CORR) ü R (51 NAL Submit In Duplicate Summary of Daily Drilling Reports, Surveys, Post Rig Summary Report and a Leak-Off Test Summary. / ·/t i. " ' ue an, rrect to thp.best.,of my knowledge ,~ ~.)} / ~ II Title Drilling Engineer 203-050 .. " t .\ 29. Geologic Markers Marker Name Measured Depth Top of Ugnu 5682' Top of Schrader Bluff 7730' Top of Kuparuk 10915' Kuparuk 'C 11074' Top of Miluveach 11488' Top of Kingak 12120' Top of Sag River 13438' Top of Shublik 13553' 'Top of Ivishak 13660' 31. List of Attachments: 32. I hereby certify that th Signed 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 4785' 6378' 8903' 9030' 9363' 9878' 10962' 11 062' 11153' JI JL ~;p t. ¿,I Date 7/ZI ~0 Prepared By Name/Number: soka ;te'Lan~564-4750 Drilling Engineer: Allen Sherriff, 564-5204 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. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 28: If no cores taken, indicate 'none'. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 ORIGINAL ,( \ ( BP EXPLORATION Operations Summary Report Page 1 of 32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From - To Hours Task Code NPT Phase Description of Operations 3/31/2003 19:30 - 20:00 0.50 MOB P PRE Move rig South 10 feet from NS19 to remove well house from NS22. 20:00 - 20:45 0.75 MOB P PRE Pick well house off NS22. 20:45 - 21 :45 1.00 MOB P PRE Set wellhead equipment around NS23. Set herculite and mats. 21:45 - 00:00 2.25 MOB P PRE Move rig to the North (NS23). 4/1/2003 00:00 - 02:00 2.00 MOB P PRE Continue move to NS23. "''''''''''ACCEPT RIG @ 00:00 hrs on 4-1-03"''''''' Note: (Rig move accept time compensated for move back and NS22 well house removal). 02:00 - 03:00 1.00 MOB P PRE Level up rig. 03:00 - 05:30 2.50 RIGU P PRE Rig Up. - Close in cellar. - Berm rig. - Position walkways and stairs. - Leveling walking areas in sub structure around wells. 05:30 - 06:30 1.00 RIGU P PRE NU surface riser. 06:30 - 07:30 1.00 RIGU N MISC PRE Identifed down scoping riser is too short to reach adapter receptor. - Pull riser and place in pipeshed. 07:30 - 14:45 7.25 RIGU N MISC PRE Decision made on new plan foward for NU surface riser. - PJSM -- Non Routine Operation/HACL - Spot in cellar and NU lower risers. - Measure and cut off 7" of surface riser. - NU surface riser. 14:45 - 15:00 0.25 RIGU P PRE Fill & test riser with sea water. 15:00 - 15:30 0.50 RIGU P PRE PJSM. - Install mouse hole and iron roughneck track. 15:30 - 16:00 0.50 RIGU P PRE Move wireline sheaves to floor. 16:00 -18:15 2.25 DRILL P SURF PJSM for rigging up for GYRO. - Rig up SWS wirline and GYRODATA tools. 18: 15 - 18:45 0.50 DRILL P SURF RIH wI 1 std of 5" DP and tag ice at 52' in surface conductor. 18:45 - 20:30 1.75 DRILL P SURF PJSM. -PU Motor and 16" bit for clean out of conductor from 52' to 121' md (Allowing room to PU HWDP and stand back in derrick). 20:30 - 21 :00 0.50 DRILL P SURF POOH. 21 :00 - 22:45 1.75 DRILL P SURF PJSM. - MU 24 jts HWDP & stand back in derrick. 22:45 - 00:00 1.25 DRILL P SURF PJSM for MU of BHA #1. BHA #1 consists of the following: -16" Hughes MX-C1 (3x20 & 1x12 Jets), - 9-5/8" PDM-1.83 deg, - Orienting Sub, NM Stab, 2x Monel LC, NM Stab 4/2/2003 00:00 - 01 :00 1.00 DRILL P SURF Continue MU BHA#1 01 :00 - 02:00 1.00 DRILL P SURF Hold Pre-Spud Meeting Notes: 1. Notify Control Room to shut in NS-24 @ SSSV for downhole Printed: 6/16/2003 2:08:44 PM ( f BP EXPLORATION Operations Summary Report Page 2 of 32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/2/2003 01 :00 - 02:00 1.00 DRILL P SURF close approach. 2. Conduct D7 Drill -- Shallow Gas without Diverter Drill 02:00 - 02:15 0.25 DRILL P SURF Clean out conductor. Note: Conductor oriented in favorable direction 0.71 inclination & 305 azimuth @ 206' md. 02: 15 - 04:00 1.75 DRILL P SURF Drlg f/ 230' - 329' md. Gryo @ 327' md. 04:00 - 04:30 0.50 DRILL P SURF LD BHA#1. 04:30 - 07:00 2.50 DRILL P SURF MU BHA#2 and RIH to 280' md. 07:00 - 07:15 0.25 DRILL P SURF Wash f/ 280' - 329' md -- circulate red mud sweep. 07:15 - 16:45 9.50 DRILL P SURF Drill Ahead 16" surface hole from 329' - 999' md. - Gyro survey on each connection Surveys: MD (') Sur Depth (') Inclination (deg) Azi (deg) 456 356 1.11 271.97 547 447 1.99 283.74 637 537 4.26 280.09 728 627 5.93 280.55 819 717 6.08 283.62 908 808 6.81 285.38 999 899 9.70 284.27 Each slide indicating build in inclination- no directional response. 16:45 - 19:00 2.25 DRILL N HMAN SURF Run new GYRO tool for confirmation. At 999' md (903.8' survey depth): 9.47 incl & 282.14 Azimuth. Note: DD cannot go further without breaking hardlines at 1100-1400' and 1700- 2100' md. 19:00 - 20:30 1.50 DRILL N HMAN SURF POOH to check for tool problem or reason for lost orientation. - At surface find orientation 50 deg off. 20:30 - 21 :30 1.00 DRILL N HMAN SURF RIH w/ BHA#2 and check torque on connections. - Found Handling Sub on the bottom of MWD without proper torque. - Shipping instructions indicated that this connection was not torque. - Standard practice is that Anadrill paint stencils labels "loose" on all connections that require rig to torque up. Note: Confer with Anchorage Engineering on plan foward and decision made to open hole side track at 500' md. 21 :30 - 22:00 0.50 DRILL N HMAN SURF Torqued connection to 48K ft-Ibs. RIH to 460' md. 22:00 - 22:45 0.75 DRILL N HMAN SURF Run Gyro Survey. - At 357.8' survey md, 0.93 degs inclination & 284.73 Azi w/ 167 deg TF. 22:45 - 23:30 0.75 DRILL N HMAN SURF Orient tool face to low side and trench from 460' to 500' md w/ 140 TF. 23:30 - 00:00 0.50 DRILL N HMAN SURF Time drill from 500' to 503' md. 4/3/2003 00:00 - 03:00 3.00 DRILL N HMAN SURF Time drill from 503' - 520' md. 03:00 - 08:00 5.00 DRILL N HMAN SURF Drlg f/ 520' - 818' md -- Gryro each connection. 08:00 - 10:30 2.50 DRILL N RREP SURF Trouble Shoot Top Drive -- Unable to operate breakout wrench. Note: Bad output relay module -- critical spare was defective. Printed: 6/16/2003 2:08:44 PM (" (' BP EXPLORATION Operations Summary Report Page 3 of 32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/3/2003 10:30 - 11 :30 1.00 DRILL N HMAN SURF Blow down top drive, Run Gyro, make connection and attempt to slide -- unable to set top drive brake. 11 :30 - 12:30 1.00 DRILL N RREP SURF Troubleshoot and repair TD brake. 12:30 - 13:00 0.50 DRILL N HMAN SURF Slide from 818' to 999' md. 13:00 - 00:00 11.00 DRILL P SURF Drill ahead 16" surface hole f/ 999' to 1856' md. - Avg ROP rotating is 518 fph - Avg ROP sliding is 126 fph. - Gyro survey every other stand. Drilling parameters: - WOB from 8 K to 25 K Ibs - Total Flow 800 to 900 gpm w/ 2200 psig SPPon. - Rotating 40 rpm w/ 7000 ft-Ibs torque. 4/4/2003 00:00 - 01 :00 1.00 DRILL P SURF Drlg f/ 1856' to 2045' md. 01 :00 - 01 :30 0.50 DRILL P SURF Circ Red Mud Sweep. 01:30-02:15 0.75 DRILL P SURF Gyro Survey on Wireline. 02:15 -14:00 11.75 DRILL P SURF Drlg f/ 2045' to 3686' md. 14:00 - 15:45 1.75 DRILL P SURF Circ and Cond Mud for running casing -- monitor well. 15:45 - 16:15 0.50 DRILL P SURF TOH 5 Stands. Note: Pump dry job and blow down lines. 16:15 - 18:00 1.75 DRILL P SURF TOH to 400' md (above OH sidetrack pt). 18:00 - 19:00 1.00 DRILL P SURF Orient TF to 140 and TIH to 1100' md. - Smooth hole no drag. - No trouble with BHA going into sidetrack. 19:00 - 20:00 1.00 DRILL P SURF TOH to DC's. 20:00 - 22:30 2.50 DRILL P SURF Rack back DC's. LD BHA#2. - Stab's have normal clay buildup. - Bit in good shape (Graded: 1-1- WT-A-E-I-PN-TD) 22:30 - 00:00 1.50 CASE P SURF PU Landing Jt and hanger. -Drift riser due earlier modification. 4/5/2003 00:00 - 01 :30 1.50 CASE P SURF PJSM -- RU Surface Casing Equipment & Franks Tool. 01 :30 - 11 :00 9.50 CASE P SURF RIH with 88 jts of 13-3/8" 68# L80 Btrc Casing. 11 :00 - 13:00 2.00 CASE P SURF Circulate and Condition for Cement Job: Note: Held Pre-Tour, Crew Change, PJSM for Cement Job and HES Preparation for job. 13:00 - 13:30 0.50 CEMT P SURF Pump 5 bbls SW and test lines to 3000 psi. Pump 75 bbls of Alpha Spacer @ 10.4 ppg. Drop Bottom Plug. 13:30 - 15:00 1.50 CEMT P SURF Mix and Pump 450 bbls of 10.7 ppg Lead Cement. 15:00 - 15:30 0.50 CEMT P SURF Mix and Pump 100 bbls of 15.9 ppg Tail Cement. 15:30 - 16:30 1.00 CEMT P SURF Drop Top Plug and Displace cement with 538 bbls. Notes: - Final 30 bbls pumped were SW to aid RD csg running equip. - Circulated -150 bbls of cement to surface. - Bumped plug with 2450 psi (500 psi above FCP) - Rig pumps @ 94.3 % efficiency. - HES meter @ 90.1 % efficiency. 16:30 - 17:30 1.00 CEMT P SURF Rig down cement head, spiders, & LD jt. Blow down all lines. 17:30 - 19:00 1.50 CEMT P SURF Clear floor off casing running tools and clean drip pan. 19:00 - 20:00 1.00 CEMT P SURF PJSM. Rig down turnbuckles, riser, and mousehole. Printed: 6/16/2003 2:08:44 PM ( { BP EXPLORATION Operations Summary Report Page 4 of 32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/5/2003 20:00 - 20:30 0.50 CEMT P SURF LD casing bails. PU drilling bails. Install master bushings. - Operations SI Wells NS22 and NS 24 for heavy lift. 20:30 - 22:30 2.00 CEMT P SURF PJSM for ND lower riser sections. - ND lower riser sections and relocate them in cellar at well slot NS25. 22:30 - 00:00 1.50 CEMT P SURF PJSM for NU ABB Vetco Grey Multibowl WHo - NU WH and test to 5000 psig. - NU Drilling sweep on annulus. 4/6/2003 00:00 - 00:30 0.50 CEMT P SURF Set test plug in tubing spool. Note: Obtain permits for heavy lift. 00:30 - 03:00 2.50 CEMT P SURF NU BOPE. Note: Set clock forward one hour for DLS Time -- Lost one hour -- 1.5 hour task and 23 hour day for 4/6/03. 03:00 - 05:30 2.50 CEMT P SURF Finish NU BOPE. 05:30 - 06:00 0.50 CEMT P SURF RU testing equipment and fill stack. 06:00 - 10:00 4.00 CEMT P SURF Test BOPE -- 250/4800 psi 5 minutes per test. Note: AOGCC Field Inspector Chuck Sheve waived witness for test @ 2000 hrs on 4/4/03. 10:00-11:00 1.00 CEMT P SURF RD Test Equipment and Blow Down Lines. 11:00-11:30 0.50 CEMT P SURF Pull Test Plug and Install Wear Ring. Note: Adjust IBOP and clean rig floor. 11 :30 - 12:00 0.50 CEMT C SURF Hold Pre-Tour Meeting with Day Tour crew while Morning Tour Crew eats lunch in prepartion for back logic class. 12:00 - 14:00 2.00 CEMT C SURF Held Back Logic Training with both crews. 14:00 - 17:00 3.00 CEMT P SURF MU BHA#3 & Surface test Rotary Steerable and MWD tools. 17:00 - 18:00 1.00 CEMT N DFAL SURF Failed DWOB on MWD tool. LD and PU spare tool from pipe shed and surface test -- program error. 18:00 -18:30 0.50 CEMT N DFAL SURF Break Connection on floor and reprogram MWD tool while BHA is in rotary. Test after reprograming is good. 18:30 - 20:00 1.50 CEMT P SURF Continue MU BHA#3 to Jars. RIH w/ HWDP. MU 12-1/4" Weatherford Ghost Reamer 998' md behind bit. MU dart valve sub. 20:00 - 21 :30 1.50 CEMT P SURF RIH w/ BHA#3 on 5" DP to 3579' md. Wash down last stand. 21 :30 - 22:30 1.00 CEMT P SURF PJSM. SI pipe rams and pressure test casing to 3500 psig for 30 mins. - 6.95 bbls to pressure up. - Bleed oft and blow down Top Drive. 22:30 - 00:00 1.50 CEMT P SURF PJSM. Slip and cut drilling line. 4/7/2003 00:00 - 00:30 0.50 CEMT P SURF Finish Slip and Cut drilling line. 00:30 - 02:00 1.50 CEMT P SURF Service top drive and drawworks. 02:00 - 02:15 0.25 CEMT P SURF Pump 100 bbls hi-vis pill followed by new 8.7 ppg drilling fluid. 02:15 - 04:30 2.25 CEMT P SURF Drill Float track and rathole while displacing well to new 8.7 ppg drilling fluid. 04:30 - 04:45 0.25 CEMT P SURF Drill 20' of new fm to 3708' md. 04:45 - 05:00 0.25 CEMT P SURF Perform FIT to 12.5 ppg EMW (633 psi with 8.7 ppg fluid). Bleed down kill line. 05:00 - 12:00 7.00 DRILL P INT1 Drilling f/ 3708' - 4777' md with RSS tool. RSS tool responding well to downlinks. 12:00 - 00:00 12.00 DRILL P INT1 Drilling f/ 4777' - 6474' md with RSS tool. RSS tool responding well to downlinks. Printed: 6/16/2003 2:08:44 PM ( t BP EXPLORATION Operations Summary Report Page 5 of 32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/8/2003 00:00 - 12:00 12.00 DRILL P INT1 Drilling ahead 12-1/4" Intermediate hole f/ 6474' - 7601' md. 12:00 - 19:30 7.50 DRILL P INT1 Drill 12-1/4" f/ 7601' - 8349' md. 19:30 - 20:00 0.50 DRILL N RREP INT1 Attempt to shim Top Drive IBOP Actuator Roller Assembly. 20:00 - 22:00 2.00 DRILL P INT1 Drill ahead 12-1/4" from 8349' - 8629' md. 22:00 - 22:45 0.75 DRILL N RREP INT1 Troubleshoot Top Drive. Notes: - Clicking sound coming from upper bearing area and not the gear box. * Clicing sound rate increased proprotionally to rpm speed. - NAD Slope Mechanic due to rig this am to troubleshoot. - Suspect upper bearing. 22:45 - 00:00 1.25 DRILL N RREP INT1 Pump sweep in preparation to POOH to Shoe to further evaluate top drive problem. Note: Added Aldecide to mud system. 4/9/2003 00:00 - 01 :00 1.00 DRILL N RREP INT1 Continue circulating and conditioning mud for trip to shoe. - Add Aldicide Treatment. 01 :00 - 01 :30 0.50 DRILL N RREP INT1 Monitor well and pull 3 stds to 8163' md. - PU WT= 280 K Ibs & SOW= 185 K Ibs. - Pump dry job blow down lines. - Blow down lines. 01:30 - 02:15 0.75 DRILL N RREP INT1 POOH from 8163' to 8069' md. - Hole tight and swabbing. 02:15 - 03:30 1.25 DRILL N RREP INT1 Back ream from 8069' to 7600' md. - Back ream w/ 15 rpm and w/ 45 spm. - Quit back ream at 7600' md- Depth where GHOST REAMER had reamed to. 03:30 - 06: 15 2.75 DRILL N RREP INT1 Monitor well. POOH from 7600' to 3648' md (into 13-3/8" shoe). 06:15 - 06:30 0.25 DRILL N RREP INT1 Monitor well at shoe. 06:30 - 10:45 4.25 DRILL N RREP INT1 Troubleshoot Top Drive. - Mike Carr w/ Nabors out to troubleshoot Top Drive. - Top Drive has broken Pinion Gear. 10:45 - 12:00 1.25 DRILL N RREP INT1 Move 72 stands of DP from the off drillers side to drillers side of pipe rack. 12:00 - 16:00 4.00 DRILL N RREP INT1 PJSM. Clear out space for parts storage on rig floor. - Remove saver sub & pipe handler. - Remove lower and upper safety valves. - Remove link assembly and torque arrestor. 16:00 - 19:00 3.00 DRILL N RREP INT1 PJSM. - Remove blower hoses and extend counter balances. - Seperate the top drive from swivel and pull quill shaft out of top drive. - Hook up slings to remove motor. Swing open top drive exposing motor for removal. NOTE: Hold initial ATP meeting with On Site Safety, Mike Carr- NAD Master Mechanic, Steve Edwards- Quadco, Night and Day TP's, Night and Day Wellsite leaders, AIC crane operator, and MTT. 19:00 - 23:00 4.00 DRILL N RREP INT1 PJSM. - Disconnect the hyraulic service loop. - Remove blower motor and duct. Printed: 6/16/2003 2:08:44 PM ( ( BP EXPLORATION Operations Summary Report Page 6 of 32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/9/2003 19:00 - 23:00 4.00 DRILL N RREP INT1 - Remove compensator valve assembly. - Remove wiring for traction and blower motors. - Rig up slings to remove top drive motor. 23:00 - 00:00 1.00 DRILL N RREP INT1 PJSM. - Work on removing mounting bolts for traction motor. 4/10/2003 00:00 - 07:00 7.00 DRILL N RREP INT1 PJSM. Remove TD traction motor from cradle and set down on rig floor. 07:00 - 08:30 1.50 DRILL N RREP INT1 Remove brake assembly and electrical equipment from motor. 08:30 - 09:30 1.00 DRILL N RREP INT1 PJSM. Move and set motor on VLE cart. 09:30 - 10:30 1.00 DRILL N RREP INT1 Steam clean TD. Spot new motor on ground by VLE. Gather up AIC crane crew. 10:30 - 12:00 1.50 DRILL N RREP INT1 PJSM. Conduct Mini ATP Meeting with all parties involved with crane picks. Set old motor down on ground. PU new motor to floor. 12:00 - 17:00 5.00 DRILL N RREP INT1 PJSM. Position TD motor near rotary table. Install heaters & attach lugs to power cables. Tuboscope MPI Quill Pin & Splines.. ok. Install Blower motor to blower assembly. Circulate hole 6000 strokes--mud in good condition-- circulated out dry jobs. Turn on centrifuge. 17:00 - 19:30 2.50 DRILL N RREP INT1 Continue work on TD. PJSM for picking up TD motor and placing into bolt up position. PU motor into position. 19:30 - 20:30 1.00 DRILL N RREP INT1 PJSM w/ scaffolding crew. Rig up scaffolding around and underneath top drive. 20:30 - 00:00 3.50 DRILL N RREP INT1 Remove primer form motor mounts. Work TD motor into place. Install pins and bolt up motor. 4/11/2003 00:00 - 01 :30 1.50 DRILL N RREP INT1 Align motor & bolt motor in place. 01 :30 - 03:30 2.00 DRILL N RREP INT1 Bolt up all equipment around the motor. 03:30 - 06:45 3.25 DRILL N RREP INT1 Hook up all hydraulic lines. Tie wire all bolts. Remove and log in all tools. 06:45 - 07: 15 0.50 DRILL N RREP INT1 RID scaffolding and clean up the work area. 07:15 - 08:00 0.75 DRILL N RREP INT1 Close and bolt TD carrier. RID slings used to P/U motor. 08:00 - 09:30 1.50 DRILL N RREP INT1 Stab quill shaft into bull gear. 09:30 - 12:00 2.50 DRILL N RREP INT1 Wire blower motor and heaters. Work on oil pump. Steam clean pipe handler pieces. Note: Hole took 11.5 bbls in 12 hours. 12:00 - 17:30 5.50 DRILL N RREP INT1 Continue wiring Top Drive. Ready parts for installation. Connect TD to swivel and install link assembly. Printed: 6/16/2003 2:08:44 PM t f BP EXPLORATION Operations Summary Report Page 7 of 32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/11/2003 12:00 - 17:30 5.50 DRILL N RREP INT1 Install blower hose. Add oil to TD. Install Torque Tube Assembly and compenstor linkage. Wire Tie all bolts. 17:30 - 21 :30 4.00 DRILL N RREP INT1 PJSM. Install TD oiler motor. Install Pipe Handler. MU Kelly hose and saver sub. Function TD. 21 :30 - 22:00 0.50 DRILL N RREP INT1 PJSM. Inspect top drive looking for leaks and tools, etc. 22:00 - 23:00 1.00 DRILL N RREP INT1 Check TD torque function - vs - SCR room torque reading good. 23:00 - 00:00 1.00 DRILL N RREP INT1 Install bails and pepe elevators. Change oil in swivel. 4/12/2003 00:00 - 01 :30 1.50 DRILL N RREP INT1 Change oil in swivel. Check IBOP timing. 01 :30 - 02:30 1.00 DRILL N RREP INT1 Circulate Bottoms up and test mud lines. 02:30 - 03:30 1.00 DRILL N RREP INT1 Take drilling parameters just below 13-3/8" shoe. - 150 rpm wI 5000 ft-Ibs torque. - UP Wt= 165 K, SOW= 150 K, RT= 160 K -Ibs. - Old mud system 9.3 ppg w/ 65 vise. - Blow down all lines. 03:30 - 07:00 3.50 DRILL N RREP INT1 RIH to 8541' md- slm. - No tight spots / no fill. 07:00 - 07:30 0.50 DRILL N RREP INT1 Wash last stand to bottom- precautionary. 07:30 -12:15 4.75 DRILL P INT1 Take parameters. - 150 rpm w/ 17500 ft-Ibs torque. - Up wt= 260 K, SOW= 205 K, RT= 230 K-Ibs. Mud swap to GEM system. - Using vac truck support. 12:15 -12:45 0.50 DRILL P INT1 Drill ahead from 8629' to 8679' md. - Torque on 21.5 Kft- Ibs w/ 150 rpm - Flow 952 gpm w/ 2500 psig PP on & 2412 psig PP off. - 9.5 ECD - WOB 15 K, PUW = 275 K, SOW= 208 K, and RWT= 230 K Ibs. - ROP= 110 fph. 12:45 - 15:30 2.75 DRILL P INT1 Drill ahead 12-1/4" Int hole f/ 8679' to 8964' md. -Torq on 19-24 K ft-Ibs & Torq off 17-20 K ft-Ibs w/ 150 rpm - Flow 952 gpm w/ 2550 psig on and 2500 psig off. - 9.65 ECD - WOB 15 K, PUW= 288 K, SOW= 208 K, and RWT= 240 K Ibs. - ROP 30-220 fph. 15:30 - 19:45 4.25 DRILL P INT1 Drill ahead 12-1/4" hole f/ 8964' to 9342' md. - Torq on 23-24 K ft-Ibs & Torq off 19-21 K ft-Ibs w/ 150 rpm - Flow 954 gpm w/ 2850 psig on. - 9.70 ECD - WOB 15 K, PUW= 340 K, SOW= 190 K, and RWT =245 K Ibs. - ROP 130-150 fph. Printed: 6/16/2003 2:08:44 PM f' ~' BP EXPLORATION Operations Summary Report Page 8 of 32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/12/2003 19:45 - 00:00 4.25 DRILL P INT1 Drill ahead 12-1/4" hole f/ 9342' to 9752' md. - Torque on 24-26 K ft-Ib - PUW's Increasing 10K Ibs per stand. *** ADD torq ue trim at 1 % at 9400' .*** - Torque reduced to 24-25 K ft-Ibs and holding steady. 4/13/2003 00:00 - 10:30 10.50 DRILL P INT1 Drill ahead 12-1/4" w/ RSS from 9752' to 10538' md. - Increasing MW from 9.2 ppg to 10 ppb while drilling ahead. - MW increase was accomplished w/ 600 bbls of BARANEX spike fluid that was bleed into system. 10:30 - 12:00 1.50 DRILL N DPRB INT1 Develope losses at 30 to 40 bph. - Mix and pump LCM sweep and circulate. - Stopped losses. 12:00 - 23:30 11.50 DRILL P INT1 Drill ahead 12-1/4" w/ RSS from 10538' to 11414' md. - 4000+ units gas when cap rock Kuparuk "C" drilled (Top of Kuparuk "C" @ 11072' md- 9028' tvd rkb. MW was gas cut to 8.8 ppg at worst levels. Background gas came down to 600-700 units while drilling ahead. - At 22:25 hrs: Cutting samples show fluorescence from Kuparuk "C". Samples continued fluorescence from 11100'- 11160' md. 23:30 - 00:00 0.50 DRILL N RREP INT1 1) Mud pump #1 end cap developed leak. Derrickhand and motorman working on #1 pump. 2) Top Drive oil motor quit. Mechanic and Electrician troubleshooting. 4/14/2003 00:00 - 01 :30 1.50 DRILL N RREP INT1 Oil pump on Top Drive doesn't appear to be working. - Continue circulating while Mechanic and Electrician troubleshoot- can't repair - no back up available. - Decision made to drill ahead. 01 :30 - 05:30 4.00 DRILL P INT1 Drill ahead 12-1/4" intermediate hole f/ 11414 to 11537' md. - Top Miluveach picked at 11488' md. - TD depth of 11537' md includes 20' rathole for running 9-5/8" casing. 05:30 - 11 :00 5.50 DRILL P INT1 Pump 50 bbls of hi-vis weighted (12.2 ppg) sweep. - Pump surface to surface with minor excess cuttings returned to surface. - Condition MW from 10.0 ppg to 10.2 ppg. 11 :00 - 11 :30 0.50 DRILL P INT1 Monitor well and pump dry job. 11:30-15:00 3.50 DRILL P INT1 POH w/ BHA #3 for OH logs. Pulling 20 - 40 klbs from 11,150' to 10,980 ft. Could not progress past ledge at 10,915'- overpull gradually upto 100 klbs- no go. Pump past and wipe out several times. 15:00 - 15:30 0.50 DRILL P INT1 Perform D-1 Drill. PJSM for rig up to spot steel seal at 8300' md. 15:30-16:15 0.75 DRILL P INT1 Spot 135 bbls of steel seal LCM pill across Schrader Bluff interval. - Pump dry job and blow down lines. 16:15 - 17:30 1.25 DRILL P INT1 Contine POH to 13-3/8" casing shoe. 17:30 - 19:30 2.00 DRILL N RREP INT1 PJSM for removing inspection plate to inspect pinion gear on Printed: 6/16/2003 2:08:44 PM ,( ~" BP EXPLORATION Operations Summary Report Page 9 of 32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/14/2003 17:30 - 19:30 2.00 DRILL N RREP INT1 TD. - Drain Top Drive gear oil. - Pull inspection plate and find that pinion gear is off the shaft. 19:30 - 20:30 1.00 DRILL P INT1 Continue POH to HWDP. - UD dart sub and Weatherford Ghost Reamer. Reamer is 3/8" underguage on flat portion of blades & 1/4" under on the beveled section of the blades. - Monitor well and Fill Trip Tank. 20:30 - 20:45 0.25 DRILL P INT1 Stand back HWDP. 20:45 - 21 :15 0.50 DRILL N WAIT INT1 Plant turned off 1-solar. Lost power- regain power. 21 :15 - 23:30 2.25 DRILL P INT1 Lay down BHA#3. Bit in excellent condition and graded: 1-1-WT-T-X-I-NO-TD. 23:30 - 00:00 0.50 DRILL P INT1 Clear and clean rig floor. 4/15/2003 00:00 - 01 :00 1.00 EVAL P INT1 Clear rig floor of 12.25" BHA. 01 :00 - 02:00 1.00 EVAL P INT1 PJSM -- Rig up wireline 02:00 - 05:30 3.50 EVAL P INT1 Wireline logs stopped at 4062' MD. POH. 05:30 - 07:00 1.50 EVAL N DPRB INT1 Change hole finder on wireline. RIH. Tagged up at 4062' MD. POH. 07:00 - 08:00 1.00 EVAL P INT1 Rig down wireline. Decision made not to attempt Pipe Conveyed MD because of the hard ledge at 4,062 ft. Decision made to conduct top drive repair, make LWD /wiper trip and make one more atempt at MDT wireline befrore running 9.5/8". 08:00 - 09:30 1.50 EVAL N RREP INT1 Clear floor of casing tools in preparation for top drive repair. 09:30 - 10:00 0.50 EVAL P INT1 PJSM -- Testing BOP's 10:00 - 11 :00 1.00 EVAL P INT1 Pull wear bushing and set test plug. 11:00-15:00 4.00 EVAL P INT1 Test BOP's to 250 psi low and 4800 psi high. 15:00 - 16:00 1.00 EVAL P INT1 Blow down lines. Rig down testing equipment. Install wear bushing. 16:00 - 18:00 2.00 EVAL N RREP INT1 PJSM -- Pick up and make up BHA #4 (kill string). RIH to 13 3/8" shoe in case of well control while repairing the top drive. 18:00 - 22:00 4.00 EVAL N RREP INT1 PJSM -- Start dismantling top drive. Remove pipe handler, elevator, bails, torque stabilizer, link tilt assembly, compensators, kelly hose, "s" pipe, safety valves. Pull quill shaft through top drive. Rig up the pick up slings. 22:00 - 00:00 2.00 EVAL N RREP INT1 PJSM -- Erect scaffolding around rotary for accessing top drive. Remove blower ductwork and blower assembly. remove motor access covers for rigging up pick up slings. Sling motor and connect to pick up lines. Pull 2k, ready to remove the four motor mounting bolts. 4/16/2003 00:00 - 07:30 7.50 EVAL N RREP INT1 Rig down oil pump. Disconnect electrical wires. Remove mounting bolts. Lift motor. Rig down scaffolding. Set motor on floor. Finish rigging down electrical supports from the motor. Place motor on VLE cart. Pull pinion gear from gear box. Entire shaft broken apart. No damage to the teeth. 07:30 - 08:00 0.50 EVAL N RREP INT1 PJSM -- taking top drive motor off with rig and crane crews. 08:00 - 10:00 2.00 EVAL N RREP INT1 Send old motor off the floor using VLE and AIC crane. Bring new motor to the floor. Printed: 6/16/2003 2:08:44 PM ) ') Bp·EXPLORATION ()peratiol1s Summary Report Page 10of32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From'" To Höu rs Task Code NPT Phase Description of Operations 4/16/2003 10:00 - 14:30 4.50 EVAL N RREP INT1 Dress new motor with brushes and blower support brackets. Install motor heaters, mounting plate, and top drive brake. 14:30 - 15:30 1.00 EVAL N RREP INT1 PJSM -- Position motor at rotary table. Rig up slings to motor for raising to final installation. Heat shrink motor electrical wires. 15:30 - 16:00 0.50 EVAL N RREP INT1 PJSM -- Rig up scaffolding. 16:00 - 17:00 1.00 EVAL N RREP INT1 Line up and bolt in motor. 17:00 - 18:30 1.50 EVAL N RREP INT1 Make electical connectioins on motor. Install winding access covers. 18:30 - 22:00 3.50 EVAL N RREP INT1 PJSM -- Install blower duct and blower assembly. Swing in top drive and button up top drive. Rig down scaffolding. 22:00 - 23:30 1.50 EVAL N RREP INT1 PJSM -- Lower quill through top drive. Hook up compensators and connect top drive to swivel. 23:30 - 00:00 0.50 EVAL N RREP INT1 Install temperature probe and remove pinion gear inspection plate. 4/17/2003 00:00 - 09:30 9.50 EVAL N RREP INT1 Continue top drive repair. Finish putting on oil inspection plate. Install link adapter, link tilt, upper and lower IBOP valves, saver sub, safety valve, actuator, and pipe handler. Add 9 gallons of oil to gear box. Install S pipe and kelly hose. Hook up air and hydraulics. Adjust counter balance. Finish rewiring oil pump. Test rotation of blower motor. Check top drive rotation. Make up to drill pipe, check make up and break out. 09:30 - 10:30 1.00 EVAL N RREP INT1 Condition mud and circulate. 10:30 - 12:00 1.50 EVAL P INT1 Cut and slip 102' of drilling line. 12:00 - 13:00 1.00 EVAL N RREP INT1 Run replacement wiring for top drive oiler motor. 13:00 - 15:30 2.50 EVAL N RREP INT1 POOH and lay down BHA #4. 15:30 - 20:00 4.50 EVAL N DPRB INT1 Make up BHA #5 for wellbore cleanout prior to running logs. RIH with HWDP. 20:00 - 20:30 0.50 EVAL N DPRB INT1 PJSM -- Hang blocks to inspect the block shieve. Suspect of being loose, all ok. 20:30 - 21 :30 1.00 EVAL N DPRB INT1 Continue to RIH to the shoe at 3660' MD. 21 :30 - 22:00 0.50 EVAL N DPRB INT1 Fill pipe and get drilling parameters. NOTE: 60 rpm; 9150 ftlb torque; 890 gpm; 1930 psi 164k PU; 141k SO; 148k ROT 22:00 - 23:00 1.00 EVAL N DPRB INT1 Continue to RIH to 3972' MD. Make up top drive to ream. NOTE: Ream from 3972' MD to 4090' MD 80 rpm; 950 gpm; 2400 psi Blow down top drive and lines. 23:00 - 00:00 1.00 EVAL N DPRB INT1 Continue to RIH. 4/18/2003 00:00 - 03:30 3.50 EVAL N DPRB INT1 Trip in hole to 10,778' MD. Bridged off. NOTES: 1. Tagged up at 10,692' MD. Began to pump and ream at 80 rpm, 15k torque, 860 gpm, and 3400 psi. 2. Pump and ream continually. 3. Work tight hole- temporally stuck several times. 4. Bottoms up returned at 10,810' MD. Thick mud blinded Printed: 6/16/2003 2:08:44 PM ) ) BPEXPLORA TION . Operations Summary Report Page 11 of 32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From- To Hours · Task Code NPT Phase Description of Operations 4/18/2003 00:00 - 03:30 3.50 EVAL N DPRB INT1 shakers. 1000 units of gas (high reading of 1250 units). 5. HRZ picked from 10,767' MD to 10,849' MD 03:30 - 04:30 1.00 EVAL N DPRB INT1 Ream to 10,880' MD. Hole packing off and sticky. NOTES: 1. Decision to pull up above the HRZ and weight up the mud system to hold back the shales. 2. Kuparuk picked from 10,899' MD to 11,488' MD 04:30 - 06:30 2.00 EVAL N DPRB INn Back ream out of HRZ NOTES: 1. Hole continually packing off and sticky. 2. Hit a No-go at 10,822' MD. Worked repeatedly. Broke free after 1.5 hours. 3. Rotated one stand out and pumped out the next two (three total, stands 105, 104, and 103). 4. Mixing Barite for mud weight up (targeting 10.7 ppg). 06:30 - 09:30 3.00 EVAL N DPRB INT1 Condition mud and circulate. Weight up from 10.2 ppg to 10.7 ppg. 09:30 - 19:45 10.25 EVAL N DPRB INT1 Wash and ream from 10,770' MD to 11,537' MD. HRZ was OK. Rotary stalling repeatedly from 10,949' to 11,000'- no packing off. NOTES: 1. MAD pass from 11,150' MD to 11,537' MD while washing and reaming. 2. At 11,474' MD: 88 rpm, 20k torque, 830 gpm, 3300 psi, 330 PU, 215 SO, and 270 ROT. 3. At TD (11,537' MD): 100 rpm, 21 k torque, 850 gpm, 3400 psi, 340 PU, 210 SO, and 265 ROT. 19:45 - 00:00 4.25 EVAL N DPRB INT1 POOH from 11,537' MD to 10,594' MD NOTES: 1. Parameters: 90 rpm, 21 k torque, 815 gpm, 3300 psi 2. First stand out (57'): pumped and rotated. 3. Second stand out: pumped and rotated; top drive stalling. Half way up the stand decided to stop rotating and pump out. This worked much better, breaking over at 400k. 4. Top of Kuparuk pulling tight- breaking over easy going down and cleaning up with wipe. 5. Could not dry pull through the HRZ- with pumps on the overpull was 20-30 Klbs- did not need to backream. 4/19/2003 00:00 - 03:00 3.00 EVAL N DPRB INT1 Continue to POOH to 8300' MD. NOTE: 1. Pulling wet with pumps off and no rotation. 2. Had to pull slow to about 10,000' MD, then the formation relaxed and allowed for normal tripping speed. 03:00 - 04:00 1.00 EVAL N DPRB INT1 Spot steel seal pill. Pump 12.7 ppg dry job. 04:00 - 06:00 2.00 EVAL N DPRB INT1 Continue to TOOH to the 13 3/8" shoe at 3666' MD. Monitor well. 06:00 - 08:00 2.00 EVAL N DPRB INT1 POOH to BHA. Lay down BHA. Printed: 6/16/2003 2:08:44 PM ) ) BPSXPLORA TION Qperations Summary Report Page 12 of32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From- To Hours Task Code NPT Phase Description of Operations 4/19/2003 08:00 - 10:00 2.00 EVAL N DPRB INT1 Clear rig floor to remove Anadrjl source. Continue to lay down BHA. 10:00 - 11 :00 1.00 CASE P INT1 Pull wear bushing and set test plug. 11 :00 - 12:30 1.50 CASE P INT1 Change out upper BOP rams to 9 5/8". 12:30 - 13:45 1.25 CASE P INT1 Rig up to test door seals. Test door seals to 3500 psi for 15 minutes. Rig down from pressure test. 13:45 - 15:15 1.50 CASE P INT1 PJSM -- Remove bails. PJSM -- Make up Franks Tool PJSM -- Install long bails PJSM -- Rig up casing tools 15:15 - 15:30 0.25 CASE P INT1 PJSM on running 9 5/8" 53.5 ppf casing. 15:30 - 19:30 4.00 CASE P INT1 Run 9 5/8" 53.5 ppf casing with centralizers to 2730' MD. 19:30 - 20:45 1.25 CASE N SFAL INT1 PJSM -- Lay down Franks tool and change out rubber cup. Circulate a string volume (2000 strokes) at 460 psi. 20:45 - 21 :15 0.50 CASE P INT1 Continue to RIH with casing to 3650' MD (13 3/8" shoe). NOTE: PU at shoe = 240k 21:15-22:15 1.00 CASE P INT1 Circulate string volume (2500 strokes) at 460 psi. 22: 15 - 00:00 1.75 CASE P INT1 Continue to RIH with casing to 4867' MD. NOTE: PU at 4615' MD = 275k Hole still taking some fluid as RIH. 4/20/2003 00:00 - 11 :30 11.50 CASE P INT1 RIH with 9 5/8" casing from 4867' MD to 11516' MD. NOTE: 1. Lay down joint #118 for damaged box threads (replaced with joint #285 between joint #173 and #174). 2. Losses were consistent at approximately 1 bph. However, the hole took about 6 bbls at Schrader Bluff. 3. Casing went down without incident until joint 276. The string would packoff, circulation would be established, the pipe would fall, then packoff again. This cycle repeated throughout the joint for nearly 2 hours. 4. Once this joint was run in, the landing joint was made up. This joint went down relatively incident free. 5. Floating centralizers were run one per joint from joint #1 to #174. 6. The final wieght of the string in the slips was 345k (including 70k for the top drive). 11 :30 - 12:30 1.00 CASE P INT1 Condition and circulate mud. 12:30 - 13:00 0.50 CASE P INT1 Land 9 5/8" casing. 13:00-13:15 0.25 CASE P INT1 PJSM -- Rig down franks tool. 13:15 -13:30 0.25 CASE P INT1 PJSM -- Rig up cement head. 13:30 - 14:00 0.50 CEMT P INT1 Circulate at 10 bpm with 890 psi in preparation for cement job. 14:00 - 16:30 2.50 CEMT P INT1 Pressure test cement lines to 3000 psi for 15 minutes. Pump cement. NOTE: 1. Pump 50 bbls of 11.2 ppg Alpha spacer. 2. Pump 363 bbls of 11.2 ppg Lead slurry. Printed: 6/16/2003 2:08:44 PM ) ) BP. EXPLORATION Operations" Sum maryReport Page 13 Of .32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/20/2003 14:00 - 16:30 2.50 CEMT P INT1 3. Pump 143 bbls of 15.9 ppg Tail slurry. 4. Cement pumped at 5 bpm, limited by G&I pump for water supply. Will look into condition of pump as this limitation is irregular. 16:30 - 18:00 1.50 CEMT P INT1 Displace with rig pump at 10 bpm. NOTE: 1. Plug bumped with 95.6% efficiency (7818 strokes). 2. No losses. 3. Approximately 25 bbls of Alpha spacer returned to surface, no cement returns. 18:00 - 18:30 0.50 CEMT P INT1 Rig down cement head and landing joint. 18:30 - 19:30 1.00 CEMT P INT1 Install packoff and test to 6500 psi for 15 minutes 19:30 - 20:15 0.75 CEMT P INT1 Change out drilling sweep on wellhead. Clear rig floor. 20:15 - 20:45 0.50 CEMT P INT1 Rig up to 13 3/8" x 9 5/8" annulus. Change out to short bails. 20:45 - 21 :00 0.25 CEMT P INT1 Pressure test lines to 3000 psi. 21 :00 - 00:00 3.00 CEMT P INT1 Flush 13 3/8" x 9 5/8" annulus with 10.7 ppg mud at 1 bpm with 920 psi. NOTE: Broke over at 1500 psi at 1/2 bpm. Install test plug. Change out upper rams. Service top drive. Begin work to change out liners to 5.5" on #2 mud pump. 4/21/2003 00:00 - 01 :30 1.50 CEMT P INT1 Continue flushing annulus with 10.6 ppg mud. 230 bbls total. 01 :30 - 02:30 1.00 CEMT N SFAL INT1 Seawater line hose fitting parted at factory end. Discharged onto 13.8 KV cable. Safeout and change over to rig power. 02:30 - 03:30 1.00 CEMT P INT1 Rig up to test BOPE. 03:30 - 08:00 4.50 CEMT P INT1 Pressure test BOPE; 250 low 4800 high. 08:00 - 09:00 1.00 CEMT P INT1 Pull test plug. Set wear bushing. Blow down lines. 09:00 - 12:00 3.00 CEMT N RREP INT1 Trouble shoot and change out top drive oil pump. 12:00 - 13:30 1.50 CEMT P INT1 PJSM -- Make up BHA #6 drilling assembly. 13:30 - 14:00 0.50 CEMT P INT1 Shallow test MWD & RSS. 14:00 - 15:00 1.00 CEMT P INT1 Continue making up BHA #6. 15:00 - 15:15 0.25 CEMT P INT1 RIH with 9 stands of HWDP. 15:15 - 15:45 0.50 CEMT P INT1 PJSM -- Lay down 12 joints of HWDP. Change liners to 5.5" on MP #1. 15:45 - 21 :30 5.75 CEMT P INT1 PJSM -- RIH with 5" drillpipe to 11329' MD. Tagged up on cement (approximately 7 bbls left on top of plug at 11430' MD). 21 :30 - 23:30 2.00 CEMT P INT1 PJSM -- Cut and slip drilling line. Check brakes. 23:30 - 00:00 0.50 CEMT P INT1 Wash and ream from 11271' MD to 11329' MD, cleaning hole. 4/22/2003 00:00 - 01 :30 1.50 CEMT P INT1 Wash and ream from 11329' MD to 11430' MD, cleaning hole. 01 :30 - 02:00 0.50 CEMT P INT1 Condition mud and circulate untill MWin = MWout at 10.6 ppg. 02:00 - 03:00 1.00 CEMT P INT1 Pressure test casing to 4600 psi for 30 minutes with 10.6 ppgl mud. Blow down mud lines. NOTE: 141 strokes to 4600 psi consistent delta P every 5 strokes. 03:00 - 10:00 7.00 CEMT P INT1 Drill float equipment. NOTES: 1. ECD = 13.7 ppg EMW 2. Packing off periodically 3. Rotary stalling out Printed: 6/16/2003 2:08:44 PM ') ) BP EXPLORATION o peratio nsSu mma ryReport Page'14of32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From - To Hours . Task Code NPT Phase · Descri ption of Operations 4/22/2003 03:00 - 10:00 7.00 CEMT P INT1 4. Picking up to 400k max. 5. Torque at 23k - 26k 6. 130 SPM I 2200 PSI 7. ROT = 240k; PU = 325k; SO = 190k 10:00 - 15:30 5.50 CEMT P INT1 Drilling up rathole and 20' of new hole to 11558' MD NOTE: 1. Packing off, stalling rotary, 50 - 1 OOK drag while cleaning rathole. Made several trips through rathole cleaning up. 2. Pumped 2 nut plug sweeps while drilling 20' of new hole due to bit balling. 15:30 - 16:15 0.75 CEMT P INT1 Perform FIT NOTE: 1. Targeting a FIT of 14.5 ppg EMW; however, it broke over to 800 psi after 1 minute (14.25 ppg EMW) and to 710 psi after 10 minutes (14.1 ppg EMW). 2. Performed FIT twice to confirm no surface leaks on first attempt. 3. The newly established ECD hardline is 14.0 ppg. 16:15 - 00:00 7.75 DRILL P LNR1 Drill new formation from 11,558' MD to 11,843' MD. NOTE: 1. Bit balling initially, cured with walnut sweeps. 2. ROP extremely low (2-15 fph); however picked up after approximately 30'. 3. Sweeps brought back over 2 Ibs of metal shavings thought to be from the bit; however, the potential exists that the NBR opened in casing while drillng up the float equipment. 4. Ditch magnets are being checked every 3 hours and metal returns are diminishing. 4/23/2003 00:00 - 01 :30 1.50 DRILL P LNR1 Drilling with 8.5" RSS & 9" NBR fl 11843' -- 11879' md. Note: RSS responding to downlinks. 01 :30 - 02:00 0.50 DRILL N RREP LNR1 Experienced problems with top drive oil pump -- pulled to 9-5/8" casing shoe to diagnose problem. 02:00 - 04:00 2.00 DRILL N RREP LNR1 Dtermined oil lines plugged with silicone -- drained oil, cleaned lines and and reservoir and refilled. 04:00 - 04:30 0.50 DRILL N RREP LNR1 RIH to resume driling. 04:30 - 12:00 7.50 DRILL P LNR1 Drilling with 8.5" RSS & 9" NBR fl 11879' -- 12126' md. Notes: - 305k PU; 215k SO; 250k ROT - RSS responding to downlinks. 12:00 - 15:00 3.00 DRILL P LNR1 Drilling with 8.5" RSS & 9" NBR fl 12126' --12310' md. Note: RSS responding well to downlinks. 15:00 -15:15 0.25 DRILL P LNR1 Service top drive. 15:15 - 00:00 8.75 DRILL P LNR1 Drilling with 8.5" RSS & 9" NBR fl 12310' --12682' md. Notes: 1. ECD's staying below 13.9 ppg EMW 2. 0.5% EP I 1.0% torque trim. 3. RSS responding well to downlinks. 4/24/2003 00:00 - 18:00 18.00 DRILL P LNR1 Drill ahead from 12687' MD -13461' MD. TD of hole section. Notes: Printed: 6/16/2003 2:08:44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ') ) BP EXPLORATION Operations Summary Report Page .150f 32 NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: 4/24/2003 00:00 - 18:00 From~To Hours Task Code NPT Phase LNR1 18:00 - 19:30 19:30 - 22:15 4/25/2003 22:15 - 00:00 00:00 - 02:30 02:30 - 04:30 04:30 - 10:30 Description of Operations' 18.00 DRILL P Drill 22' into the Sag river. Lost circulation. Likely caused by a fault for vug down hole. Prior to losing circulation, ROP was 25 fph then drilled 105 fph for about 10 feet and back to 25 fph. Losses occurred while drilling 105 fph at approximately 2.5 bph. Lost circulation. Circulated at 2 bpm, losing 2.4 bpm (150 bph) for a total of 195 bbls lost. Stopped circulating and lined up on the trip tank. Established static losses at 0.7 bpm (42 bph). Decision to POOH to the shoe to eliminate risk of differential sticking.j POOH with 21 stands to 11,462' MD -- lost 22 addtional bbls while POOH to shoelTotal Losses are 195 bbls. 1.50 DRILL N DPRB LNR1 2.75 DRILL N DPRB LNR1 Notes: - First 7 stands pulled without incident. - Stands 8 and 9 pulled tight and required significant wiping (12,700' -12,850'). - Stands 10 - 17 pulled relatively easy with signs of ledges that required wiping -- ledges did not go away. No signs of swabbing. - Stands 18 and 19 pulled tight and required significant wiping with tendency to swab. 1.75 DRILL N 2.50 DRILL P LNR1 LNR1 Trip in hole with drilling assembly to spot LCM pill at 13,448' MD. Notes: 1. RIH with pumps off. 2. Very ledgy with 450k max overpull and 125 min slack off. 3. Significant trouble at 12,700' MD, 13,000' MD, and 13,200' MD to TD at 13,448' MD. - stacking up numerous times even when attempting to wipe. - ledges in these areas would not wipe out -- repeated overpulls. 4. Hole took approximately 5 bbls during the trip in (less than 2 bbls per hour). Spot LCM pill. Notes: 1. Pill contained 30 ppb Barofibre and 10 ppb of Walnut. 2. Pumped at 32 spm I 2.7 bpm I 750 psi 3. Chased with 2600 strokes. 4. No losses observed while pumping on bottom. Trip out of the hole to the 9 5/8" shoe at 11,517' MD. Notes: 1. Layed down the single without incident. 2. Tried repeatedly to pull the first stand, but would not go. Overpull to 475k. Decided to begin pumping out of the hole. 3. Started pumping at 2 bpm and 600 psi. Started to packoff. Adjusted pumps and POOH with pumps between 40 and 60 strokes for rest of trip. 4. Pulled out with some packing off and overpulls of 450k until approximately 12,500' MD. 5. Pulled better with frequent wiping until 11 ,600' MD. 2.00 DRILL N DPRB LNR1 6.00 DRILL P LNR1 Printed: 6/16/2003 2:08:44 PM ... ) ) BP EXPLORATION Operations Summary Réport Page 16 of 32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: . Date From- To Hours Task Code NPT Phase Descri ption of. Operations 4/25/2003 04:30 - 10:30 6.00 DRILL P LNR1 6. Pulled good to the shoe from 11,600' MD except had overpulls of 450-475K last two stands to get into shoe. 7. Necessary to reduce pump rate to 12 to 24 spm on last two stands up into shoe to prevent packing off. 10:30 - 12:30 2.00 DRILL P LNR1 Condition and circulate at the shoe. Monitor well. 12:30 - 12:45 0.25 DRILL P LNR1 POOH 3 stand wet -- hole not swabbing. Note: Lesson Learned about pull rate required to break fluid couple with pipe for the high break back yield formula for this intermediate fluid. Pulling too slow equates to swab similar to pulling too fast -- 120 and 110 see per stand swabbed while 90 see per stand pull without swabbing. 12:45 - 13:00 0.25 DRILL P LNR1 Pump dry job and blow down. 13:00-17:00 4.00 DRILL P LNR1 POOH to the HWDP. 17:00 - 17: 15 0.25 DRILL P LNR1 Monitor well at HWDP. 17:15 - 17:45 0.50 DRILL P LNR1 POOH and lay down HWDP with correct hole fill. 17:45 - 19:30 1.75 DRILL P LNR1 LD BHA #6. 19:30 - 20:00 0.50 DRILL P LNR1 Clear floor. 20:00 - 21 :00 1.00 CASE P LNR1 PJSM -- RU casing tools. 21 :00 - 21 :30 0.50 CASE P LNR1 PJSM on running 7" liner. 21 :30 - 00:00 2.50 CASE P LNR1 RIH with 7" 29# Hydril 511 liner assembly with reamer shoe. Notes: 1. Centralized shoe track and three joints below the liner equipment (above the 9 5/8" shoe). 2. Centralizers are floating. 8 total. 3. PU 125k; SO 108k with pipe full, liner in the hole, with one stand of 5" drillpipe. 4/26/2003 00:00 - 02:30 2.50 CASE P LNR1 RIH with 7" 29# Hydril 511 liner üoints #24 - #54). 02:30 - 03:30 1.00 CASE P LNR1 Make up liner hanger assembly. Mix Pal Mix (set up 30 minutes). 03:30 - 04:00 0.50 CASE P LNR1 Run one stand of 5" drillpipe. Circulate one liner volume (80 bbls). Notes: PU = 125k; SO = 108K 04:00 - 11 :00 7.00 CASE P LNR1 RIH with 5" drillpipe to 11,452' MD (shoe at 11,517' MD). Notes: Filling pipe every 10 stands. No losses. 11:00 -12:30 1.50 CASE P LNR1 Circulate a drill string and liner volume at shoe. Notes: 1. 241 bbls pumped at 80 spm I 1050 psi 2. PU = 320k; SO = 200k; ROT = 245k 3. At 15 rpm, torque = 18k ftlbs 12:30 - 13:30 1.00 CASE P LNR1 RIH with 7" liner to 11,797' MD. Notes: 1. Stack up with 45k, 60k, 8Sk, and 11 Ok Ibs. 2. Slowly making progress working liner through ledges to 11, 824' MD. 13:30 - 15:30 2.00 CASE P LNR1 RIH with 7" liner to 12,105' MD. Notes: 1. Stack up with 11 Ok Ibs. Unable to work past ledge. 2. Pump at 24 spm and rotate at 40 rpm to work past ledges. 15:30 - 19:00 3.50 CASE P LNR1 RIH with 7" liner to 12,952' MD. Notes: 1. Stack up with 45k, 85k, and 11 Ok Ibs. Printed: 6/16/2003 2:08:44 PM \0. ') ) BP EXPLORATION Opera.ti onsS u m l11aryRe PQ rt Page 17 of 32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From - To Hours Task·· Code NPT Phase Description of Operations 4/26/2003 15:30 - 19:00 3.50 CASE P LNR1 2. Unable to work pipe past ledge or obstruction. 3. Pump at 24 spm and rotate at 60 rpm to work liner past ledge/obstruction. 19:00 - 00:00 5.00 CASE P LNR1 RIH with 7" liner to 13,310' MD. Notes: 1. Stack up with 45k, 85k, and 11 Ok Ibs. 2. Unable to work pipe past ledge or obstruction. 3. Pump at 24 spm and rotate at 60 rpm to work liner past ledgelobstruction. 4/2712003 00:00 - 04:30 4.50 CASE P LNR1 RIH with 7" 29# L80 Hydrill 511 liner. Notes: 1. Ream liner from 13,330 - 13,445' MD. 2. 29 spm 1450 psi. 3. 40 to 50 rpm with 25K to 27K torque. 4. Torque reduced -30% with addtion of 0.5% and 2.0% EP Mud Lube and Torq Trim, respectively. 04:30 - 05:00 0.50 CASE P LNR1 Rig up Baker cement head. 05:00 - 07:00 2.00 CASE P LNR1 Establish circulation up to 5.5 bpm at 950 psi. Note: As rates were staged up, there were some tendencies to pack oft; however, the pressure would break over after a few minutes. 07:00 - 09:00 2.00 CASE P LNR1 PJSM -- Test cement lines to 4500 psi. Set hanger and attempt to release. Notes: 1. Drop hanger setting ball. Pump down at 5.5 bpm. 2. Pressure up to 2300 psi at 2870 strokes to set hanger. 3. Set down to 11 Ok Ibs (90K slack off). 4. Pressure up to 3200 psi, bled pressure to zero and PU to verify release of liner weight -- not released. 5. Repeat Steps 3 and 4 with 40K down in attempt to release -- unsuccessful. 5. Set down and pressure up to 4250 psi to blow ball seat in landing collar (attempting to set hanger in case of over pinning). Still will not release. 09:00 - 12:00 3.00 CASE N DFAL LNR1 Try to emergency release from hangerlpacker assembly. Notes: 1. Pick up 5' pup to allow for more downstroke. 2. Work 20k ftlbs of left hand torque into pipe for mechanical emergency release. 3. Lay down 5' pup and pickup 15' pup for more travel room. 4. Work down to 13,461' MD and slack oft to 90k Ibs. 5. Pick up to 200k Ibs with 10k ftlbs of torque. Still not released. 12:00 - 19:00 7.00 CASE N DFAL LNR1 Continue trying to release from hanger I packer with no success. Notes: 1. Working 10K left hand torque down hole in hopes of emergency release. 19:00 - 20:00 1.00 CASE P LNR1 Rig down cement head in preparation for POOH. 20:00 - 21 :00 1.00 CASE P LNR1 PJSM - Cut and slip 102' of drilling line. 21 :00 - 21 :30 0.50 CASE P LNR1 Adjust brakes. 21 :30 - 22:30 1.00 CASE P LNR1 Lubricate rig -- Service top drive and crown. 22:30 - 00:00 1.50 CASE P LNR1 POOH with 7" liner. Printed: 6/16/2003 2:08:44 PM ') ) BP EXPLORATION Operations SurnmäryReport Page·18 öf 32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/27/2003 22:30 - 00:00 1.50 CASE P LNR1 Notes: 1. Pulled up with 450K on first stand. Slacked off and pulled free with 425K. Slacked back off and when pulled back up weight fell off to 330K. 2. Pulled 30' but could not get out without swabbing. Decided to pump out of hole. 2. Pumping at 24 spm 1270 psi I with 270 hookload. 3. Aireated fluid coming out of the drill pipe at connections. 4. No losses and no swabbing. 4/28/2003 00:00 - 03:00 3.00 CASE P LNR1 POOH with 5" drillpipe from #114 - #99. Notes: 1. Starting to pull faster (according to Sperry Sun schedule), no swabbing or losses. 2. Pumping at 24 spm I 270 to 110 psi. 3. Hookload was 260k at 12,290' MD; 240k at 11,800' MD. 4. Fluid coming out of the drill pipe at connections no longer showing signs of air; looking more like u-tubing. 03:00 - 04:00 1.00 CASE P LNR1 Monitor well. Pump 14.6 ppg dry job. Blow down lines. Clean rig floor. 04:00 - 09:00 5.00 CASE P LNR1 Continue to POOH to liner running tool. No liner. 09:00 - 09:45 0.75 CASE P LNR1 Inspect and lay down tool. Notes: 1. All parts accounted for to include drill pipe wiper plug. 2. Sent back to Baker for inspection. -- Still tearing it down at report time; however, did confirm that the hydraulic release mechanism was sheared. 09:45 - 10:15 0.50 BOPSURP LNR1 Clean floor. Pump out stack. Pull wear ring. 10:15-11:00 0.75 BOPSURP LNR1 Set test plug. Rig up for BOP test. Fill stack. 11:00 -18:15 7.25 BOPSUR P LNR1 Test BOP's. Rig down, pull test plug, blow down lines, drain stack, and clear floor. Notes: 1. TestS" 2. Test 7" (no test on top Rams) 3. Test 4.5" 18:15 - 19:15 1.00 BOPSUR N RREP LNR1 PJSM -- pull mouse hole and riser. 19:15 - 19:45 0.50 BOPSURN RREP LNR1 Secure rotating ring off upper ram doors. 19:45 - 20:30 0.75 BOPSURN RREP LNR1 Change out 4 1/2" x 7" ram on east side and pull ram out of west door. 20:30 - 21 :30 1.00 BOPSURN RREP LNR1 PJSM -- Rig up to pull the pit-side door and pull ram out of west door. 21 :30 - 22:00 0.50 BOPSUR N RREP LNR1 Rig up and pick new door. 22:00 - 23: 15 1.25 BOPSUR N RREP LNR1 Install new ram door and new 4 1/2" x 7" ram and door seal. 23:15 - 00:00 0.75 BOPSURN RREP LNR1 Nipple up riser, mouse hole, turn buckles, and rotating ring. 4/29/2003 00:00 - 01 :00 1.00 BOPSURN RREP LNR1 Continue installing turn buckles and lift ring on hydril. 01 :00 - 02:00 1.00 BOPSUR P LNR1 Run Junk Catcher Sub. RU BOPE Stack Jetting Tool and Flush Stack. Pull Junk Catcher Sub. 02:00 - 05:30 3.50 BOPSURP LNR1 Pressure Test BOPE Stack to 250/4800 psig. 05:30 - 06:30 1.00 BOPSURP LNR1 Pull test plug. Set wear ring. RID BOPE testing equipment. 06:30 - 07:30 1.00 CEMT N DFAL LNR1 PJSM. RlU SWS wireline for drift and liner correlation runs. 07:30 - 09: 15 1.75 CEMT N DFAL LNR1 Trouble shoot wireline toolstring (GR tool). 09: 15 - 09:45 0.50 CEMT N DFAL LNR1 Change out toolstring. 09:45 - 14:30 4.75 CEMT N DFAL LNR1 WL Run #1 (GRlCCU wI 5" sinker bar max OD). Printed: 6/16/2003 2:08:44 PM ) ') BP EXPLORATION OpèrationsSuI11maryReport Page 190f 32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/29/2003 09:45 - 14:30 4.75 CEMT N DFAL LNR1 - Find liner top at 11282' elmd. - Tag fill @ 13168' elmd. - POOH fl sample bailer run. 14:30 - 15:00 0.50 CEMT N DFAL LNR1 MU BHA #2 (CCL wI sample bailer wI 2.125" max OD). 15:00 - 18:00 3.00 CEMT N DFAL LNR1 WL Run #2. - Tag fill @ 13222' elmd. - Slack off several times and fill sample bailer. - On surface - recover finely ground shale from bailer. * See pictures sent in with forward plan. 18:00 - 18:30 0.50 CEMT N DFAL LNR1 Rig Down SWS wireline. 18:30 - 19:45 1.25 CEMT N DFAL LNR1 PJSM for MU BHA #7. MU BHA #7 which consists of the following: 6" OD Bit (no jets); 3 jts 4" HWDP; Jar; and 2 Jts 4" HWDP. 19:45 - 22:00 2.25 CEMT N DFAL LNR1 PU 63 jts of 4" DP. 22:00 - 22:15 0.25 CEMT N RREP LNR1 Check swivel. Note: 1) Bottom seal on swivel has slight hydraulic oil. 2) Fix requires removing pipe handler. 3) 10 to 12 hour repair -- Tool Pusher feels this can be repaired during prep for drilling hiatus. 22: 15 - 00:00 1.75 CEMT N DFAL LNR1 RIH wI BHA #7 -- clean out assembly. 4/30/2003 00:00 - 02:00 2.00 CEMT N DFAL LNR1 RIH wI clean out string from 7762' md to 12988' md. -- Find Top of liner at 11288' md. Set down 10 K Ibs and PU off liner top. Run through liner top without any trouble. -At 12988' md, PUW= 290 KI SOW= 210 K Ibs. 02:00 - 03:00 1.00 CEMT N DFAL LNR1 Wash from 12988' md to 13349' md (landing collar). - Top of fill @ 13330' md. 03:00 - 06:00 3.00 CEMT N DFAL LNR1 Circulate Hi-vis sweeps x 3 while reciprocating and rotating. - Rotated at 130-150 rpm. - Circulated at 16 bpm. - Finely ground Kingyak, Miluveach, and Sag cuttings were returned across shakers (Size varied from coarse to down to powder). 06:00 - 07:00 1.00 CEMT N DFAL LNR1 Monitor well. - Set down on landing collar and attempt to move liner down hole 3 x 's by slacking off 50 K Ibs. No movement. - Pump dry job. 07:00 - 13:00 6.00 CEMT N DFAL LNR1 POOH wI 5" DP to 4" DP. - SLM 5" DP- no change from previous talley. 13:00-13:15 0.25 CEMT N DFAL LNR1 Monitor well. 13:15 - 14:00 0.75 CEMT N DFAL LNR1 POOH wI 4" DP to BHA #7. - SLM 4" DP- no change from previous talley. 14:00 -15:00 1.00 CEMT N DFAL LNR1 PJSM. Lay down BHA #7. 15:00 -16:15 1.25 CEMT N DFAL LNR1 Clear floor. PJSM. MU BHA #8 (7" Fas - Drill Pkr). 16:15 -16:45 0.50 CEMT N MISC LNR1 Dry hole tree in cellar was found to be starting to tip over because of subsidence. NS24 was SI and dry hole tree was secu red. - PJSM for moving dry hole tree. Move dry hole tree. 16:45 - 18:00 1.25 CEMT N DFAL LNR1 PJSM. Pull test tugger lines. 18:00 - 19:00 1.00 CEMT N DFAL LNR1 PJSM. RIH wI BHA #8 (7" Fas-Drill Pkr) on 4" DP. 19:00 - 00:00 5.00 CEMT N DFAL LNR1 PJSM. RIH wI 5" DP. Printed: 6/16/2003 2:08:44 PM ) ) BP EXPLORATION OpE!ration!;S umnia ryRe port Page·20of32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From ~To Hours Task Code NPT Phase Description of Operations 5/1/2003 00:00 - 01 :30 1.50 CEMT N DFAL LNR1 RIH wI Fas- Drill Pkr from 12330' - 13348' md. 01 :30 - 02:00 0.50 CEMT N DFAL LNR1 Fill Pipe and break circulation. PJSM for RU TD head. 02:00 - 02:30 0.50 CEMT N DFAL LNR1 Set Fas- Drill Pkr at 13343' md (element depth) I Top of Plug @ 13341' md. - Fas Drill took 4 attempts (25, 20, 20, 25 turns to right). Slacked off 20 K Ibs and then 40 K Ibs onto pkr. - Suspect slips were coated with solids which had to be worn off. 02:30 - 04:00 1.50 CEMT N DFAL LNR1 RU cement head. 04:00 - 04:30 0.50 CEMT N DFAL LNR1 Sting out of Fas- Drill and establish circulation inside the liner up to 5.5 bpm wi 1040 psig. 04:30 - 05:30 1.00 CEMT N DFAL LNR1 Spot 75 bbls of 12.6 ppg Hi-vis sweep inside 7" liner. 05:30 - 07:30 2.00 CEMT N DFAL LNR1 Sting back into Fas-Drill and attempt to circulate around 7" liner without success. - Slack off and place 20 K Ibs on Fas- Drill. - Break circulation and pressure up to 2500 psig. Bleed off and pressure up to 1500 psig - 4 times - not able to establish any type of circulation. Pressure up to 4000 psig and to 4500 psig-- no circulation established. - 4500 psi applied to top of Sag with 4500 psi and 12.6 ppg mud is 20.5 ppg EMW -- Float Track is plugged. 07:30 - 08:00 0.50 CEMT N DFAL LNR1 Rig Down manifold and cement head. 08:00 - 09:30 1.50 CEMT N DFAL LNR1 MU top drive and rotate. Notes: - Rotate setting tool to extend stinger on more time. - Sting back into Fas -Drill and attempt to circulate one more time without success. 09:30 - 11 :30 2.00 CEMT N DFAL LNR1 Trip out of 7" liner without pumping dry job- leaving hi-vis pill in 7" liner. 11 :30 - 12:00 0.50 CEMT N DFAL LNR1 Monitor well. Clean rig floor. 12:00 - 13: 15 1.25 CEMT N DFAL LNR1 PJSM. Slip and cut drilling line. 13:15 -14:00 0.75 CEMT N DFAL LNR1 Service top drive and drawworks. 14:00 - 14:30 0.50 CEMT N DFAL LNR1 Monitor well. Slug well. Blow down top drive. 14:30 - 17:00 2.50 CEMT N DFAL LNR1 Trip out of hole wI 5" DP. 17:00 - 17:15 0.25 CEMT N DFAL LNR1 Monitor well and change out elevators. 17:15 - 18:15 1.00 CEMT N DFAL LNR1 Trip out of hole wI 4" DP. 18:15 -18:30 0.25 CEMT N DFAL LNR1 Lay down Fas-drill plug setting tool. 18:30 - 18:45 0.25 CEMT N DFAL LNR1 Clear floor. 18:45 - 19:30 0.75 CEMT N DFAL LNR1 PJSM. Rig up wire line. - Clear floor and cellar area. Arm gun. 19:30 - 23:45 4.25 CEMT N DFAL LNR1 RIH wI 5',4.5" HSD, 12 SPF perforation gun. - Tie into SWS Depth Determination Log Dated 29-MA Y -03. - Tag Fas-Drill Plug at 13342' elmd. - Perforate gun from 13259'- 13264' md. Very little weight change. Log off 3 collars. POOH. - At 200', Clear rig floor and cellar area. Surface - All shots fired. 23:45 - 00:00 0.25 CEMT N DFAL LNR1 Rig down wireline. 5/2/2003 00:00 - 01 :00 1.00 CEMT N DFAL LNR1 RD wireline. Bring Tools to Rig fllor. 01 :00 - 01: 15 0.25 CEMT N DFAL LNR1 MU BHA #9 (7" EZ-Drill, running tool, plug catcher sub). 01 :15 - 02:30 1.25 CEMT N DFAL LNR1 RIH wi BHA #9 on 4" DP. 02:30 - 04:00 1.50 CEMT N DFAL LNR1 Change to 5" equipment. Printed: 6/16/2003 2:08:44 PM ") ) BP EXPLORATION, o perationsS urnmaryRe port Page 21 of 32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From- To Hours Task Code NPT Phase Description· of Operations 5/2/2003 02:30 - 04:00 1.50 CEMT N DFAL LNR1 - Break down cement heads. 04:00 - 07:30 3.50 CEMT N DFAL LNR1 RIH wI 5" DP to 11185' - above liner. 07:30 - 08:00 0.50 CEMT N DFAL LNR1 Break circulation prior to entering 7" liner. 08:00 - 09:00 1.00 CEMT N DFAL LNR1 RIH to 13240' md- just above perforations. 09:00 - 09:30 0.50 CEMT N DFAL LNR1 RU Baker Cement Head. 09:30 - 10:00 0.50 CEMT N DFAL LNR1 Break circulation and set HES EZ-Drill at 13210' md. 10:00 - 15:00 5.00 CEMT N DFAL LNR1 Attempt to establish circulation through perforations in 7" linerfrom 13259'-13264' md. - Choose 1100 psi as max pressure not to exceed based on EMW calculations of 14.6 ppg @ top perf (13259' md/10804' tvdrkb) and 14.4 ppg @ 9-5/8" casing shoe (11517' md/9386' tvd rkb). - Perform Pressure Cycles while monitoring bleed pressure as follows: '" Press up to 700 psi & bleed to 300 psi for six cycles (Cycle time improving from 1 0 minutes to 9 minutes) -- very slight sign of returns into flow line. Lined up on trip tank 1 to measure returns. '" Press up to 800 psi & bleed to 300 psi for 6 cycles (cycle time reducing from 9 minutes to 8 minutes) -- extremely slight stream of returns improving with time and resulting in full returns measured in trip tank 1. '" Press up to 900 psi & bleed to 500 psi for 6 cycles (cycle time improved from 7 minutes to 4 minutes) -- returns rate visually improving with full returns measured in trip tank 1. '" Press up to 1 000 psi & bleed to 700 psi for 4 cycles (cycle time improved from 5 minutes to 2 minutes) -- returns rate visually improving with full returns measured in trip tank 1. psig. 15:00 - 15:30 0.50 CEMT N DFAL LNR1 Established circulation while continuing pressure bleed cycles. '" Press up to 1 000 psi & bleed to 800 psi for ten cycles (Cycle time improving from 2 minutes to 1 minute) -- returns rate visually improving with full returns measured in trip tank 1. '" Well started circulating while attempting to increase the pressure to 1100 psi -- broke back and started circulating @ 3 spm (0.25 bpm) with 1020 psi and full retuns. 15:30 - 22:30 7.00 CEMT N DFAL LNR1 Establish circulation. - Initially at 3 spm (0.25 bpm wI 850 psig). - Continued slowly increasing rate in 1 spm increments to 1 bpm into trip tank without any losses. - Switch over to active system pit 1 E. Continued circulating at 1 bpm wI 1060 psig. Slowly increase rate to 1.7 bpm wI 1680 psig. - Increase rate to 1.75 bpm wI 1720 psig and begin to have slight losses (5 bbls in 10 min). Losses quit and pressure reduced to 1600 psig. - Slowly increased rate to 2.1 bpm and developed pack off wI pressure spike to 1760 psig. Back off rate and pressure still trying to climb. Quit pumping and pressure not falling off. Bleed down and attempt to regain circulation 2 times at miminum without getting returns. 22:30 - 23:45 1.25 CEMT N FLUD LNR1 Discussion with core rig team on rig floor to review data leading up to pack off and discuss forward plan. - Decision to Perform Step Rate Test to establish injection rate Printed: 6/16/2003 2:08:44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BPEXPLORATION Operations Summa.ryReport Page 22 of 32 NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Descri ption· of Operations 5/2/2003 22:30 - 23:45 From - To Hours Task Code NPT Phase FLUD LNR1 Date 23:45 - 00:00 5/3/2003 00:00 - 03:15 03:15 - 03:30 03:30 - 04:00 04:00 - 05:00 05:00 - 06: 15 1.25 CEMT N for Pumping Cement Job without returns. Suspected that pack off was occuring at Liner/Hanger/Packer and formation was breaking down @ 9-5/8" casing shoe which had LOT data for 14.4 ppg EMW. - Plan to set balance cement plug on top of EZ drill in event that decision is made to not run cement bond log based on poor results of cement job. - Mud Engineer informed WSL that MW in closed circulating system L Pit and Pit 1 E had lightened to 12.2 ppg. * Approximantely 75 bbls of 12.2 ppg drilling fluid had been circulated into drill string. * Additional light spots ranging from 12.4 to 12.5+ had been circulated. * Good consistent MW in and out would be required to perform forward plan. - Decision to unsting from EZ drill and circulate and condition mud while pumping max acceptable rate of 5.5 bpm through EZ drill setting tool stinger.condition MW back to 12.6 ppg (MW had slipped down 12.1- 12.2 ppg in and 12.3- 12.4 ppg out. Condition surface mud in Pit 1 to 12.6 ppg. Bleed pressure down to 300 psig and sting out of EZ-Drill. Circulate and condition mud while adding barite to achieve consistent MW in = MW out + 12.6 ppg. - Held discussion with Mud Engineers regarding maintaining proper mud weight. Sting out of PKR. - 5.5 bpm wI 850 psig (12.6 ppg = MW in = MW out) Decision made to take single out of string since it is evident that the liner is not going to move downhole this will make cement head LD safer and more efficient regarding dumping 4 bbls of cement on top of EZ Drill. - MU cement head and sting back into EZ Drill Pkr - Set 20 K Ibs on EZ drill. Attempt to establish circulation without success. - Leak off occured at 1350 psig. Perform step rate injectivity test: Rate (SPM) (BPM) PSIA 6 0.5 1440 12 1.0 1510 18 1 .5 1550 24 2.0 1610 30 2.5 1700 36 3.0 1760 42 3.5 1840 48 4.1 1950 54 4.6 2050 60 5.1 2140 *Total bbls pumped 20 bbls. Bleed back 10 bbls. * ISIP= 1370 psig. Held Planning Meeting/PJSM for cementing thru EZ Drill with no returns. - Revised Forward Plan while crews ate lunch. - Moved fluid between rig & G&I in preparation for cement job. 0.25 CEMT N FLUD LNR1 3.25 CEMT N FLUD LNR1 0.25 CEMT N DFAL LNR1 0.50 CEMT N DFAL LNR1 1.00 CEMT N DFAL LNR1 1.25 CEMT N DFAL LNR1 Printed: 6/16/2003 2:08:44 PM ) ) BPEXPLORA TION QperationsSummaryReport Page 23 of 32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From;;. To Hours Task Code NPT. Phase Description of Operations 5/3/2003 06:15 - 06:30 0.25 CEMT N DFAL LNR1 Sting out of EZ-Drill PKR. - Well is static. - Close hydril. 06:30 - 07:30 1.00 CEMT N DFAL LNR1 Pump cement job as per plan while holding back pressure with choke to prevent cement from falling away in drill pipe: 1) Pump 10 bbls sea water. Test lines to 4500 psig. 2) Pump 35 bbls 13.0 ppg Alpha spacer. 3) Mix and pump 85 bbls 15.9 ppg tail cement. 4) Pump 7 bbls of sea water. 5) Drop dart. 07:30 - 08:00 0.50 CEMT N DFAL LNR1 Displace cement wI 89.6 bbls with 12.6 bbls mud. - SD pump and close choke. - Sting into EZ- Drill. - Bleed annulus to 0 psig and open hydril. - Continue displacement with 116 bbls of 12.6 ppg mud. - Good cement lift (4 bpm wI a pressure increase from 1500 psig to 1900 psig). Increase rate to 5 bpm wI 2440 psig at 2430 total strokes. 08:00 - 08:30 0.50 CEMT N DFAL LNR1 Rig down the cement head and single. Rig up on top drive. 08:30 - 11 :30 3.00 CEMT N DFAL LNR1 Circulate hi vis sweep and shear wiper dart out at 2650 psig @ 2493 strokes. - Circulate at 5.5 bpm wI 875 psig while reciprocating 35' without any rotation. 11 :30 - 12:00 0.50 CEMT N DFAL LNR1 Monitor well and pump 3.3 ppg over dry job. 12:00 - 12:30 0.50 CEMT N DFAL LNR1 POOH 4 stds. 12:30 - 00:00 11.50 CEMT N RREP LNR1 Inspect traveling block sheaves. -Find one sheave bad. -Hang blocks and inspect further. Sheave bearing is found to be worn out. - Make plan for repair. Decision made to restring blocks and utililize unused sheave. - Formulate plan and gather tools for job. - Order out e-line string up cable. - Spool on 2600' e-line onto drawworks. Braise to drlling line. - Unstring blocks. 5/4/2003 00:00 - 01 :00 1.00 CEMT N RREP LNR1 Shift change. Review plan for restringing the blocks. Hold PJSM. 01 :00 - 04:00 3.00 CEMT N RREP LNR1 String e-line out of the bad sheave and through the spare @ crown & blocks. 04:00 - 05:30 1.50 CEMT N RREP LNR1 Braise e-line to drilling line. 05:30 - 06:00 0.50 CEMT N RREP LNR1 PJSM for stringing drilling line through sheaves and back onto drum. 06:00 - 07:30 1.50 CEMT N RREP LNR1 String drilling line through all sheaves and back down to drum. 07:30 - 08:30 1.00 CEMT N RREP LNR1 Place wraps on the dead man. Spool of the 2600' of eline. 08:30 - 09:30 1.00 CEMT N RREP LNR1 Secure drilling line on drum. Slip line. 09:30 - 11 :00 1.50 CEMT N RREP LNR1 Unhang blocks, grease sheaves, make several test runs while observing sheaves, secure oil pump prower supply line. 11:00-13:15 2.25 CEMT N DFAL LNR1 POOH wI BHA #9. - D1 Drill. - High winds causing electrical line to top drive oil pump to blow Printed: 6/16/2003 2:08:44 PM ) BP EXPLORATION Operations Summäry Report Page 24 of 32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From- To Hours Task Code NPT Phase Description of Operations 5/4/2003 11 :00 - 13:15 2.25 CEMT N DFAL LNR1 into kelly hoses - creating hazard in that it may get caught and possibly parting.. 13:15 -14:00 0.75 CEMT N MISC LNR1 PJSM. Disconnect eletrical supply line from TD oiler pump. 14:00 - 15:00 1.00 CEMT N DFAL LNR1 POH to 7900' md. Lost dry job- pipe pulling wet. 15:00 -15:15 0.25 CEMT N DFAL LNR1 Pump dry job. 15:15 -16:30 1.25 CEMT N DFAL LNR1 POH wI BHA #9. - Find worn couplings on 5" DP. 16:30 - 17:00 0.50 CEMT N DFAL LNR1 PU cement head. Make service breaks. Lay back down. 17:00 - 18:00 1.00 CEMT N DFAL LNR1 Lay down two worn singles. PU 2 singles from pipeshed. Continue POH to 4" DP. Monitor well and change handling equipment. 18:00 - 19:45 1.75 CEMT N DFAL LNR1 POH wI 4" DP and Lay down EZ-Drill setting tool stinger running assembly. 19:45 - 20:00 0.25 CEMT N DFAL LNR1 Clear and clean floor. 20:00 - 22: 15 2.25 CEMT N DFAL LNR1 MU BHA #10 -- 6" - 6 bladed mill. 22:15 - 23:00 0.75 CEMT N DFAL LNR1 TIH wI 69 jts 4" DP. 23:00 - 00:00 1.00 CEMT N DFAL LNR1 TIH wI BHA #10 on 5" DP. 5/5/2003 00:00 - 02:00 2.00 CEMT N DFAL LNR1 RIH from 5673' - 11275' md Gust above 7" liner top at 11288'). 02:00 - 03:30 1.50 CEMT N DFAL LNR1 Break circulation. MW out= 12.0- 12.2 ppg. Condition MW in= MW out = 12.6 ppg. - Circulation rate 170 spm (14.4 bpm) wI 3200 psig. - While circulating, Rig Electrician reconnecting power supply for TD oiler pump (had been secured during high-winds yesterday). - On btms up some finely ground Kingyak and Sag cuttings came across shakers. 03:30 - 04:15 0.75 CEMT N DFAL LNR1 Attempt casing test. Leak off occured at 800 psig or 14.2 EMW at 9-5/8" shoe. 04:15 - 06:00 1.75 CEMT N DFAL LNR1 Continue RIH wI 13085' md. 06:00 - 06: 15 0.25 CEMT N DFAL LNR1 Wash down to 13207' md. - No cement on plug? 06:15 - 16:30 10.25 CEMT N DFAL LNR1 Mill on EZ Drill Pker fl 13207' md. Chase EZ drill down to 13239' md - Top of cement. Continue to mill on EZ-Drill, Fas-Drill, Landing collar, and Float collar. -- Tag Reamer shoe at 13434'. md. 16:30 - 17:30 1.00 CEMT N DFAL LNR1 Circulate Hi-Vis sweep at 560 gpm wI 3600 psig surface to surface. 17:30 - 18:00 0.50 CEMT N DFAL LNR1 Monitor well. Pump dry job. 18:00 - 22:00 4.00 CEMT N DFAL LNR1 TOH wI 6" milling assembly. - PU Wt off btm 350 K Ibs. - At 13216' md - overpull 60 K Ibs. RIH wI see 10 K bobble down. Pick up through without any trouble. Run stand through area without any trouble. Continue POOH. 22:00 - 23:00 1.00 CEMT N DFAL LNR1 Swap over to 4" equipment. Monitor well. Continue POH. 23:00 - 00:00 1.00 CEMT N DFAL LNR1 Swap over to 3.5" equipment. LD BHA #10. Clear & clean rig floor. -- Good recovery in boot baskets. -- 6" mill somewhat cored in center. 5/6/2003 00:00 - 01 :00 1.00 CEMT N DFAL LNR1 Remove tools from VLE. Spot up E-liner. Load up equipment and sheaves. 01 :00 - 01 :30 0.50 EVAL N DFAL LNR1 PJSM for picking up logging tools. Printed: 6/16/2003 2:08:44 PM ) ) BP EXPLORATION Operatiol1s Summary Report Page 250f32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From- To Hours Task Code NPT Phase Descri ption. of Operations 5/6/2003 01 :30 - 02:30 1.00 EVAL N DFAL LNR1 RU wireline. String e-line. MU & test logging tools. 02:30 - 03:00 0.50 EVAL N HMAN LNR1 Wireline crew that had taken over Unit was not told that counter wheels had not been changed over for bigger line. - Change counter wheels. 03:00 - 15:00 12.00 EVAL N DFAL LNR1 Run #1: Log USIT-CBL across 7" liner. - Place log on Interact system. Log evaluated by Anchorage Engineering (Cumulative total of 87' of cement above Sag). - USIT sonde would not work below 13392' md (Impellar would quit spinning). - Log Primary Depth Control log. - POOH wI USIT. 15:00 - 17:00 2.00 EVAL N DFAL LNR1 Break and lay down logging tools. Bring HALCO Fas Drill BP & running tools to floor. 17:00 - 22:30 5.50 EVAL N DFAL LNR1 Run #2: MU 7" Fas Drill BP. - RIH and tie into Primary Depth Control Log. - Set HALCO 7" Fas Drill BP at 13250' elmd (above squeeze perforations). Log off. RIH and tag Fas Drill. - POOH. 22:30 - 23:00 0.50 EVAL N DFAL LNR1 PJSM. RD wireline. 23:00 - 23:30 0.50 BOPSUR N DFAL LNR1 PJSM. Pull wear bushing. Function rams to dislodge any metal from inside ram cavities befor pull bushing. 23:30 - 00:00 0.50 BOPSUR N DFAL LNR1 PJSM. Drain stack. Rig up to P-Test BOPE to 250 psil 4800 psig. 5/7/2003 00:00 - 04:30 4.50 BOPSUR N DFAL LNR1 Pressure test BOP's 250/4800 psig and Hydril to 3500 psig. Test 4" & 5" floor valves. - AOGCC Rep: J. Crisp waived witness. 04:30 - 05:30 1.00 BOPSUR N DFAL LNR1 Pull test plug. Run wear bushing. RD BOP testing equipment. 05:30 - 06:00 0.50 CEMT N DFAL LNR1 PJSM. Prepare to MU BHA #11. - Adjust IBOP valve while preparing. 06:00 - 07:00 1.00 CEMT N DFAL LNR1 MU BHA #11. - 7 2/5" polish mill, Stop Sub, 9-5/8" casing scraper, and 6 jts of 4" HWDP. 07:00 - 12:00 5.00 CEMT N DFAL LNR1 RIH wI BHA #11 on 4" and 5" DP to 11283' md (just above 7" liner top at 11288' md). 12:00 - 13:30 1.50 CASE N DFAL LNR1 Tag 7" liner top and set 'ZXP' liner top packer. Utilizing wt only no rotation. - Did not see shear with the three attmepts to set. PJSM. Test liner top packer to 3460 psig for 30 mins. 13:30 -16:15 2.75 CASE N DFAL LNR1 Pump dry job. POOH wI 5" DP to 4" DP wI BHA #11. 16:15 -17:00 0.75 CASE N DFAL LNR1 POOH wI 4" DP to BHA #11. 17:00 - 17:30 0.50 CASE N DFAL LNR1 LD BHA #11. 17:30 - 18:00 0.50 CASE P LNR1 Clear and clean rig floor. 18:00 - 18:30 0.50 CASE P LNR1 Service top drive. 18:30 - 20:00 1.50 CASE P LNR1 Slip and cut drilling line and service drawworks. 20:00 - 22:45 2.75 CASE P LNR1 PJSM. MU BHA #12 (6" HTC EP4970 bit, 4.75" PDM SSS- 1.15 deg, ADN4, ARCS, MWD - Slim pulse, PBL Sub) 22:45 - 00:00 1 .25 CASE P LNR1 Change to 4" handling equipment & RIH wI BHA #12. Printed: 6/16/2003 2:08:44 PM ) ) BP EXPLORATION Operatio n55 II mm~ ryReporl: Page 2ßof32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From ~ To Hours Task Code .NPT Phase Description of Operations 5/8/2003 00:00 - 00:30 0.50 CASE P LNR1 RIH wI 4" DP and BHA #12. 00:30 - 06:30 6.00 CASE P LNR1 Change over to 5" equipment and RIH wI 5" x4" DP and BHA #12 (6" bit). - Didn't see any bobbles when entering 7" liner top. 06:30 - 07:30 1.00 CASE N WAIT LNR1 Lost Hi-line power from OPS (Intakes plugging from Hoar Frost-Turbine quit). Fire up rig engines and have Electrician back feed to G & I. 07:30 - 08:00 0.50 CASE P LNR1 Wash down and tag HES 'Fas-drill' BP @ 13229' md -- Drill out Fas-drill. 08:00 - 10:30 2.50 CASE P LNR1 PJSM. Pump 70 bbls Hi-Vis Spacer and displace well to 9.3 ppg mud. 10:30 - 12:00 1.50 CASE P LNR1 Wash down and Tag 7" Reamer Shoe. - Drill shoe fl 13434' to 13436' md. 12:00 - 12:30 0.50 DRILL P PROD1 Drill shoe and rat hole to 13461' md. 12:30 - 14:00 1.50 DRILL P PROD1 Drill 20' new formation 13461'· 13481' md. 14:00 - 14:30 0.50 DRILL P PROD1 FIT test to 1140 psig and leak off occured. -- LOT = 11.35 ppg EMW wI 9.35 ppg MW 14:30 - 00:00 9.50 DRILL P PROD1 Drill ahead 6" production hole from 13481'- 13654' md. Drilling parameters: - ROP from 15 to 60 fph. - WOB= 25 K Ibs, 80 rpm wI 14-15 ft-klbs torque, 90 spm or 320 gpm wI 1800 psig. - ROW= 268 K Ibs, PUW= 305 K Ibs, and SOW= 236 K Ibs. - BHA showing slight dropping trend. 5/9/2003 00:00 - 11 :30 11.50 DRILL P PROD1 Drill ahead 6" production hole fl 13654' - 13981' md (11434' tvd rkb). - Total ROP for run is 34.3 - Final hole Incl. of 28.17 and azimuth of 326.06 degrees. Drilling parameters: - WOB of 25, ROW of 275, PUW of 320, & SOW of 240 K Ibs. - Total flow of 320 gpm wI 1900 psig. - 80 rpm wI 15000 ft-Ibs torque. 11 :30 - 12:00 0.50 DRILL P PROD1 Take final survey and take slow pump rates. 12:00 - 16:00 4.00 DRILL P PROD1 MADD pass fl TD to 7" shoe @ 150 fph. 16:00 - 17:30 1.50 DRILL P PROD1 Wipe hole back to 13,480 ft. Hole slick. Monitor well. POOH to 11576' md which places PBL sub (2-ported) 100' below 7" liner top at 11288'. 17:30 - 19:30 2.00 DRILL P PROD1 Drop PBL opening ball. Pump sweep. Chase sweep staging pumps up to 18 bpm. - Hole is clean - drop PBL closing ball. . Flowcheck well. 19:30 - 22:30 3.00 DRILL P PROD1 Pump dry job. Drop rabbit into Std #90. POH wI 5" DP to 4" DP. 22:30 - 23:30 1.00 DRILL P PROD1 Monitor well while changing over to 4" handling equipment. - POOH to 4" HWDP. 23:30 - 00:00 0.50 DRILL P PROD1 LD 4" HWDP. 5/10/2003 00:00 - 03:00 3.00 DRILL P PROD1 Lay down BHA #12. - Down load data. - Bit graded 4-8-BT-G-E-1-WT-TD. 03:00 - 03:30 0.50 CASE P COMP PJSM for rigging up to run 4.5",12.6 ppf, L-80 liner, Vam-ace threads with 2.875" inner string. Printed: 6/16/2003 2:08:44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 5/10/2003 5/11/2003 Date ) ) . BP EXPLORATION Operations .Summary.·Report NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Page 27 of 32 Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: From - To Hours Task Code NPT Phase Description of Operations 03:30 - 04:00 04:00 - 11 :00 0.50 CASE P 7.00 CASE P COMP COMP 11 : 00 - 11: 30 0.50 CASE P COMP 11:30-12:30 1.00 CASE P COMP 12:30 - 14:00 1.50 CASE P COMP 14:00 - 19:30 5.50 CASE P COMP 19:30 - 21 :00 1.50 CASE P COMP 21 :00 - 22:00 1.00 CASE P COMP 22:00 - 23:00 1.00 CASE P COMP 23:00 - 00:00 1.00 CASE P COMP 00:00 - 00:30 00:30 - 02:00 02:00 - 04:00 0.50 CEMT P COMP 1.50 CEMT N FLUD COMP 2.00 CEMT P COMP RU to run liner. MU float equipment. - 7' of shoe track. Check floats. - Run 19' jts of 4.5", 12.6#, L-80, Vam-ace Liner. - Torque turn each jt which had 2x RHT and stop rings. - Stop short of filling liner with 9.3 ppg viscosified pill. MU up and run 25 jts and 6' pup jt of 2.875" fox inner string, space out 4.5 ft above LC. - Fill up 2.875" x 4.5" annulus with 9.3 ppg viscosified pill. - MU Baker liner hanger - 'ZXP' liner top pkr assembly. - Mix up and add Pal mix. Let mix set up for 1/2 hour. RD casing running equipment. RU to TIH wI drill pipe and to fill string volume after making up 1 st stand of DP. RIH wI 4.5" liner on 4" DP, filling after 10 stds. RIH wI 4.5" liner on 5" DP to top of 7" liner. RIH w/ 4.5" liner through 7" liner to the 7" shoe. - Didn't see the liner top. Circulate String Volume at 7" shoe. - PUW= 314 K and SOW= 235 K Ibs at shoe. RIH wI 4.5" liner into open hole to 13975' md without any problems. MU cement head and cement manifold. - RIH to 13980' md- touch down on fill. - Break circulation at 0.5 bpm and stage up rate in 0.5 bpm increments to 1.5 bpm by midnight. PJSM for cement job. - Staged up circulation rate to 5.5 bpm wI 1175 psig. Operations needs injection well for produced water injection. - They need 1 hour+ to inject produced water every 6 hrs. ** Lessoned Learned** - better communication with operations before large disposal operations (cement jobs and displacements). Pump cement job as per plan: 1) Mix & pump 5 bbls 10.5 ppg Alpha Spacer. SI & pressure test lines to 4500 psig. 2) Break circulation and pump remainder of Spacer for a total volume of 25 bbls. 3) Mix and pump 32 bbls (120 sxs) of 15.9 ppg Class 'G' cement. 4) Close valve on cement head. Wash up cement lines. Precharge cement line with 9.3 ppg viscosified NACL brine pill. 5) Drop wiper dart plug & flush with 15 bbls of viscosified brine. 6) Switch to 9.3 ppg mud and displace at 5.5 bpm. Have good cement lift as spacer and cement come around the shoe. Final rate before bump was 5.2 bpm at 1700 psig. Latch and bump pressure to 2800 psig. Bumped wI pump efficiency of 96.2% (HALCO meter reading 210 bbls). 7) Slack off 30 K Ibs and set hanger. 8) Bleed off to zero and check floats holding. 9) Pressure up to 4000 psig to release 'HRD' running tool and Printed: 6/16/2003 2:08:44 PM ) ') BP EXPLORATION Ope rati 0 I1sSul11maryRø port Page 28of32 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From ~ To Hours Task Code NPT Phase Description of Operations 5/11/2003 02:00 - 04:00 2.00 CEMT P COMP bleed back to 0 psig. 10) PU to string weight (317 K) plus 7' to expose packer setting dogs. Slack off 50 K Ibs and set 'ZXP' liner top packer. Repeat sequence twice once without and once with rotation. Good surface indication of pkr setting. 11) Pressure up to 1000 psig and PU 15' over string weight. When pressure loss detected broke circulation and pumped max rate to clean off cement from liner top. 04:00 - 06:15 2.25 CEMT P COMP Circulate out estimated 12 bbls of excess cement. 06:15 - 06:30 0.25 CEMT P COMP SI hyril and pressure up to test Liner Top Pkr to 1500 psig for 10 mins. - Begin circulation again while preparing for caustic washl sea water displacement. -- Notified control room to pump down produced water. 06:30 - 07:00 0.50 CEMT P COMP PJSM for casing washl sea water displacement. - Addressed proper PPE and precautions for pumping Dirt Magnet and Caustic wash. - Slacked off 5' for 2.875 inner string placement at 13958' md. 07:00 - 07:30 0.50 CEMT P COMP Clean Pits 1 D and 1 E. Mix 70 bbls of caustic wash and 50 bbls of Dirt Magnet. 07:30 - 10:30 3.00 CEMT P COMP Pump Casing Washl Sea Water Displacement as per plan: 1) Flush both pumps 1 & 2. 2) Follow with 75 bbls caustic wash and then 50 bbls of Dirt Magnet wash. 3) Pump 75 bbls of hi-vis spacer. 4) Follow with sea water at 14 bpm. 5) Didn't reciprocate until washes and sea water turned corner. At that time picked up string 12' and reciprocated pipe. 6) Final NTU value of 78 after 140% of hole volume pumped. 10:30 - 11 :00 0.50 CEMT P COMP Monitor well for 1/2 hour (negitive test). 11 :00 - 12:00 1.00 CEMT P COMP Lay down cement head. 12:00 - 20:30 8.50 CEMT P COMP POH wI 'HRD' running tool wI inner string. - Lay down worst 150 single joints of 5" DP for inspection. 20:30 - 21 :00 0.50 CEMT P COMP PU cement head from pipe shed. Make service breaks and lay back down. 21 :00 - 23:00 2.00 CEMT P COMP Swap to 4" handling equipment and POH wI 4" DP. 23:00 - 23:30 0.50 CEMT P COMP PJSM. Lay down 'HRD' liner running tool. - Indication of good set on 'ZXP' liner top pkr. 23:30 - 00:00 0.50 CEMT P COMP LD 2.875" Fox inner string. 5/12/2003 00:00 - 02:00 2.00 CEMT P COMP LD inner string -2.875" Fox tubing. 02:00 - 02:30 0.50 CEMT P COMP RD tubing tongs and clear floor. 02:30 - 03:00 0.50 CEMT P COMP Pressure test csg to 4370 psig wI 13 bbls of sea water. -Record test on chart for 30 mins. 03:00 - 04:30 1.50 TA P SURE Blow down all lines. Pump out BOP stack. Change annulus sweeps from drilling to production. 04:30 - 05:30 1.00 TA P SURE RIH wI 30 stands of 5" DP. 05:30 - 06:00 0.50 TA P SURE RU to freeze protect well with diesel for suspension. 06:00 - 06:30 0.50 TA P SURE PJSM for pumping freeze protect operation. 06:30 - 09:00 2.50 TA P SURE Reverse circulate 125 bbls of warm diesel into 9.625 x 5" DP Printed: 6/16/2003 2:08:44 PM ) ) BPEXPLORATION Ope ratiönsSu rnmaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Date From-To Hours Task Code NPT Phase 5/12/2003 06:30 - 09:00 2.50 TA P SURE 09:00 - 10:00 1.00 TA P SURE 10:00 - 10:30 0.50 TA P SURE 10:30 - 11 :30 1.00 TA P SURE 11 :30 - 12:00 0.50 WHSUR P SURE 12:00 - 12:30 0.50 WHSUR P SURE 12:30 - 14:30 2.00 WHSUR P SURE 14:30 -17:30 3.00 WHSUR P SURE 17:30 - 20:30 3.00 WHSUR P SURE 20:30 - 23:00 2.50 WHSUR P SURE 23:00 - 00:00 1.00 WHSUR P SURE 6/4/2003 00:00 - 00:30 0.50 MOB P SURE 00:30 - 02:30 2.00 MOB P SURE 02:30 - 03:30 1.00 MOB P SURE 03:30 - 04:00 0.50 MOB P SURE 04:00 - 05:00 1.00 BOPSUR P SURE 05:00 - 09:00 4.00 BOPSURP SURE 09:00 - 10:30 1.50 BOPSURP SURE 10:30 - 17:00 6.50 BOPSUR P SURE 17:00 - 18:00 1.00 RUNCOI\1P SURE 18:00 - 19:00 19:00 - 20:00 1.00 RUNCOI\1P 1.00 RUNCOI\1P SURE SURE 20:00 - 23:00 3.00 RUNCOI\1P SURE Page 29 of 32 Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Description ofOperatibns annulus. U-tube diesel. RD diesel lines. POOH wI 5" DP. PJSM. Pull wear bushing. PJSM. Install hanger with 2-way check. RILDS. - Pressure teste seals to 6500 psig. PJSM. Fill voild below hanger & pump into annulus teste 2-way check to 4200 psig fl 5 mins. Bleed off and blow down lines to trip tank. Pull Master bushings, clean drip pan, RU cellar pump and pump out stack, bleed off Koomey system, disconnect lines, and disconnect choke hose. Disconnect turn buckles, pull the mouse hole, ND the flow risers, and remove bolts from the BOP stack. PJSM for lifting BOP stack while Operations is shutting in NS 24. Pick up BOP stack and place on BOP pedestal. Secure BOP stack. PJSM. NU and pressure test dry hole tree to 4800 psig. Clear cellar area. Prep outside for rig move. Work on rig move checklist. Forklift driver and Roustabouts complete loading pipeshed with 1 row of 5" DP (Thaw out). »»»(Release Rig at 0001 hrs on 5/13/2003)«««< PJSM wI oncoming crew. - Nightshift review Pre-move checklist and ATP -- 360 degree walk around. Move rig to NS23. - Operations SI NS24 and put on production well NS19. Shim and level rig. Berm rig and set walkways. «««« (ACCEPT RIG @ 0400 Hrs on 6/4/2003) »»»»> ND dry hole tree and set BOP's. - Give operations NS24 and NS22 back to put on production. NU BOP's. Pull 7" hanger wI TWC. Install Test Plug. RU to test BOP's. - Fill stack and check for leaks. Pressure test BOP's to 250/4800 psig and annular to 3500 psig. - Tested 4.5", 5", and 7". Pull test plug and install wear ring. - RD BOP testing equipment. PJSM. Slip and cut drilling line. RIH wI 4" DP to 1900' md below diesel FP level at 1766' md (125 bbls). - RU to displace diesel. - PJSM for displacement to sea water. PJSM for displacing well to sea water. Printed: 6/16/2003 2:08:44 PM ') ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/4/2003 6/5/2003 6/6/2003 NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E From - To Hours Task Code NPT Phase 20:00 - 23:00 3.00 RUNCOrvP SURE 23:00 - 00:00 1.00 RUNCOrvP SURE 00:00 - 02:00 2.00 RUNCOrvP SURE 02:00 - 04:30 2.50 RUNCOrvP SURE 04:30 - 05:30 1.00 RUNCOrvP SURE 05:30 - 10:30 5.00 RUNCOrvP SURE 10:30 - 12:00 1.50 RUNCOrvP SURE 12:00 - 12:30 0.50 RUNCOrvP SURE 12:30 - 13:30 1.00 RUNCOrvP SURE 13:30 - 15:30 2.00 RUNCOrvP SURE 15:30 - 20:30 5.00 RUNCOrvP SURE 20:30 - 21:15 0.75 RUNCOrvP SURE 21 :15 - 22:00 0.75 RUNCOrvP SURE 22:00 - 22:30 0.50 RUNCOrvP COMP 22:30 - 00:00 1.50 RUNCOrvP COMP 00:00 - 13:30 13.50 RUNCOrvP COMP 13:30 - 19:30 6.00 RUNCOrvP COMP 19:30 - 21 :00 1.50 RUNCOrvP COMP 21 :00 - 23:00 2.00 RUNCOrvP COMP Page 30 of32 Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Descri ptionof· Operations - ACS had no benzene level at trip tank on displacement. Continue RIH wI 4" DP (32 stands total). - Swap over to 5" DP. RIH wI 4" x5" DP. Reverse circulate hot sea water. Pressure test 9-5/8" x 7" x 4-1/2" wellbore to 4370 psig for 30 mins. TOH and LD singles (239 Jts of 5" DP). RIH to 6855' wI 5" DP. Lubricate rig. Continue RIH wI 5" DP from derrick. Rig up and reverse circulate heated sea water. TOH and LD singles (241 jts of 5") Swap over to 4" equip & continue to POH wI 4" DP (LD 30 jts). POH and stand back 22 stands of 4" DP (These will be used to displace diesel from NS16). PJSM and pull wear bushing. Load pipe shed with 7" 32#, T-95, Vam Top HC, tubing. - One row already prepared in pipeshed. Load pipeshed with 7" and 4.5" tubing. - 297 jts of 7" 32#, T-95, Vam Top HC - 5 jts of 4.5" 18.9#, 13CR-95, Vam Top - 40 jts of 18.9#, L-80, Vam Top HC - drift, strap, and clean threads. - RU floor for Torque turning and Gatorhawk testing. - PJSM for running completion. Run the following: 1) 4.5" Tailpipe Assembly: a) 4.5" Self- Aligning Muleshoe WLEG (3.85" ID); b) 4.5" 18.9#, L-80, XO Pup jt (Vam Top HC box x 8 rd pin); c) HES 4.5" 'RN' nipple (3.437" packing borel 3.265" ID) wI RHC-M plug installed. d) 4.5" 18.9#, L-80, Vam Top HC, Pup jt; e) HES 4.5" 'R' Nipple (3.437" packing bore/3.437" ID); f) 4.5" 18.9#, L-80, Vam Top HC, Pup jt. 2) Baker 7" x 4.5" 'S-3' Permanent Pkr assembly (Baker lock connection). 3) MU HES 4.5" 'R' Nipple Assembly. 4) Run 40 jts 4.5", 18.9#, L-80, Vam Top HC tubing a) MU torque 8700 ft-Ibs (Shoulder fl 17-2000 ft-Ibs). b) Gatorhawk testing each connection to 6500 psig. 5) MU 4.5" Vam Top box x Vam Top HC XO. a) Gatorhawk test connection to 6500 psig. 6) Run 5 jts 4.5", 18.9#, T-95, Vam Top. a) MU torque 9400 ft-Ibs. b) Gatorhawk test all connections to 6500 psig. Change over to 7" equipment from 4.5". MU 7" X 4.5" XO (Vam Top HC box x Vam Top Pin. Run jts 1-10 of 1",32#, T-95, Vam Top HC tubing. a) MU torque 17700 ft-Ibs. b) Gatorhawk each connection to 6500 psig. Printed: 6/16/2003 2:08:44 PM ) ) BP EXPLORATION Operations ·Su.111 mary Réport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Date From - To Hours Task Code NPT Phase 6/6/2003 23:00 - 23:30 23:30 - 00:00 0.50 RUNCOI\.If\J 0.50 RUNCOrvP SFAL COMP COMP 6/7/2003 00:00 - 02:30 2.50 RUNCOrvP COMP 02:30 - 03: 15 03:15 - 05:30 0.75 RUNCOI\.If\J 2.25 RUNCOrvP COMP COMP 05:30 - 06:00 0.50 RUNCOrvP COMP 06:00 - 12:00 6.00 RUNCOrvP COMP 12:00 - 12:30 0.50 RUNCOrvP COMP 12:30 - 19:15 6.75 RUNCOrvP COMP 19:15 - 21:30 2.25 RUNCOI\.If\J COMP 21 :30 - 23:30 2.00 RUNCOrvP COMP 23:30 - 00:00 0.50 RUNCOrvP COMP 6/8/2003 00:00 - 05:30 5.50 RUNCOrvP COMP 05:30 - 07:00 1.50 RUNCOrvP COMP 07:00 - 13:00 6.00 RUNCOrvP COMP 13:00 - 14:45 1.75 RUNCOrvP COMP 14:45 - 15:45 1.00 RUNCOrvP COMP 15:45 - 16:30 0.75 RUNCOrvP COMP 16:30 -19:00 2.50 RUNCOrvP COMP 19:00 - 20:00 1.00 RUNCOrvP COMP Page 31 of 32 Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Description of Operations Repair Gatorhawk pressure transducer. Run jts 11-16 of 7",32#, T-95, Vam Top HC tubing. a) MU torque 17700 ft-Ibs. b) Gatorhawk each connection to 6500 psig. Run 7" 32#, T-95, Vam Top HC tubing from Jt #17 to Jt #32. - MU torque 17700 ft-Ibs - 'Gator Hawk' testing each connection to 6500 psig. 'Gator Hawk' repairing leak on testing unit. Run 7" 32#, T-95, Vam Top HC tubing from Jt #32 to Jt #47. - MU torque 17700 ft-Ibs -'Gator Hawk' testing connections to 6500 psig. - No rejected joints. Break for lunch. Run 7" 32#, T-95, Vam Top HC tubing from Jt #48 to Jt #103. - MU torque 17700 ft-Ibs - 'Gator Hawk' testing each connection to 6500 psig. Lubricate the rig. Run 7" 32#, T-95, Vam Top HC tubing from Jt #104 to Jt #167. - MU torque 17700 ft-Ibs - 'Gator Hawk' testing each connection to 6500 psig. 'Gator Hawk' Transducer not working. Troubleshoot. Wake up electrician. Find replacement transducer. - Decide to use old system. Run 7" 32#, T-95, Vam Top HC tubing from Jt #168 to Jt# 194 - No rejections. Change out elevators 125 T YC to 200 T spiders. Run 7" 32#, T-95, Vam Top HC pipe from Jt #195 to #222. - MU Torque from 17.2- 17.7 K ft-Ibs. - Gator Hawk testing each connection to 6500 psig. MU 7" HES "HRQ" SVLN wI Dummy SSSV installed. - MU and test control lines to 6000 psig. - Run Jt #223 (Did not like the exposure to pinch points for the person handling the contollines or for the control lines themselves) . - RU control lines to spool from the Driller's side- much better. Run 7" 32#, T-95, Vam Top HC tubing from Jt #224- #274. - MU Torque from 17.2-17.7 K ft-Ibs. - Gator Hawk testing each connection to 6500 psig. - Installing control line clamps on each connection (52 total). Space out. - MU Jt #275. RIH & see Self-aligning mule shoe roll off 4.5" liner top and continue to tie-back bottom (Tag was 18' in on #275). - LD #275,274, & 273. - MU and Gator Hawk test 7.77' Space out pup. - MU #273. MU Hanger and Landing joint. -Terminate SCSSV control lines. - Hanging weight 430 K Ibs. Land Hanger. RILDS. Test Hanger body seals to 6500 psig. RU lines for pumping diesel, packer setting, and testing. Reverse circulate 5 bbls sea water to verify pathway. - Pressure test lines to 1500 psig. Printed: 6/16/2003 2:08:44 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') " BPEXPLORATION Operations" Summary . R~port NS23 NS23 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Page 32 Of 32 Start: 3/31/2003 Rig Release: 6/9/2003 Rig Number: 33E Spud Date: 4/1/2003 End: Date From -To Hours Task Code NPT Phase 6/8/2003 19:00 - 20:00 1.00 RUNCOrvP COMP 20:00 - 00:00 4.00 RUNCOrvP COMP 6/9/2003 00:00 - 01 :30 01 :30 - 05:30 05:30 - 06:00 06:00 - 07:00 07:00 - 09:00 1.50 RUNCOrvP COMP 4.00 RUNCOrvP COMP 0.50 RUNCOrvP 1.00 RUNCOrvP 2.00 RUNCOrvP COMP COMP COMP 09:00 - 10:30 1.50 RUNCOrvP COMP 10:30 - 11 :00 0.50 BOPSUR P COMP 11 :00 - 11 :30 0.50 BOPSUR P COMP 11 :30 - 12:00 0.50 BOPSUR P COMP 12:00 - 13:00 1.00 BOPSURP COMP 13:00 - 15:30 2.50 BOPSUR P COMP 15:30 -18:00 2.50 WHSUR P COMP Description of Operations - PJSM for pumping corrosion inhibited sea water and diesel. 1) Reverse circulate 25 bbls of sea water wI 2 drums of corrosion inhibitor(EC 1124A) in it. 2) Follow with 30 bbls of filtered SW. 3) Follow with diesel wI 2 drums of corr inhib (EC 1206 A). At midnight 260 bbls I 280 bbls total diesel reversed. - All volumes were verified with G & I pit strap and with HALCO meter. Finish reversing 280 bbls of diesel for FP. - Verify volumes with G & I strap - within 5 bbls. - Switch to filtered sea water to flush mud pump. - Isolate mud pump. Allow diesel to U-tube. - Starting Inner Annulus pressure 900 psig. - Monitor U-tube through HALCO meter. - Hold back U-tube rate to under 3 bpm. - PJSM for Pressure Testing lines wI HALCO. Pressure test surface lines with HALCO to 6000 psig. Drop 1-5/16" ball and rod. Pressure up and set Baker 'S-3' Packer and continue to pressure up to 5800 psig with HALCO (Inner annulus valve open). - Pressure leaking off slowly. Cross-over to Landing joint begin to drip. Bleed off pressure and tighten connection with rig tongs. - Pressure up on tubing to 5800 psig with HALCO - Lost 300 psig in 30 mins. No fluid coming off the open inner annulus. Good test. - Bleed off to 2000 psig and conduct MIT on Inner Annulus to 5800 psig for 30 mins - Good test. « AOGCC REP, Chuck Sheave, waived witnessing MIT»> Rig down pressure testing manifold after flushing with sea water and blowing down lines. Pump out BOP stack with lock down screw adapter. Set TWC. PJSM for ND BOP's. Change out lower rams to 2-7/8" x 5" variables. ND BOPE. - Change to drilling bails and build up NS-16 cellar with 3" x12's. Terminate control lines, NU dry hole tree cap flange, clean cellar area, and continue with rig move check list. «««<RELEASE RIG AT 1800 HRS ON 5/9/2003»»»»> PJSM for Rig Move to NS16. Printed: 6/16/2003 2:08:44 PM ) ) Well: Field: API: Permit: Date NS23i Northstar Unit 50-029-23146-00 203-050 Accept: Spud: Release: Rig: 04/01/03 04/02/03 06/09/03 Nabors 33E POST RIG WORK 06/15/03 RIG UP TO PULL DSSSV, B&R, RHC AND MAKE DRIFT. PULLED DSSSV AND COULD NOT GET IT THROUGH THE TUBING HANGER. PROBLEM IS AT THE BOTTOM OF THE TUBING HANGER. RIH TO SSSVN AND SHEARED OFF AND LEFT DSSSV AT 21141 SLM. PUMP ALL THE FLUIDS OUT OF TREE. TRIED TO RUN THE RIG DRIFT (RABBIT) WITH 3.969" O.D.DOWN THROUGH TUBING HANGER, BUT IT STOPS AT THE BOTTOM OF THE TUBING HANGER. CANNOT WORK DRIFT THROUGH. MADE SEVERAL ATTEMPTS WITH DIFFERANT SIZE DRIFTS AND DETERMINED THAT A 5.930" 0.0. CENT. WILL NOT GO THROUGH. A 5.81" 0.0. CENTRALIZER WILL GO TROUGH WITHOUT ANY PROBLEMS. 06/17/03 SET PR PLUG IN R NIPPLE AT 13,0391 SLM (NOTE: PRONG IS 60" X 1 7/8" WITH 1 3/4" FISHING NECK) . 06/20/03 PULLED DUMMY SSSV, PLUG IN R NIPPLE, RHC PLUG AND DRIFTED TO 13,9291 WITH 2 7/8" DUMMY GUN AND SAMPLE BAILER TO TO, POOH WITH SAMPLE. 06/21/03 RIG UP E-LlNE AND RAN PRIMARY DEPTH CONTROL LOG, GR-CCL (PBMS) FROM TD TO SURFACE TO GET GOOD GR DEFINITION. 06/22/03 RAN 2 718" HSD, 6SPF, 2906PJ HMX, PERFORATE INTERVAL (13,808.51 - 13,868.51) INTERVAL WAS ADJUSTED FROM THE ONE PICKED FROM LWD 7-MAY-03 06/23/03 RAN 2 718" HSD, 6SPF, 2906PJ HMX, SHOOT INTERVAL (13808.5 - 13746.51), RUNS 4,5,6 06/24/03 RAN 2 7/8" HSD, 6SPF, 2906PJ HMX, SHOOT INTERVAL (136881 - 137481 = 601), RUNS 7,8,9 COMPLETED 06/25/03 27/8 HSD, 6SPF, 2906PJ HMX, INTERVAL (13628.51-13868.5'), RUNS 10,11,12 06/26/03 RIH WI 2.80" CENT AND PETREDAT MEM GAUGES AND CONDUCT STATIC BHP SURVEY. RUN 7" FXE SCSSV TO 7' WHERE VALVE BECAME HUNG UP. JAR VALVE FREE AFTER 30 MINUTES. VALVE HAS MARK ON 6.03" 00 NO-GO RING AND THE PACKING STACKS WERE DAMAGED. RECENT HANGER BORING OPERATION -- MAY STILL HAVE RESTRICTION. ) ") NS23i Page 2 06/29/03 MIRU SWS. SET 4.5" "PR" PLUG IN BOTTOM "R" LN @ 130821 WLM. SET CENTRALIZED PRONG IN SAME. BLEED OFF WHP FROM 650 TO 350 PSI. MONITOR 1 HR- GOOD PLUG SET. RIH WI 2ND 4.5" "PR" PLUG AND SET IN "R" LN @ 130431 WLM. SET CENTRALIZED PRONG IN SAME. BLEED OFF WHP FROM 350 PSIG TO o. GOOD PLUG SET. MONITOR WELL. SET T' PR PLUG IN "HRQ" SVLN @ 21161 WLM. SET CENTRALIZED PRONG AFTER TWO ATTEMPTS IN SAME. START TESTING PLUG WHILE MONITORING CONTROL LINE PRESSURE UNDER PLUG. 06/30/03 PT ON TOP OF 1'1 "PR" PLUG TO 500 PSIG WHILE MONITORING CONTROL LINE PRESSURE. GOOD TEST ON PLUG. BLEED OFF TO O. RDMO. OPERATOR TO CONTINUE BLEEDING OFF TUBING TO 0 PSIG. 07/01/03 WELL SAFED OUT WITH THREE PLUGS. PULL TREE AND STAND BACK. MACHINE OUT HANGER AND PUP JT WITH BORING TOOL TO 6.075" ID. STARTING ID WAS 6.01811 WITH ROUGH SURFACE. CARBIDE BLADE WAS USED. FOUR CUTS TOTAL WERE MADE. 07/02103 PULLED ALL THREE PLUGS AND SET 7'1 FXE (SER# NS-04) GOOD CLOSURE TEST (NOTE: HAD TO TAKE OFF NO GO RING ON FXE DUE TO NOT BEING ABLE TO GET PAST 31 PUP BELOW TBG HANGER) 07/13/03 SI WELL WI 2.28" CENT AND 1.75" SAMPLE BAILER. TAG TD @ 139121 SLM. POH. RIH WI SWS MEMORY PSP. BRING ON WELL TO 28 MMSCFD AFTER RUNNING THROUGH IFXE1 SCSSV. STOP AT 129001 AND ALLOW WELL TO STABILIZE. LOG 40, 60, 80 FPM SPINNER PASSES. OPEN UP CHOKE TO FOC AND ALLOW WELL TO STABILIZE AT 44 MMSCFD. LOG BASELINE TEMPERATURE PASS FROM 13900-129001 SLM. LOG 40, 60, & 80 FPM SPINNER PASSES. STOP AT 136621. SI WELL AND MONITOR FALL OFF FOR 2 HRS. LOG 2 WARM BACK PASSES FROM 139001 TO 129001. POOH. DOWN LOAD MEM TOOLS - GOOD DATA. RD. Legal Name: Common Name: Test Date 4/7/2003 4/22/2003 5/812003 FIT FIT LOT NS23 NS23 Test Type Test Depth (TMD) 3,708.0 (ft) 11,558.0 (ft) 13,434.0 (ft) BPEXPI..0RATION Lea·k-Off·.Test·.··SUl11mêlfy Test Depth (TVD) 3,222.6 (ft) 9,419.0 (ft) 10,958.0 (ft) AMW 8.70 (ppg) 12.60 (ppg) 9.35 (ppg) SurfacePtesslIrê 635 (psi) 800 (psi) 1,140 (psi) Lèák()ffprêS$lI,.~('ªHP) 2,091 (psi) 6,965 (psi) 6,462 (psi) EMW 12.49 (ppg) 14.23 (ppg) 11.35 (ppg) ---" ...---./~ Printed: 6/16/2003 2:08:37 PM TREE::; WELLHEAD::; ÄcïiJÄrÓR;;;; kËLï~ï.:: ËV"';' BF. ELEV = KOP::; Max Angle ::; ba turn rvD :; batÙnÏÏŸó"; FI'vC CtN .. ï3Äï<ER(j ·····sïL4iii' ? 6548' 99 @ 9993' 9231' .... .. 'sii6öï'ss ) 15-48A SAFErYNOTES: HORIZ. WELL GOES 70o@ 9348' e'" '<,.J ,,", 2184' 1-1 4-1/2" HES HXOSVLN SSSV NIP, D ::;3.813" ~ GAS LIFT MANDRELS ST MD TVD DEV ìYÆ VLV LATCH PORT DATE 1* 3677 3674 1 DOrvE INT 16 03/06/03 2* 6288 6285 5 S/O INT 20 03/06/03 3* 8237 8060 33 DU'v1MY INT 0 * MANDRELS REQUIRE MODIFIIÐ LATCH 9-5/8" CSG, 40#, L-80, D ::; 8.835" l-i 3548' ¡-AI Minimum ID = 2.225" @ 6779' 4-1/2" EC LlPSE TBG P ATC H 14-1/2" TBG, 12.6#, L-80, .0152 bpf, D::; 3.958" 1--1 1 TOP OF 4-1/2' LNR H 8341' 8341' :8: L N :&--f 8306' 1-1 7" X 4-1/2' BAKffi 5-3 PKR 1 6779' 1-14-1/2' EQIFSETBG PATa; (03/13/03), D::; 2.225" I 8329' 1--1 4-1/2"HESXNIP, ID=3.813" 1 ~ 1 ~ ~ ~ 1--1 4-1/2" TLBING TAIL WLEG 1 1-1 ELMDTTLOGGBJ 06/07/97 1 l-i 7" x 4-1/2' TtN LNR PKR & HY DRO HGR 1 8341 ' 8347' 8341' 7" CSG, 26#, L-80, ID = 6.276" H 8554' ----A .. PERFORA~ONSUMMARY REF LOG: SWS MGR/CQ/QlJL ON 02/19/03 ANGLE AT TOP PERF: 88° @ 10360' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10360 - 10380 0 02/20/03 2" 4 10450 - 10490 0 02/20/03 2" 4 10520 - 10570 0 02/20/03 2" 4 10610 - 10660 0 02/20/03 2" 4 10750 - 10890 0 02/20103 2" 4 10980 - 11800 0 02/20103 WHIPSTOCK 1-1 I RA TAG l-t 1 CIBP 1-1 9901' 9908' 10050' 14-1/2' LNR, 12.6#, L-80, .0152 bpf, ID= 3.958" 1--1 11390' DATE REV BY COrvMEl'JTS 01/28/96 ORIGINAL COrvPLEfION 02/23/03 JUvVKK CTD S IDETRA 0< (15-48A) 03/06/03 JUvVTP 00 GLV'S 03/18/03 PW6'TLH SEfTBG PA Ta; ~¿ I 1 1 9379' l-i 4-1 12" BKR LNR TOP PKR, ID = 2.56" 1 9397' 1--13.75" BKR DEPLOYMENT SLY, ID= 3.0" 9397' I-iTOP OF CEM ENT I 9416' 1--13-1/2' HOWCOXN NIP,ID = 2.750" I 9418' 1-13-1/2" X 3-3116" XO, ID = 2.880" 1 I\t1ILLOUT WINDOW 9890 '- 9896' WHIFSTOCK - 9901' RA TAG - 9908' 1-i3-3/16" X 2-718" XO,ID=2.372" 1 ~ ~ -, ~~I 2-718"LNR,6.16#,L-80,.0055bpf,D=2.372" 1-1 11843' OA. TE REV BY COMtv'ENTS PRUDHOE BAY LNIT WELL: 15-48A PffiMT I\b: 2030050 APII\b: 50-029-22635-01 SEC 22, T11 N, R14E, 2967.84' ÆL & 1006.73' FNL BP Exploration (Alaska) ) MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Well No W-23A Date Dispatche Installation/Rig Nabors 9ES Dispatched By: Data ) &O~3 -05ê) Lisa Weepie 22-Apr-03 Nate Rose No Of Prints No of Floppies Surveys 2 RECEIVEC JUN 1 3 2003 Alaska Oif & Ges Cons. CommiMion Received By: ~C~ ~~, O'i ,h Œ:>JV\ LWD Log Delivery V1.1 Dee '97 '~~~'I~S Please sign and return t~,.. Anadrill LWD Division .If'' 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 ANADRILL SCHLUMBERGER Survey report 9-May-2003 16:55:01 Client............ .......: BP Exploration (Alaska) Inc Field....................: Northstar Well.....................: NS23i API number........... ....: 50-029-23146-00 Engineer.............. ...: Leafstedt Spud date.. '" ..... ......: Last survey date... ......: Total accepted surveys...: MD of first survey.. .....: MD of last survey.. ......: RIG:.....................: Nabors 33E STATE:...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS.... ... ....: Mason & Taylor 803-- OE:;ð Page 1 of 7 01-Apr-03 09-May-03 153 0.00 ft 13981.00 ft -' ----- Geomagnetic data ---------------------- Magnetic model..... ......: BGGM version 2002 Magnetic date...... ......: 01-Apr-2003 Magnetic field strength..: 1151.06 HCNT Magnetic dec (+E/W-). ....: 26.01 degrees Magnetic dip......... ....: 80.95 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 26.01 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 26.01 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N). .... ...: No degree: 0.00 ----- Depth reference ----------------------- Permanent datum...... ....: Mean Sea Level Depth reference...... ....: Driller's Pipe Tally GL above permanent... ....: 15.90 ft KB above permanent.... ...: na DF above permanent.... ...: 56.55 ft ----- MWD survey Reference Reference G.. ... ... ......: Reference H..... ... ......: Reference Dip............: Tolerance of G.. ... ......: Tolerance of H...... .....: Tolerance of Dip...... ...: ----- Vertical section origin---------------- Latitude (+N/S-)..... ....: 0.00 ft Departure (+E/W-).... ....: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-). .......: -999.25 ft Azimuth from rotary table to target: 332.32 degrees ** Survey tool type marked "MWD_IFR" are IFR and drillstringMagnetics corrected ** [(c)2003 Anadrill IDEAL ID6_1C_10J ífR-' ~::C t: i\ I~':: f \1 ti II-:: .!I La \j b """"o? (' t\ f' ., JUf\l 1') '¡\í¡J j' L f-../,. AJaef~ (h'; &. G6.S ~{;¡·¡G. \":V,i1!'i1!~~:on '---- "-.. '- r."\.^ C' ~ ~ \"'11 V \ . ,-,.....,. Criteria --------- 1002.69 mGal 1151.06 HCNT 80.95 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees - ANADRILL SCHLUMBERGER Survey Report 9-May-2003 16:55:01 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Page Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 1 2 3 4 5 0.00 50.00 100.00 163.00 200.00 0.00 0.34 0.38 0.50 0.71 0.78 1.11 1.99 1.76 3.88 5.48 6.82 11.13 13.09 16.23 21.16 24.21 23.97 25.31 26.83 32.13 32.32 36.67 36.15 33.21 38.01 37.94 35.08 33.56 35.19 0.00 344.41 287.01 306.46 305.05 325.51 271.97 283.74 313.25 317.45 317.34 317.59 317.65 317.24 319.52 323.20 325.23 325.26 321.80 329.53 334.96 336.66 338.22 338.78 339.70 331.54 333.55 334.76 332.67 331.65 0.00 50.00 50.00 63.00 37.00 84.00 72.00 91.00 92.80 91.00 89.20 91.00 90.00 90.00 90.00 102.80 95.00 28.26 96.51 91.65 97.75 65.93 95.90 97.00 95.00 122.22 95.32 92.98 95.49 95.41 [(c)2003 Anadrill IDEAL ID6_1C_10J 6 7 8 9 10 284.00 356.00 447.00 539.80 630.80 11 12 13 14 15 720.00 811.00 901.00 991.00 1081.00 16 17 18 19 20 1183.80 1278.80 1307.06 1403.57 1495.22 21 22 23 24 25 1592.97 1658.90 1754.80 1851.80 1946.80 26 27 28 29 30 2069.02 2164.34 2257.32 2352.81 2448.22 0.00 50.00 100.00 163.00 199.99 283.99 355.98 446.95 539.70 630.58 719.48 809.96 898.83 986.83 1073.89 1171.24 1258.88 1284.68 1372.40 1454.75 1539.83 1595.60 1674.62 1752.69 1830.80 1930.20 2005.34 2080.06 2158.93 2237.67 0.00 0.15 0.41 0.80 1.15 2.18 3.01 4.49 6.91 11.20 18.24 27.66 41.24 59.48 81.59 113.94 150.21 161.66 201.40 241.33 289.38 324.47 378.54 435.78 489.44 560.34 618.98 674.27 728.08 781.95 0.00 0.14 0.33 0.56 0.79 1.56 1.98 2.39 3.75 6.98 12.33 19.52 29.89 43.79 60.84 86.64 116.38 125.86 158.18 191.42 234.02 266.09 316.24 369.81 420.34 484.89 536.93 586.70 634.98 682.60 0.00 -0.04 -0.24 -0.66 -0.98 -1.73 -2.70 -5.12 -7.72 -10.82 -15.75 -22.34 -31.80 -44.57 -59.66 -80.11 -101.50 -108.07 -132.00 -154.61 -176.82 -191.23 -212.02 -233.12 -252.29 -281.87 -308.91 -333.04 -356.86 -382.03 0.00 0.15 0.41 0.86 1.25 2.32 3.35 5.65 8.58 12.87 20.00 29.66 43.64 62.48 85.21 118.00 154.42 165.89 206.03 246.06 293.31 327.67 380.74 437.16 490.24 560.87 619.45 674.64 728.39 782.23 0.00 344.41 324.52 310.29 308.84 312.04 306.30 295.04 295.90 302.81 308.06 311.14 313.23 314.49 315.56 317.24 318.91 319.35 320.16 321.07 322.93 324.30 326.16 327.77 329.03 329.83 330.09 330.42 330.66 330.77 2 of 7 DLS (deg/ 100f) 0.00 0.68 0.70 0.30 0.57 0.33 1.25 1.02 1.06 2.34 1.79 1.47 4.79 2.18 3.55 4.93 3.31 0.85 2.04 4.06 6.07 1.40 4.63 0.64 3.14 5.52 1.30 3.17 2.01 1.81 Srvy tool type TIP GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR GYR MWD_IFR MWD_IFR MWD_IFR MWD_IFR GYR GYR GYR GYR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR ------ ------ Tool qual type ------ ------ ---- '-" ANADRILL SCHLUMBERGER Survey Report 9-May-2003 16:55:01 Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 31 32 33 34 35 2541.77 2636.42 2730.85 2824.48 2918.72 38.39 36.61 37.16 39.04 38.41 39.80 39.64 37.75 39.74 38.36 40.01 39.62 38.96 37.95 38.02 38.59 38.86 39.01 38.88 38.32 37.75 37.46 37.50 37.29 37.16 37.53 37.57 37.59 37.20 37.07 333.10 334.93 334.55 334.14 331.38 329.29 329.91 330.78 329.23 330.80 328.93 329.54 329.23 328.99 328.86 328.18 327.74 327.81 327.98 327.90 328.64 328.83 329.18 329.88 330.09 330.67 330.66 330.86 332.02 332.38 93.55 94.65 94.43 93.63 94.24 94.18 93.27 94.29 92.55 94.79 94.64 91.14 42.03 157.01 93.76 94.73 94.75 95.11 94.28 93.85 95.72 92.99 94.38 94.32 94.23 95.10 94.50 95.25 93.22 94.23 [(c)2003 Anadrill IDEAL ID6_1C_10J 36 37 38 39 40 3012.90 3106.17 3200.46 3293.01 3387.80 41 42 43 44 45 3482.44 3573.58 3615.61 3772.62 3866.38 46 47 48 49 50 3961.11 4055.86 4150.97 4245.25 4339.10 51 52 53 54 55 4434.82 4527.81 4622.19 4716.51 4810.74 56 57 58 59 60 4905.84 5000.34 5095.59 5188.81 5283.04 2312.58 2387.67 2463.20 2536.88 2610.41 2683.49 2755.23 2828.82 2901.00 2974.62 3047.97 3117.98 3150.51 3273.46 3347.36 3421.70 3495.62 3569.60 3642.93 3716.27 3791.66 3865.33 3940.23 4015.17 4090.20 4165.80 4240.72 4316.21 4390.27 4465.39 837.96 895.55 952.17 1009.91 1068.85 1128.21 1187.74 1246.65 1304.52 1364.18 1423.91 1482.19 1508.77 1606.26 1663.86 1722.45 1781.55 1841.13 1900.22 1958.60 2017.43 2074.06 2131.39 2188.61 2245.56 2303.22 2360.79 2418.86 2475.46 2532.35 732.24 784.02 835.28 887.35 939.76 991.37 1042.77 1093.99 1144.14 1195.86 1247.55 1297.70 1320.60 1404.40 1453.82 1503.90 1554.14 1604.70 1654.90 1704.53 1754.69 1803.19 1852.42 1901.79 1951.15 -407.98 -433.23 -457.42 -482.44 -509.41 -538.82 -568.98 -598.15 -627.12 -656.97 -687.00 -716.85 -730.41 -780.54 -810.32 -840.98 -872.43 -904.30 -935.80 -966.88 -997.90 -1027.35 -1056.92 -1085.97 -1114.48 2001.30 -1142.99 2051.50 -1171.21 2102.19 -1199.58 2151.91 -1226.65 2202.23 -1253.18 838.23 895.76 952.33 1010.02 1068.95 1128.33 1187.90 1246.84 1304.74 1364.44 1424.21 1482.53 1509.14 1606.73 1664.40 1723.07 1782.27 1841.97 1901.16 1959.66 2018.59 2075.31 2132.73 2190.00 2247.01 2304.69 2362.29 2420.38 2476.97 2533.83 330.88 331.08 331.29 331.47 331.54 331.48 331.38 331.33 331.27 331.22 331.16 331.08 331.05 330.94 330.87 330.79 330.69 330.60 330.51 330.44 330.37 330.33 330.29 330.27 330.27 330.27 330.28 330.29 330.32 330.36 3 of 7 DLS (deg/ 100f) 3.54 2.22 0.63 2.03 1.95 2.03 0.46 2.09 2.39 1.79 2.14 0.61 1.64 0.65 0.11 0.75 0.41 0.16 0.18 0.60 0.76 0.34 0.23 0.50 0.19 0.54 0.04 0.13 0.86 0.27 Srvy tool type MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR ------ ------ Tool qual type ------ ------ -- --- ANADRILL SCHLUMBERGER Survey Report 9-May-2003 16:55:01 Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim ( deg ) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 61 62 63 64 65 5376.77 5471.98 5565.75 5659.64 5752.36 36.75 36.61 36.81 36.95 37.25 37.84 38.14 38.49 38.96 39.28 39.58 39.97 40.14 40.15 40.20 40.17 40.26 40.41 40.26 39.78 39.09 38.22 37.56 36.91 36.35 35.96 36.56 37.02 37.30 37.49 333.28 333.23 334.50 334.83 335.97 337.16 337.75 338.15 338.94 339.74 339.44 338.16 337.49 336.49 334.89 333.71 332.11 330.38 328.77 326.99 325.84 324.03 323.52 323.93 323.99 324.32 325.90 327.37 329.47 331.30 93.73 95.21 93.77 93.89 92.72 94.36 94.40 94.36 94.12 93.78 92.52 94.44 93.73 93.61 94.50 94.41 93.33 93.97 92.96 93.32 94.89 94.37 93.78 93.40 95.19 92.84 94.02 93.79 94.38 94.11 [(c)2003 Anadrill IDEAL ID6_1C_10J 66 67 68 69 70 5846.72 5941.12 6035.48 6129.60 6223.38 71 72 73 74 75 6315.90 6410.34 6504.07 6597.68 6692.18 76 77 78 79 80 6786.59 6879.92 6973.89 7066.85 7160.17 81 82 83 84 85 7255.06 7349.43 7443.21 7536.61 7631.80 86 87 88 89 90 7724.64 7818.66 7912.45 8006.83 8100.94 4540.34 4616.69 4691.87 4766.97 4840.92 4915.74 4990.14 5064.17 5137.60 5210.36 5281.82 5354.41 5426.15 5497.71 5569.92 5642.04 5713.31 5784.95 5855.81 5927.28 6000.57 6074.26 6148.27 6222.63 6299.02 6373.99 6449.80 6524.91 6600.13 6674.90 2588.63 2645.50 2701.53 2757.83 2813.67 2871.01 2928.89 2987.10 3045.64 3104.36 3162.65 3222.68 3282.72 3342.87 3403.73 3464.61 3524.86 3585.67 3645.76 3705.59 3765.54 3823.99 3880.95 3936.83 3993.02 4047.23 4102.40 4158.29 4215.16 4272.27 2252.31 -1278.89 2303.10 -1304.48 2353.42 -1329.17 2404.35 -1353.28 2455.20 -1376.56 2507.96 -1399.42 2561.62 -1421.70 2615.84 -1443.66 2670.64 -1465.20 2726.01 -1486.07 2781.08 -1506.56 2837.41 -1528.42 2893.26 -1551.18 2948.81 -1574.77 3004.37 -1599.87 3059.26 -1626.29 3112.90 -1653.73 3166.22 -1682.98 3218.10 -1713.45 3268.92 -1745.35 3319.13 -1778.69 3367.38 -1812.54 3413.84 -1846.58 3459.41 -1880.02 3505.33 -1913.43 3549.73 -1945.51 3595.34 -1977.31 3642.25 -2008.19 3690.81 -2038.04 3740.50 -2066.28 2590.07 2646.87 2702.83 2759.03 2814.77 2871.97 2929.70 2987.78 3046.17 3104.76 3162.93 3222.88 3282.86 3342.96 3403.79 3464.66 3524.91 3585.72 3645.83 3705.68 3765.69 3824.21 3881.26 3937.25 3993.56 4047.91 4103.20 4159.19 4216.13 4273.27 330.41 330.47 330.54 330.63 330.72 330.84 330.97 331.11 331.25 331.40 331.55 331.69 331.80 331.90 331.96 332.01 332.02 332.01 331.97 331.90 331.81 331.71 331.59 331.48 331.37 331.27 331.19 331.13 331.09 331.08 4 of 7 DLS (deg/ 100f) 0.67 0.15 0.84 0.26 0.81 0.99 0.50 0.45 0.72 0.64 0.38 0.96 0.49 0.69 1.09 0.81 1.11 1.20 1.13 1.33 1.06 1.51 0.78 0.74 0.59 0.47 1.18 1.06 1.38 1.20 Srvy tool type MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR ------ ------ Tool qual type ------ ------ ._/ ANADRILL SCHLUMBERGER Survey Report --- -------- -------- Seq Measured # depth (ft) 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 ------ ------- ------ -------- ------ ------- ------ -------- Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) -------- -------- Vertical section (ft) 9-May-2003 16:55:01 Page ---------------- --------------- ---------------- --------------- Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 91 92 93 94 95 8193.53 8288.15 8383.43 8476.99 8567.58 37.54 37.32 37.50 37.38 37.21 37.18 36.91 36.54 36.29 36.34 36.29 36.45 36.02 34.63 33.84 34.39 34.90 35.97 37.15 38.49 39.81 40.77 41.34 41.40 40.95 40.19 39.72 39.45 38.48 37.65 332.84 333.85 333.93 334.05 333.97 334.16 333.87 334.06 333.82 334.01 334.07 333.83 335.83 340.14 342.39 342.52 342.24 341.22 339.48 339.09 338.26 335.13 332.84 331.05 330.79 330.75 330.03 329.89 329.80 329.82 92.59 94.62 95.28 93.56 90.59 46.83 94.32 96.12 95.82 93.88 96.90 93.06 94.30 95.05 93.18 96.24 95.16 93.04 96.04 95.49 95.86 97.94 92.75 94.50 93.74 99.44 95.20 95.83 95.65 93.99 [(c)2003 Anadrill IDEAL ID6_1C_10J 8614.41 8708.73 8804.85 8900.67 8994.55 9091.45 9184.51 9278.81 9373.86 9467.04 9563.28 9658.44 9751.48 9847.52 9943.01 10038.87 10136.81 10229.56 10324.06 10417.80 10517.24 10612.44 10708.27 10803.92 10897.91 6748.34 6823.48 6899.16 6973.45 7045.52 7082.82 7158.10 7235.14 7312.25 7387.90 7465.98 7540.91 7616.98 7694.54 7771.57 7851.25 7929.54 8005.35 8082.49 8157.92 8232.26 8306.97 8376.91 8447.83 8518.39 8593.93 8666.90 8740.76 8815.13 8889.13 4328.65 4386.15 4444.01 4500.87 4555.73 4584.03 4640.83 4698.28 4755.14 4810.72 4868.08 4923.24 4978.92 5033.58 5085.36 5138.50 5191.76 5244.98 5301.62 5359.74 5419.89 5483.02 5543.90 5606.35 5668.05 5732.70 5793.80 5854.81 5914.90 5972.80 3790.31 -2092.69 3841.71 -2118.49 3893.68 -2143.96 3944.80 -2168.91 3994.14 -2192.96 4019.60 -2205.34 4070.68 -2230.24 4122.32 -2255.46 4173.42 -2280.45 4223.35 -2304.90 4274.95 -2330.02 4324.53 -2354.25 4374.97 -2377.96 4425.88 -2398.59 4475.51 -2415.43 4526.98 -2431.70 4578.54 -2448.08 4629.76 -2464.99 4683.62 -2484.24 4738.39 -2504.95 4794.76 -2526.97 4852.90 -2552.03 4907.64 -2578.75 4962.75 -2608.13 5016.68 -2638.12 5073.12 -2669.70 5126.28 -2699.91 5179.14 ~2730.48 5231.15 -2760.69 5281.24 -2789.83 4329.64 4387.11 4444.92 4501.73 4556.56 4584.83 4641.59 4699.00 4755.83 4811.37 4868.70 4923.83 4979.46 5034.05 5085.72 5138.74 5191.92 5245.08 5301.67 5359.77 5419.90 5483.02 5543.90 5606.35 5668.05 5732.70 5793.81 5854.82 5914.92 5972.82 331.10 331.13 331.16 331.20 331.23 331.25 331.28 331.32 331.35 331.38 331.41 331.44 331.47 331.54 331.64 331.76 331.87 331.97 332.06 332.14 332.21 332.26 332.28 332.28 332.26 332.24 332.23 332.20 332.18 332.15 5 of 7 DLS (deg/ 100f) 1.01 0.69 0.20 0.15 0.20 0.25 0.34 0.40 0.30 0.13 0.06 0.23 1.33 3.00 1.60 0.58 0.56 1.31 1.64 1.43 1.48 2.29 1.73 1.25 0.51 0.76 0.69 0.30 1.02 0.88 Srvy tool type MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR ------ ------ Tool qual type ------ ------ ~. ~. ANADRILL SCHLUMBERGER Survey Report 9-May-2003 16:55:01 Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) 121 122 123 124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 142 143 144 145 146 147 148 149 150 Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 10993.54 11089.04 11184.68 11279.19 11371.97 11475.34 11571.05 11666.79 11762.12 11855.78 11948.71 12043.47 12138.96 12230.27 12325.75 12418.29 12511.11 12607.09 12698.95 12793.14 12887.72 12981.30 13075.47 13170.35 13264.11 13357.79 13484.58 13577.95 13675.87 13771.45 36.75 36.09 36.36 36.48 36.29 36.86 37.04 34.94 34.00 34.51 35.26 36.03 36.81 37.54 37.89 37.61 37.46 37.42 37.00 36.35 34.58 33.29 32.42 30.86 29.24 27.92 28.80 32.02 30.28 29.27 329.82 329.43 329.25 328.36 327.74 328.30 327.71 328.08 326.94 327.55 329.82 332.91 334.20 335.30 335.91 336.30 336.48 336.49 336.19 335.67 334.48 333.32 332.00 330.76 328.92 327.01 327.34 325.67 326.05 324.36 95.63 95.50 95.64 94.51 92.78 103.37 95.71 95.74 95.33 93.66 92.93 94.76 95.49 91.31 95.48 92.54 92.82 95.98 91.86 94.19 94.58 93.58 94.17 94.88 93.76 93.68 126.79 93.37 97.92 95.58 [(c)2003 Anadrill IDEAL ID6_1C_10J 8965.30 9042.15 9119.30 9195.35 9270.04 9353.06 9429.54 9507.00 9585.60 9663.01 9739.24 9816.26 9893.10 9965.85 10041.38 10114.55 10188.16 10264.36 10337.52 10413.07 10490.10 10567.74 10646.84 10727.62 10808.78 10891.04 11002.61 11083.13 11166.93 11249.89 6030.56 6087.19 6143.64 6199.64 6254.53 6315.95 6373.32 6429.41 6483.17 6535.68 6588.71 6643.91 6700.59 6755.71 6814.02 6870.56 6926.96 6985.16 7040.57 7096.72 7151.52 7203.74 7254.83 7304.59 7351.49 7396.17 7456.15 7503.16 7553.49 7600.58 5331.22 -2818.90 5380.13 -2847.56 5428.75 -2876.39 5476.75 -2905.45 5523.45 -2934.57 5575.69 -2967.19 5624.49 -2997.68 5672.14 -3027.58 5717.65 -3056.56 5761.99 -3085.08 5807.39 -3112.69 5855.85 -3139.13 5906.61 -3164.37 5956.51 -3187.90 6009.71 -3212.03 6061.51 -3234.98 6113.32 -3257.62 6166.83 -3280.90 6217.71 -3303.20 6269.07 -3326.14 6318.84 -3349.25 6365.75 -3372.23 6411.14 -3395.68 6454.83 -3419.51 6495.43 -3443.08 6533.42 -3466.84 6584.03 -3499.48 6623.42 -3525.58 6665.34 -3554.01 6704.32 -3581.09 6030.59 6087.24 6143.69 6199.71 6254.61 6316.06 6373.45 6429.57 6483.37 6535.91 6588.98 6644.18 6700.84 6755.94 6814.23 6870.73 6927.11 6985.28 7040.67 7096.79 7151.59 7203.80 7254.88 7304.65 7351.56 7396.25 7456.26 7503.29 7553.66 7600.79 332.13 332.11 332.08 332.05 332.02 331.98 331.94 331.91 331.87 331.83 331.81 331.81 331.82 331.84 331.88 331.91 331.95 331.99 332.02 332.05 332.07 332.09 332.09 332.09 332.07 332.05 332.01 331.97 331.93 331.89 6 of 7 DLS (deg/ 100f) 0.94 0.73 0.30 0.57 0.45 0.64 0.42 2.21 1.20 0.66 1.61 2.07 1.14 1.08 0.54 0.40 0.20 0.04 0.50 0.76 2.01 1.54 1.20 1.78 1.99 1.71 0.70 3.57 1.79 1.37 Srvy tool type MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR MWD_IFR ------ ------ Tool qual type ------ ------ ---- ~ , r ANADRILL SCHLUMBERGER Survey Report 9-May-2003 16:55:01 Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) 151 13865.11 152 13891.46 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 28.56 326.21 28.17 326.06 Projected to TD 153 13981.00 28.17 326.06 93.66 11331.87 26.35 11355.06 89.54 11433.99 [(c)2003 Anadrill IDEAL ID6_1C_10] 7645.52 6741.53 -3606.88 7645.77 331.85 7657.97 6751.93 -3613.86 7658.23 331.84 7699.98 6787.00 -3637.46 7700.29 331.81 7 of 7 DLS (deg/ 100f) Srvy tool type 1.22 MWD_IFR 1.50 MWD_IFR 0.00 PROJ ------ ------ Tool qual type ------ ------ -/ -" bp NS23 ~03 -(J50 Schlumberuer Report Date: 9-May-03 Client: BP Exploration Alaska Field: Northstar Structure I Slot: Northstar PF 1 NS23 Well: NS23 Borehole: NS23 UWI/API#: 500292314600 Survey Name I Date: NS23/ May 9, 2003 TortI AHD I DDI I ERD ratio: 172.941° 17727.13 ft/6.213/ 0.676 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Location Lat/Long: N 70.49135092, W 148.6933160S Location Grid NIE YIX: N 6031041.560 ftUS, E 659826.260 ftU~ Grid Convergence Angle: +1.23169248° Grid Scale Factor: 0.99992902 Survey Report - Geodetic Survey I DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 331.810° Vertical Section Origin: N 0.000 ft, E 0.000 fl TVD Reference Datum: KB TVD Reference Elevation: 56.550 ft relative to MSL Sea Bed I Ground Level Elevation: 15.670 ft relative to MSL Magnetic Declination: +25.976° Total Field Strength: 57554.520 nT Magnetic Dip: 80.954° Declination Date: May 01, 2003 Magnetic Declination Model: BGGM 2002 North Reference: True North Total Corr Mag North -> True North: +25.976° Local Coordinates Referenced To: Well Head Station ID MD Incl Azim TVD VSec N/-S (ft) (0) (0) (ft) (ft) (ft) 0.00 0.00 0.00 0.00 0.00 0.00 50.00 0.34 344.41 50.00 0.14 0.14 100.00 0.38 287.01 100.00 0.41 0.33 163.00 0.50 306.46 163.00 0.80 0.56 200.00 0.71 305.05 199.99 1.15 0.79 284.00 0.78 325.51 283.99 2.19 1.56 356.00 1.11 271.97 355.98 3.02 1.98 447.00 1.99 283.74 446.95 4.52 2.39 539.80 1.76 313.25 539.70 6.95 3.75 630.80 3.88 317.45 630.58 11.26 6.98 720.00 5.48 317.34 719.48 18.31 12.33 811.00 6.82 317.59 809.96 27.75 19.52 901.00 11.13 317.65 898.83 41.36 29.89 991.00 13.09 317.24 986.83 59.65 43.79 1081.00 16.23 319.52 1073.89 81.81 60.84 1183.80 21.16 323.20 1171.24 114.21 86.64 1278.80 24.21 325.23 1258.88 150.52 116.38 1307.06 23.97 325.26 1284.68 161.98 125.86 RECEIVED JU"t 1 r, f'.(\"',7 I', L. L!)V.,) Alaska Of·; & Gas ï..:cn2. ~(,\"¡jmj~5fJn A~chor¿r-:Jij NS23 ASP Final Survey.xls Schlumberger Private Page 1 of 5 ~.~ ~ ^^ c....... - EI-W (ft) 0.00 -0.04 -0.24 -0.66 -0.98 DLS (°/1 o Oft) Grid Coordinates Northing Easting (ftUS) (ftUS) 6031041.56 659826.26 6031041.70 659826.22 6031041.89 659826.01 6031042.10 659825.59 6031042.33 659825.27 Geographic Coordinates Latitude Longitude 0.68 0.70 0.30 0.57 N 70.49135092 W 148.69331609 N 70.49135131 W 148.69331641 N 70.49135183 W 148.69331804 N 70.49135244 W 148.69332148 N 70.49135306 W 148.69332407 -1.73 0.33 6031043.08 659824.50 N 70.49135517 W 148.69333020 -2.70 1.25 6031043.49 659823.52 N 70.49135634 W 148.69333817 -5.12 1.02 6031043.84 659821.09 N 70.49135745 W 148.69335791 -7.72 1.06 6031045.14 659818.46 N 70.49136116 W 148.69337919 ~/ -10.82 2.34 6031048.30 659815.29 N 70.49136997 W 148.69340454 -15.75 1.79 6031053.55 659810.25 N 70.49138460 W 148.69344481 -22.34 1.47 6031060.59 659803.51 N 70.49140423 W 148.69349867 -31.80 4.79 6031070.75 659793.83 N 70.49143256 W 148.6.9357600 -44.57 2.18 6031084.38 659780.76 N 70.49147055 W 148.69368041 -59.66 3.55 6031101.10 659765.31 N 70.49151713 W 148.69380375 -80.11 4.93 6031126.46 659744.31 N 70.49158762 W 148.69397095 -101.50 3.31 6031155.73 659722.29 N 70.49166886 W 148.69414576 -108.07 0.85 6031165.06 659715.52 N 70.49169475 W 148.69419951 5/15/2003-4:14 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/·S Ef·W DLS Northing I Easting Latitude I Longitude (ft) (0) n (ft) (ft) (ft) (ft) r/100ft) (ftUS) (ftUS) 1403.57 25.31 321.80 1372.40 201.78 158.18 -132.00 2.04 6031196.86 659690.90 N 70.49178305 W 148.69439514 1495.22 26.83 329.53 1454.75 241.75 191 .42 -154.61 4.06 6031229.60 659667.58 N 70.49187384 W 148.69457998 1592.97 32.13 334.96 1539.83 289.79 234.02 -176.82 6.07 6031271.71 659644.46 N 70.49199022 W 148.69476153 1658.90 32.32 336.66 1595.60 324.86 266.09 -191.23 1.40 6031303.46 659629.37 N 70.49207782 W 148.69487927 1754.80 36.67 338.22 1674.62 378.89 316.24 -212.02 4.63 6031353.15 659607.51 N 70.49221484 W 148.69504925 1851.80 36.15 338.78 1752.69 436.07 369.81 -233.12 0.64 6031406.25 659585.26 N 70.49236118 W 148.69522177 1946.80 33.21 339.70 1830.80 489.67 420.34 -252.29 3.14 6031456.35 659565.01 N 70.49249922 W 148.69537851 2069.02 38.01 331.54 1930.20 560.53 484.89 -281.87 5.52 6031520.25 659534.05 N 70.49267556 W 148.69562034 2164.34 37.94 333.55 2005.34 619.17 536.93 -308.91 1.30 6031571.69 659505.90 N 70.49281773 W 148.69584140 2257.32 35.08 334.76 2080.06 674.44 586.70 -333.04 3.17 6031620.93 659480.71 N 70.49295369 W 148.69603868 33.56 634.98 2.01 '- 2352.81 332.67 2158.93 728.24 -356.86 6031668.67 659455.86 N 70.49308556 W 148.69623343 2448.22 35.19 331 .65 2237.67 782.10 682.60 -382.03 1.81 6031715.74 659429.68 N 70.49321567 W 148.69643916 2541.77 38.39 333.10 2312.58 838.12 732.24 -407.98 3.54 6031764.81 659402.67 N 70.49335128 W 148.69665132 2636.42 36.61 334.93 2387.67 895.69 784.02 -433.23 2.22 6031816.03 659376.31 N 70.49349273 W 148.69685784 2730.85 37.16 334.55 2463.20 952.29 835.28 -457.42 0.63 6031866.75 659351.02 N 70.49363275 W 148.69705560 2824.48 39.04 334.14 2536.88 1010.00 887.35 -482.44 2.03 6031918.27 659324.90 N 70.49377500 W 148.69726013 2918.72 38.41 331 .38 2610.41 1068.94 939.76 -509.41 1.95 6031970.09 659296.81 N 70.49391817 W 148.69748065 3012.90 39.80 329.29 2683.49 1128.31 991.37 -538.82 2.03 6032021 .04 659266.30 N 70.49405914 W 148.69772111 3106.17 39.64 329.91 2755.23 1187.87 1042.77 -568.98 0.46 6032071 .79 659235.04 N 70.49419957 W 148.69796772 3200.46 37.75 330.78 2828.82 1246.79 1093.99 -598.15 2.09 6032122.36 659204.78 N 70.49433949 W 148.69820625 3293.01 39.74 329.23 2901.00 1304.68 1144.14 -627.12 2.39 6032171.88 659174.74 N 70.49447649 W 148.69844312 3387.80 38.36 330.80 2974.62 1364.36 1195.86 -656.97 1.79 6032222.93 659143.78 N 70.49461775 W 148.69868722 3482.44 40.01 328.93 3047.97 1424.12 1247.55 -687.00 2.14 6032273.97 659112.65 N 70.49475898 W 148.69893278 3573.58 39.62 329.54 3117.98 1482.41 1297.70 -716.85 0.61 6032323.46 659081.73 N 70.49489596 W 148.69917687 3615.61 38.96 329.23 3150.51 1509.01 1320.60 -730.41 1.64 6032346.06 659067.69 N 70.49495853 W 148.69928770 3772.62 37.95 328.99 3273.46 1606.54 1404.40 -780.54 0.65 6032428.75 659015.78 N 70.49518743 W 148.69969760 - 3866.38 38.02 328.86 3347.36 1664.17 1453.82 -810.32 0.11 6032477.52 658984.94 N 70.49532244 W 148.69994116 3961.11 38.59 328.18 3421.70 1722.79 1503.90 -840.98 0.75 6032526.92 658953.21 N 70.49545923 W 148.70019191 4055.86 38.86 327.74 3495.62 1781.93 1554.14 -872.43 0.41 6032576.48 658920.69 N 70.49559648 W 148.70044906 4150.97 39.01 327.81 3569.60 1841.55 1604.71 -904.30 0.16 6032626.34 658887.74 N 70.49573460 W 148.70070970 4245.25 38.88 327.98 3642.93 1900.68 1654.90 -935.80 0.18 6032675.85 658855.17 N 70.49587173 W 148.70096726 4339.10 38.32 327.90 3716.27 1959.1 0 1704.53 -966.88 0.60 6032724.79 658823.04 N 70.49600728 W 148.70122142 4434.82 37.75 328.64 3791.66 2017.96 1754.69 -997.90 0.76 6032774.26 658790.95 N 70.49614430 W 148.70147509 4527.81 37.46 328.83 3865.33 2074.62 1803.19 -1027.35 0.34 6032822.12 658760.47 N 70.49627679 W 148.70171593 4622.19 37.50 329.18 3940.23 2131.98 1852.42 -1056.92 0.23 6032870.70 658729.85 N 70.49641126 W 148.70195779 Schlumberger Private NS23 ASP Final Survey.xls Page 2 of 5 5/15/2003-4:14 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/·S E/·W DLS Northing Easting Latitude Longitude (ft) n n (ft) (ft) (ft) (ft) ("/100ft) (ftUS) (ftUS) 4716.51 37.29 329.88 401 5.17 2189.22 1901.79 -1085.97 0.50 6032919.43 658699.75 N 70.49654612 W 148.70219534 4810.74 37.16 330.09 4090.20 2246.19 1951.15 -1114.48 0.19 6032968.16 658670.18 N 70.49668096 W 148.70242855 4905.84 37.53 330.67 4165.80 2303.86 2001 .30 -1142.99 0.54 6033017.68 658640.60 N 70.49681795 W 148.70266173 5000.34 37.57 330.66 4240.72 2361 .44 2051.50 -1171.21 0.04 6033067.27 658611.31 N 70.49695510 W 148.70289251 5095.59 37.59 330.86 4316.21 2419.52 2102.19 -1199.58 0.13 6033117.33 658581.86 N 70.49709356 W 148.70312458 5188.81 37.20 332.02 4390.27 2476.13 2151.91 -1226.65 0.86 6033166.45 658553.73 N 70.49722938 W 148.70334596 5283.04 37.07 332.38 4465.39 2533.02 2202.23 -1253.18 0.27 6033216.19 658526.12 N 70.49736683 W 148.70356297 5376.77 36.75 333.28 4540.34 2589.30 2252.31 -1278.89 0.67 6033265.70 658499.35 N 70.49750362 W 148.70377322 5471.98 36.61 333.23 4616.69 2646.15 2303.10 -1304.48 0.15 6033315.92 658472.67 N 70.49764236 W .148.70398257 5565.75 36.81 334.50 4691.87 2702.17 2353.42 -1329.17 0.84 6033365.69 658446.91 N 70.49777982 W148.70418451 5659.64 36.95 334.83 4766.97 2758.44 2404.35 -1353.28 0.26 6033416.09 658421.71 N 70.49791893 W 148.70438174 5752.36 37.25 335.97 4840.92 2814.26 2455.20 -1376.56 0.81 6033466.42 658397.35 N 70.49805784 W 148.70457217 5846.72 37.84 337.16 4915.74 2871.56 2507.96 -1399.42 0.99 6033518.68 658373.36 N 70.49820196 W 148.70475921 5941 .12 38.14 337.75 4990.14 2929.38 2561.62 -1421.70 0.50 6033571.84 658349.93 N 70.49834855 W 148.70494145 6035.48 38.49 338.15 5064.17 2987.55 2615.84 -1443.66 0.45 6033625.58 658326.81 N 70.49849667 W 148.70512112 6129.60 38.96 338.94 5137.60 3046.02 2670.64 -1465.20 0.72 6033679.90 658304.11 N 70.49864636 W 148.70529730 6223.38 39.28 339.74 5210.36 3104.68 2726.01 -1486.07 0.64 6033734.80 658282.05 N 70.49879760 W 148.70546808 6315.90 39.58 339.44 5281 .82 3162.90 2781.08 -1506.56 0.38 6033789.41 658260.38 N 70.49894804 W 148.70563575 6410.34 39.97 338.16 5354.41 3222.87 2837.41 -1528.42 0.96 6033845.25 658237.32 N 70.49910190 W 148.70581453 6504.07 40.14 337.49 5426.15 3282.86 2893.26 -1551 .18 0.49 6033900.60 658213.36 N 70.49925448 W 148.70600079 6597.68 40.15 336.49 5497.71 3342.96 2948.81 -1574.77 0.69 6033955.63 658188.58 N 70.49940622 W 148.70619380 6692.18 40.20 334.89 5569.92 3403.78 3004.37 -1599.87 1.09 6034010.63 658162.30 N 70.49955797 W 148.70639912 6786.59 40.17 333.71 5642.04 3464.64 3059.26 -1626.29 0.81 6034064.93 658134.71 N 70.49970791 W 148.70661524 6879.92 40.26 332.11 5713.31 3524.88 3112.90 -1653.73 1.11 6034117.97 658106.13 N 70.49985444 W 148.70683974 6973.89 40.41 330.38 5784.95 3585.70 3166.22 -1682.98 1.20 6034170.64 658075.73 N 70.50000008 W 148.70707910 7066.85 40.26 328.77 5855.81 3645.82 3218.10 -1713.45 1.13 6034221.85 658044.16 N 70.50014179 W 148.70732835~ 7160.17 39.78 326.99 5927.28 3705.68 3268.92 -1745.35 1.33 6034271.97 658011.18 N 70.50028061 W 148.70758932 7255.06 39.09 325.84 6000.57 3765.69 3319.13 -1778.69 1.06 6034321 .45 657976.77 N 70.50041776 W 148.70786204 7349.43 38.22 324.03 6074.26 3824.20 3367.38 -1812.54 1.51 6034368.96 657941.89 N 70.50054955 W 148.70813900 7443.21 37.56 323.52 6148.27 3881.23 3413.84 -1846.58 0.78 6034414.68 657906.87 N 70.50067645 W 148.70841742 7536.61 36.91 323.93 6222.64 3937.18 3459.4 1 -1880.02 0.74 6034459.50 657872.46 N 70.50080089 W 148.70869098 7631.80 36.35 323.99 6299.03 3993.45 3505.33 -1913.43 0.59 6034504.70 657838.07 N 70.50092633 W 148.70896434 7724.64 35.96 324.32 6373.99 4047.73 3549.73 -1945.51 0.47 6034548.39 657805.05 N 70.50104760 W 148.70922675 7818.66 36.56 325.90 6449.80 4102.96 3595.34 -1977.31 1.18 6034593.31 657772.28 N 70.50117218 W 148.70948693 7912.45 37.02 327.37 6524.91 4158.89 3642.25 -2008.19 1.06 6034639.54 657740.39 N 70.50130031 W 148.70973963 Schlumberger Private NS23 ASP Final Survey.xls Page 3 of 5 5/15/2003-4: 14 PM Grid Coordinates Geographic Coordinates Station ID MD IntI Azim TVD VSec N/·S E/·W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) ("/100ft) (ftUS) (ftUS) 8006.83 37.30 329.47 6600.13 4215.80 3690.81 -2038.04 1.38 6034687.45 657709.51 N 70.50143296 W 148.70998384 8100.94 37.49 331.30 6674.90 4272.93 3740.50 -2066.28 1.20 6034736.51 657680.21 N 70.50156866 W 148.71021491 8193.53 37.54 332.84 6748.34 4329.31 3790.31 -2092.69 1.01 6034785.74 657652.74 N 70.50170473 W 148.71043099 8288.15 37.32 333.85 6823.48 4386.79 3841.71 -2118.49 0.69 6034836.56 657625.84 N 70.50184511 W 148.71064212 8383.43 37.50 333.93 6899.16 4444.64 3893.68 -2143.96 0.20 6034887.98 657599.26 N 70.50198709 W 148.71085058 8476.99 37.38 334.05 6973.45 4501 .48 3944.80 -2168.91 0.15 6034938.54 657573.22 N 70.50212671 W 148.71105470 8567.58 37.21 333.97 7045.52 4556.33 3994.14 -2192.96 0.20 6034987.35 657548.12 N 70.50226148 W 148.71125154 8614.41 37.18 334.16 7082.82 4584.61 4019.60 -2205.34 0.25 6035012.54 657535.19 N 70.50233102 W 148.71135287 8708.73 36.91 333.87 7158.10 4641 .39 4070.68 -2230.24 0.34 6035063.06 657509.21 N 70.50247054 W 148.71155660 8804.85 36.54 334.06 7235.14 4698.83 4122.32 -2255.46 0.40 6035114.15 657482.88 N 70.50261161 W 148.71176307 8900.67 36.29 333.82 7312.25 4755.67 4173.42 -2280.45 0.30 6035164.70 657456.80 N 70.50275118 W 148.71196757 .~~ 8994.55 36.34 334.01 7387.90 4811.23 4223.35 -2304.90 0.13 6035214.09 657431.29 N 70.50288757 W 148.71216764 9091 .45 36.29 334.07 7465.98 4868.58 4274.95 -2330.02 0.06 6035265.13 657405.06 N 70.50302851 W 148.71237323 9184.51 36.45 333.83 7540.91 4923.72 4324.53 -2354.25 0.23 6035314.17 657379.77 N 70.50316393 W 148.71257157 9278.81 36.02 335.83 7616.98 4979.38 4374.97 -2377.96 1.33 6035364.09 657354.99 N 70.50330170 W 148.71276562 9373.86 34.63 340.14 7694.54 5033.99 4425.88 -2398.59 3.00 6035414.54 657333.27 N 70.50344076 W 148.71293442 9467.04 33.84 342.39 7771.58 5085.69 4475.51 -2415.43 1.60 6035463.79 657315.37 N 70.50357634 W 148.71307233 9563.28 34.39 342.52 7851.25 5138.74 4526.98 -2431.70 0.58 6035514.89 657298.00 N 70.50371692 W 148.71320555 9658.44 34.90 342.24 7929.54 5191.92 4578.54 -2448.08 0.56 6035566.09 657280.52 N 70.50385776 W 148.71333964 9751.48 35.97 341 .22 8005.35 5245.06 4629.76 -2464.99 1.31 6035616.93 657262.50 N 70.50399767 W 148.71347813 9847.52 37.15 339.48 8082.49 5301.62 4683.62 -2484.24 1.64 6035670.36 657242.11 N 70.50414480 W 148.71363571 9943.01 38.49 339.09 8157.92 5359.68 4738.39 -2504.95 1.43 6035724.66 657220.22 N 70.50429439 W 148.71380528 10038.87 39.81 338.26 8232.26 5419.77 4794.76 -2526.97 1.48 6035780.55 657197.00 N 70.50444838 W 148.71398550 10136.81 40.77 335.13 8306.97 5482.85 4852.90 -2552.03 2.29 6035838.13 657170.70 N 70.50460719 W 148.71419068 10229.56 41.34 332.84 8376.92 5543.72 4907.64 -2578.75 1.73 6035892.28 657142.81 N 70.50475669 W 148.71440940 10324.06 41 .40 331.05 8447.84 5606.17 4962.75 -2608.13 1.25 6035946.74 657112.26 N 70.50490723 W 148.71464982~ 10417.80 40.95 330.79 8518.39 5667.87 5016.68 -2638.12 0.51 6036000.02 657081.11 N 70.50505454 W 148.71489532 10517.24 40.19 330.75 8593.93 5732.54 5073.12 -2669.70 0.76 6036055.76 657048.33 N 70.50520869 W 148.71515381 10612.44 39.72 330.03 8666.91 5793.65 5126.27 -2699.91 0.69 6036108.24 657016.99 N 70.50535387 W 148.71540104 10708.27 39.45 329.89 8740.76 5854.69 5179.14 -2730.48 0.30 6036160.43 656985.30 N 70.50549825 W 148.71565125 10803.92 38.48 329.80 8815.13 5914.80 5231.15 -2760.69 1.02 6036211.78 656953.97 N 70.50564030 W 148.71589856 10897.91 37.65 329.82 8889.13 5972.71 5281.24 -2789.83 0.88 6036261.23 656923.76 N 70.50577711 W 148.71613709 10993.54 36.75 329.82 8965.30 6030.50 5331.22 -2818.90 0.94 6036310.57 656893.63 N 70.50591362 W 148.71637501 11089.04 36.09 329.43 9042.15 6087.15 5380.13 -2847.56 0.73 6036358.85 656863.92 N 70.50604722 W 148.71660967 11184.68 36.36 329.25 9119.30 6143.62 5428.75 -2876.39 0.30 6036406.83 656834.06 N 70.50618001 W 148.71684559 Schlumberger Private NS23 ASP Final Survey.xls Page 4 of 5 5/15/2003-4: 14 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NI·S E/·W DLS Northing Easting Latitude Longitude (ft) n n (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 11279.19 36.48 328.36 9195.35 6199.65 5476.75 -2905.45 0.57 6036454.19 656803.98 N 70.50631109 W 148.71708348 11371.97 36.29 327.74 9270.04 6254.57 5523.44 -2934.57 0.45 6036500.25 656773.86 N 70.50643864 W 148.71732187 11475.34 36.86 328.30 9353.06 6316.03 5575.69 -2967.19 0.64 6036551.78 656740.13 N 70.50658134 W 148.71758889 11571.05 37.04 327.71 9429.55 6373.44 5624.49 -2997.68 0.42 6036599.90 656708.60 N 70.50671460 W 148.71783842 11666.79 34.94 328.08 9507.01 6429.56 5672.14 -3027.58 2.21 6036646.90 656677.68 N 70.50684475 W 148.71808320 11762.12 34.00 326.94 9585.60 6483.36 5717.65 -3056.56 1.20 6036691 .77 656647.74 N 70.50696904 W 148.71832038 11855.78 34.51 327.55 9663.01 6535.91 5761 .99 -3085.08 0.66 6036735.48 656618.27 N 70.50709013 W 148.71855386 11948.71 35.26 329.82 9739.25 6588.98 5807.39 -3112.69 1.61 6036780.28 656589.69 N 70.50721414 W 148.71877989 12043.47 36.03 332.91 9816.26 6644.18 5855.85 -3139.13 2.07 6036828.16 656562.22 N 70.50734650 W 148.71899638 12138.96 36.81 334.20 9893.10 6700.84 5906.61 -3164.37 1.14 6036878.36 656535.89 N 70.50748514 W 148.71920305 12230.27 37.54 335.30 9965.85 6755.94 5956.51 -3187.90 1.08 6036927.74 656511.30 N 70.50762144 W 148.71939572 - 12325.75 37.89 335.91 1 0041 .38 6814.22 6009.71 -3212.03 0.54 6036980.40 656486.04 N 70.50776673 W 148.71959325 12418.29 37.61 336.30 10114.56 6870.72 6061.50 -3234.98 0.40 6037031.69 656461.98 N 70.50790821 W 148.71978118 12511 .11 37.46 336.48 10188.16 6927.09 6113.32 -3257.62 0.20 6037083.00 656438.23 N 70.50804974 W 148.71996665 12607.09 37.42 336.49 10264.37 6985.24 6166.82 -3280.90 0.04 6037135.99 656413.80 N 70.50819587 W 148.72015730 12698.95 37.00 336.19 10337.53 7040.62 6217.71 -3303.20 0.50 6037186.38 656390.42 N 70.50833485 W 148.72033986 12793.14 36.35 335.67 10413.07 7096.73 6269.07 -3326.14 0.76 6037237.23 656366.38 N 70.50847514 W 148.72052775 12887.72 34.58 334.48 10490.10 7151.51 6318.84 -3349.25 2.01 6037286.49 656342.21 N 70.50861107 W 148.72071702 12981.30 33.29 333.32 10567.74 7203.71 6365.75 -3372.23 1.54 6037332.90 656318.23 N 70.50873920 W 148.72090515 13075.47 32.42 332.00 10646.85 7254.79 6411.14 -3395.68 1.20 6037377.76 656293.81 N 70.50886315 W 148.72109722 13170.35 30.86 330.76 10727.62 7304.56 6454.83 -3419.51 1.78 6037420.93 656269.05 N 70.50898249 W 148.72129233 13264.11 29.24 328.92 10808.78 7351 .48 6495.43 -3443.08 1.99 6037461.01 656244.61 N 70.50909337 W 148.72148532 13357.79 27.92 327.01 10891.04 7396.19 6533.42 -3466.84 1.71 6037498.48 656220.05 N 70.50919713 W 148.72167981 13484.58 28.80 327.34 11002.62 7456.22 6584.03 -3499.48 0.70 6037548.37 656186.33 N 70.50933535 W 148.72194708 13577.95 32.02 325.67 11083.13 7503.26 6623.42 -3525.58 3.57 6037587.19 656159.38 N 70.50944292 W 148.72216081 13675.87 30.28 326.05 11166.93 7553.64 6665.34 -3554.01 1.79 6037628.48 656130.06 N 70.50955740 W 148.72239357--' 13771.45 29.27 324.36 11249.89 7600.79 6704.32 -3581.09 1.37 6037666.87 656102.16 N 70.50966385 W 148.72261523 13865.11 28.56 326.21 11331.88 7645.77 6741.53 -3606.88 1.22 6037703.52 656075.57 N 70.50976548 W 148.72282641 13891.46 28.17 326.06 11355.06 7658.23 6751.93 -3613.86 1.50 6037713.76 656068.38 N 70.50979387 W 148.72288352 13981 .00 28.17 326.06 11434.00 7700.29 6787.00 -3637.46 0.00 6037748.31 656044.03 N 70.50988964 W 148.72307676 NS23 ASP Final Survey.xls Schlumberger Private Page 5 of 5 5/15/2003-4:14 PM ) ) / STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us Packer Depths (ft.) Well NS-23 Type Inj. G MD/TVD 13,079' 10,650' Tubing ,P;T;D. 203,.050 Type test P Test psi 2,663 Casing Notes: Initial MITIA, pre-injection start. Another MITIA will be conducted post-injection start. Well Type Inj. MD/TVD Tubing P.T.D. Type test Test psi Casing Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting MIT Report Form Revised: 06/19/02 Type Inj. Type tesl Type Inj. Type test Type Inj. Type tesl BP Exploration (Alaska) Inc. NorthStar / NorthStar / NorthStar 06/09/03 Clump Waived by Chuck Scheve Pretest MD/TVD Test psi Tubing Casing MD/TVD Tubing Casing Test psi MD/TVD Test psi Tubing Casing TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test MIT NS NS-23 pre-inj 06-25-031.xls Initial 15 Min. 30 Min. 2,000 2,000 2,000 Interva I 5,800 5,800 5,800 P/F P Interva P/F Interva P/F Interva PIF Interva P/F INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) ) ) Date: 05-27-2003 Transmittal #92651 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top Bottom SW Name Date Contractor Log Run Depth Depth Log Type NS23 05-09-2003 SCH 1 0 13981 MWD SURVEY RE(QRT/HARD~OPYI DISKETTE \'\..~) \":> ~ A. ~ ~~ f)rb>-~-1 NS19 05-03-2003 SCH 1 14012 12550 JEWELRY LOG; -- J .. \~~' NS10 03-25-2003 SCH 4850 8015 RST WFL-UP FLOW MODE; ~ NS19 05-05-2003 SCH 13140 14000 PERFORATING RECORD; NS06 04-09-2003 SCH 13000 13788 PERFORATING RECORD; NS23 05-01-2003 SCH 11040 13333 PERFORATING RECORD; 't13~NS23 04-29-2003 SCH 13340 13212 DEPTH DETERMINATION SAMPLE BAILER;_,···· ?}/J!) , \C' \ .NS06 04-11-2003 SCH 13025 13746 BAKER IBP SET RECORD; M---' \0 NS18 07 -17 -2002 SPERRY 1 END OF WELL REPORT/MUDLOG: @.cX:}~(9:).3 NS22 01-22-2003 SPERRY 1 END OF WELL REPORT/MUDLOG: @...~ -}67'-1 NS24 12-27 -2002 SPERRY 1 END OF WELL REPORT/MUDLOG: ~~~ '~l~~",^, \~ t (j ~ ~ j'V'\.. Please Sign and Return one copy of this transmittal. Thank Y Oll, James H. Johnson Petrotechnical Data Center R·, r.:Ct=~VED \ "'\t-.r", . ,6 - M/\ '( 2. U 2.00~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 19-6612 . . _" ,. . \ c·... .,~ :····.I.T:.·(''>:'l:.1oõr'r.'! A!a~.r,a vr;';'; t...¡~~ \.A~IIÌ.:. \..{.;..to 1.:.1I.\:~'~ 1~\!:~':1 t'~::; ) BPXA WELL DATA TRANSMITTAL BP - Ken Lemley BP - Ester Fueg AOGCC Attn: Lisa Weepie Murphy Exploration (Alaska), Inc. Attn: Jason Smith DNR - Division of Oil & Gas Attn: Tim Ryherd MMS Attn: Doug Choromanski Attn: Kristin Dirks (DNR) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ) Date: 05-27-2003 Transmittal #92651 RE: Northstar Completion Delays ) ) Subject: RE: Northstar Completion Delays Date: Mon, 17 Mar 2003 12:50:49 -0600 From: "Hernandez, Floyd" <HernanF1@BP.com> To: "'Winton Aubert'" <Winton_Aubert@admin.state.ak.us> Winton, The wells th~t could potentially have deferred completions will be NS16, NS19/~'NS20, & NS21. JUS~'fO let you know, I'm planning on suspending these wells with seawater and a diesel cap (1700'). This puts us in an under balance situations, except that before the well is switch over to seawater, a positive pressure test to 4370 psi will be conducted. After the switching to seawater, a negative test or inflow test will be performed for 30 minutes. A tubing hanger and BPV will also be installed and tested to 4200 psi. Any issues with how we suspend these wells? They are basically the same as what we have been doing on the previous Top Sag suspensions. Thanks, Floyd Hernandez Senior Drilling Engineer Northstar Development (907) 564-5960 work (907) 240-8056 cell hernanf1@bp.com -----Original Message----- From: Winton Aubert [mailto:Winton Aubert@admin.state.ak.us] Sent: Friday, March 14, 2003 6:50 AM To: Hernandez, Floyd Subject: Re: Northstar Completion Delays Floyd, No Sundries are necessary. Let me know by E-mail which wells are involved so I can update our files. Thanks, Winton "Hernandez, Floyd" wrote: > Winton, > > To be able to drill and case off as many wells thru the reservoir section > prior to the beginning of the Seasonal Drilling Restriction which begin on > June 1st, we have decided to delay running the tubing completions on wells > until after June 1st. Do you need a Sundry Notice or can we still utilize > the Original Drilling Permit which discussed "Operation Shutdown" of the > wells after top setting the Sag River. > > Thanks, > Floyd Hernandez > Senior Drilling Engineer > Northstar Development > (907) 564-5960 work > (907) 240-8056 cell > hernanfl®bp.com ~~®~L ci!) ~. I.r\1 i.~ ..1 ~ ) -e ® - ® @ -r; ® J lffi .-=:1ln1 æ) _ \\ LA1 ) ,..::~,; FRANK H. MURKOWSKI, GOVERNOR ( AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION Floyd Hernandez Senior Drilling Engineer BP Exploration (Alaska) Inc P. O. Box 196612 Anchorage, Alaska 99519-6612 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Northstar Unit NS23i BP Exploration (Alaska) Inc Permit No: 203-050 Surface Location: 1269' NSL, 647' WEL, SEC. 11, TI3N, RI3E, UM Bottomhole Location: 2832' NSL, 4231' WEL, SEC. 02, TI3N, RI3E, UM Dear Mr. Hernandez: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exeInpt you frOIn obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit 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 COInmission specifically authorizes a variance. Failure to cOlnply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a COInmission order, or the tenns 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 North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ["--'7 ~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED thiszr day of March, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. }kJl.1A- '~l¿ç ¡ 'l.oo's 12. Distance to nearest property line 13. Distance to nearest well / ADL Y0179, Approx. 24481 MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 3001 MD Maximum Hole Angle 18. Casing ~rogram Specifications Size Casina Weiaht Grade Couplina 20" 169# X-56 Weld 13-3/8" 68# L-80 BTC 9-5/8" 53.5# L-80 BTC-M 7" 2~ L-80 Hydril511 4-1/2" 12.6# L-80 Yam Ace Hole 20" 16" 12-1/4" 8-1/2" 6-1/8" -) STATE OF ALASKA ') ALASKA 01L AND GAS CONSERVATION COMMI~SION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil II Service D Development Gas [] Single Zone [] Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned KBE = 561 Northstar Unit 6. Property Designation ADL312799 7. Unit or Property Name Northstar Unit 8. Well Number /. NS23i 9. Approximate spud date... 04/03/03 /" Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 4472 139321 MD /113761 TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 38 0 Maximum surface 3860 ~ig, At total depth (TVD) 111001 I 5192 psig Setting Depth Top Bottom MD TVD MD TVD Surface Surface 2011 2011 Driven Surface Surface 3666' . 32001 563 sx PF IE', 471 sx Class IGI Surface Surface 11694' 95361 662 sx Econolite, 673 Class IGI 115441 94181 134171, 109301 278 sx Class IGI 132671 1 07991 13932~ 113761 95 sx Class 'GI 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work III Drill [] Redrill [] Re-Entry [] Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 659826, Y = 6031042 12691 NSL, 6471 WEL, SEC. 11, T13N, R13E, UM At top of productive interval x = 656222, Y = 6037565 25881 NSL, 41051 WEL, SEC. 02, T13N R13E, UM At total depth x = 656091, Y = 6037806 2832' NSL, 42311 WEL, SEC. 02, T13N, R13E, UM Number 2S100302630-277 Lenath 2011 36661 116941 18731 6651 Quantity of Cement (include staae data) ,/" / ",...- /' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner 2~-. 4 ÎVi.AH - í'~\". .~, I, .-, '-""", ". f"-",', --'\. rt1 Perforation depth: measured /"'. ~.,.,.~:.."·l~;~~lfl ., true vertical 20. Attachments III Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch II Drilling Program III Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Allen Sherritt, 564-5204 Prepared By NamelNumber: Sandra Stewman, 564-4750 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Floyd Hemand", ....... ~.. .' .', ",:~I~ ~n:~~ ,Drillin~.,~ngineer Date s/;¿ 1/ () 3 ',',..,...; ,," ·.".,,:·.,,~Jcm:'U$.\Q(tlVi,:':.- ;":'<L:"~"::;t;',,,·,", ,.",1_ ,:"..' Permit Number API Number Approv~ ~te. See cover letter 20 ~ - 06éJ 50- ð2 7 - .z "3 17' ~ 0 j /2.Jí c: 1 for other requirements Conditions of Approval: Samples Required 0 Yes ø No Mud Log Required ~ Yes .121 No Hydrogen Sulfide Measures ~ Yes ø No Directional Survey Required 51 Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU _ t- p )- J _ .Qther· ?~V '2:0 AAL lS, O'3S (h)t2.) ¡ i,l."ev-tev re~c;<"lr\.( JY\.'tt..c 1- i'~ ~'t,-,( V'l d. \ ~ S ~fì\ t- TO.4 åQC p~L µ\ 1:. T) t~t Õ'{J~_t(,ht /p~ r£ê~·u~d. b~ order of _. Approved By n ~~/CL--"- ~'-, Commissioner the commission Date ¿J 3>/¿s~ '( Form 10-401 Rev. 12-01-85 Submit In Trip1îê'ate ) ) bp .~A~J. ..'~ ~~.. ~: ~--....... - ~........ J tj,,- ,. BP Exploration Alaska Inc. To: Winton Aubert - AOGCC Date: March 21, 2003 From: Floyd Hernandez Northstar Senior Drilling Engineer Subject: NS23 Application for Drilling Permit Mr. Aubert, / NS23 is currently scheduled for Nabors 33E on April 1 2003. A Diverter waiver is also requested on NS23. To date, BP has drilled twenty development wells through the Northstar upper strata-graphic intervals and has not experienced any difficulty with shallow gas. Twenty surface holes have been drilled and cemented to a common depth of approximately 3,170' TVDss depth, (.....150' TVD below the top of the SV6), with one well extending into the SV5 ....3280' TVDss. Well mud logs and seismic data do not indicate the presence of a shallow gas hazard. NS23 may perform an "Operation Shutdown" to delay the running of the completion tubing until after June 1, 2003 to allow maximum penetrations through the reservoir prior to the beginning of the 2003 Seasonal ./,/ Drilling Restriction period. A Sundry for the Operation Shutdown will not be submitted, as the operations are covered in the ADP procedure. Please find attached the NS23 Well Plan Summary, directional plan and proposed completion diagram. If you should have any questions or concerns, please contact me @ 564-5960 Sincerely, Floyd Hernandez BP Northstar Senior Drilling Engineer 564-5960 work 240-8056 cell ,) ) NS23 SUMMARY DRilLING OPERATIONS Pre-RiQ Work: 1 . Set 20" conductor and weld an ASS Vetco landing ring for the ASS Vetco Multibowl Wellhead on the conductor. (Already performed.) 2. Install 7' x 7' cellar and polyshield same. (Already performed.) RiQ Operations: 1. MIRU Nabors 33E. 2. Nipple up and function test 21-1/4" diverter system, if~uired. NOTE: A diverter dispensation has been requested. Confirm dispensation decision with the Drilling Engineer. A 07 Diverter Drill will be conducted prior to spud. 3. MU 16" drilling assembly with MWD/GR and directionally drill surface hole to +/-150' TVD below the /.- top of the SV6 marker at approximately 3486' MD. Surface casing point has been picked at 3666' MD. POOH. 4. Run 13-3/8", 68# surface casing. Cement the casing to surface in 1 stage. No TAM port collar will be /' run. The risk of leak, and potential loss of hole, far outweighs the likelihood of not getting cement to surface in one stage. In the event the cement does not circulate to surface, please contact the Anchorage Drilling Team. 5. NO diverter / riser system and NU casing / multi-bowl wellhead. NU SOPE and test to 250/4800 psi.""'-- 6. MU 12-1/4" directional assembly. RIH to float collar. Test the 13-3/8" casing to 3500 psi with 9.3-ppg / mud for 30 min. This test pressure may change based on actual mud weight in the hole. 7. Drill out remaining cement. Drill 20' of new formation below 13-3/8" shoe and perform FIT to a minimum of 11.0 ppg EMW. (FIT/LOT procedure on file with AOGCC). 8. Drill 12-1/4" intermediate hole to casing point (approximately 11,694' MD) 60' MD into the top of the Miluveach. Minimum mud weight of 9.6 ppg at the top of HRZ and a minimum of 10.0 ppg at the top of Kuparuk. POOH. (No logs will be run, unless the Kuparuk is oil bearing.) 9. Run 9-5/8", 53.5# intermediate casing. Cement the casing to the top of the SV2 sand in a single stage. Set the 9 5/8" pack off. Perform a down-squeeze on the 9-5/8" x 13-3/8" annulus with 1 /" annular volume of mud upon installing and testing the packoff. Down-squeeze diesel to 2000' TVD for freeze protection after WOC. 10. MU 8-1/2" directional assembly and RIH to float collar. Pressure-test the 9-5/8" casing to 4750 psi ....-- with 10.3 ppg mud for 30 min. This test pressure may change based on the actual mud weight in the hole. 11. Drill out remaining cement. Drill 20' of new formation below 9-5/8" shoe and perform a FIT to a .-" minimum of 12.8 ppg EMW, (FIT/LOT procedure on file with AOGCC). 12. Ensure the mud is in good condition prior to drilling ahead. Drill the drilling liner hole to the top of the / Sag at approximately 13,382' MD. Intermediate casing point has been picked at 13,417' MD. POOH. 13. Run and cement a 7" 29# Hydril 511 drilling liner. Displace cement with mud. Set the liner hanger ../' and liner top packer. Circulate excess cement from well bore. 14. POOH and lay down liner running tools. Test 9 5/8" & 7" casing to 3360 psi for 30 minutes with 12.8 . ------- ppg fluid. This test pressure may change based on the actual mud weight in the hole. 15. RIH w/ 6" directional assembly. Clean out 7' liner to the landing collar. Displace to 9.1 ppg mud. 16. Drill out remaining cement. Drill 20' of new formation below 7" shoe with 9.1 ppg mud. Perform a Formation Integrity test to 11.5 ppg. (FIT/LOT procedure on file with AOGCC). 6'1 17 _ Drill 6" production interval to proposed TO at 13,932' MD. Increase mud weight t ~. '))... ppg prior to POOH. y · · While POOH, perform MAD Pass with lWD tools from TD to Top of Ivishak. , N523 Permit to Drill ) ) 18. POOH to the 7" liner shoe. Open circulation sub and circulate at maximum flowrate (630 to 750 GPM) for at least 1 bottoms up or until wellbore is clean. 19. Close circulation sub if applicable, pump dry job, and POOH. /' 20. RU wireline. Run USIT/CBL combo suite to confirm successful cement job of 7" liner. RD wireline. 21. Run and cement the 4-1/2" 12.6# 13Cr liner with a 2 7/8" inner string. Set the liner hanger and liner / top packer. Circulate a minimum of one bottoms-up to remove excess ~ent with a 9.3 ppg- viscosified brine. Ensure proper RAMS are run in the BOP for Well Control. Drill pipe elevators and a TIW crossover from 4 1/2" to DP will be on the rig floor at all times. · When pumping cement, "pump till you bump". If you do not bump the plug, circulate out the cement in preparation for another cement job. Discuss with Anchorage team. · Calculate circulating depth of inner string, while displacing well to seawater. · Attempt to keep distance from inner string circulating point to Landing Collar to less than 40'. /' 22. Once a successful cement job is obtained, pressure test liner lap to 1500 psi with 9.3 ppg mud to confirm pressure integrity. 62'·'···'''...... 23. Change well over to cleaë'á~a r thru the inner string (less than 80 NTU's) and by using spacers as per Baroid recommen ti· >,. ",., · Attempt to keep dist cé from inner string circulating point to Landing Collar to less than 40'. 24. Shut down and monitor the well for a minimum of 30 minutes (negative test on liner top). ~ 25. POOH. Close the blind rams and pressure-test the liner lap to 4370 psi with 8.65 ppg seawater ~ the well for 30 minutes. Prepare to suspend completion operations until after June 1st. Note: Assume 15.5 ppg LOT at 10,842' TVD liner lap. Test to 500 psi over LOT with seawater. 26. RIH to 100' below the base of the permafrost and circulate 6.8 ppg diesel to freeze protect the well to surface. POOH /~,.. 27. Install 7" tubing hanger and test to 6500 psi. 28. Set the TWC. ND BOP's. NU Tree. Test the tubing head adapter and tree to 6500 psi. 29. Pull TWC and install BPV (dry rod is acceptable). Test BPV from below to 4200 psi for 10 minutes./ 30. RD and move well to NS20. 31. Prepare for "Operations Shutdown. (June 1st Seasonal Drilling Restriction)" Prepare to re-enter well post "Seasonal DrillinQ Restriction." 32. Prepare to re-enter well post "Seasonal Drilling Restriction. " 33. MIRU Nabors 33E. 34. Verify there is no pressure on the tree. ND tree. a. The well was left with a TWC, tested to 4200 psi from below. 35. NU BOPE, pull the tubing hanger and run the test plug. Open annulus valve and test to 250/4800 psi. Test annular to 3500 psi. 36. Pull the test plug. Install the wear bushing. 37. RIH with 4" drillpipe to 2000' MD, circulating/displacing out diesel to the trip tank. Change over to seawater. a. Have G&I and rig crew line up Trip Tank#1 sump to G&I disposal pump suction. b. Coordinate with G&I and circulate one surface-to-surface volume of seawater, monitoring the volume in Trip Tank #1. c. When the Mud Engineer is satisfied with the water quality, the hole can be lined up elsewhere on the rig. d. POOH ¿ 2 r NS23 Permit to Drill ) ) · See Baroid Mud Program: Well Clean-out/Displacement Procedure. This well was suspended on July 15th, 2002. / 38. Test 9 5/8" x 7" liner to 4370 psi for 30 minutes. 39. Run the 4 ~" 18.8# L-80 x 4 %" 18.8# 13Cr-95 x 7" 32# T-95 tubing string. Ensure proper RAMS are // run in the BOP for Well Control. Drill pipe elevators and a TIW crossover from 4 1/2" to DP will be on the rig floor at all times. · Please Reference Completion Section · No fiber optics will be run on gas injectors. Note: Consider running a gauge ring inside the 4-1/2" liner if prior to running completion string if there are any indications that cement may have been left inside the liner during the cement job and change over to seawater. 40. The SCSSSV control line will be run from the Halliburton 7" HRQ SVLN at +/- 2000' TVD (2025' MD) to surface. a. Run two control lines on the safety valve landing nipples. b. Completely flush the SCSSV lines with hydraulic fluid. This may have been done at the service company facility. Verify that the line is full of fluid. c. Make up the SCSSV control lines to the landing nipple or valve. Test the lines to 5000 psi for 10 minutes. d. Strap the bare SCSSV control lines to the tubing with one stainless steel band per joint. Record the number of bands and clamps used on the completion tally/report and morning report. e. Do not splice the SCSSV control line. 41. RIH to packer setting depth. Record pick up and slack off weights. Tag up on the 4-1/2" ZXP liner , top packer with 5-10k. Regain full string weight and PU an additional 3' to confirm spaceout. This/ should leave the WLEG spaced out in the tie back extension +/- 7'. Space out pups should be placed 1 full joint below the tubing hanger. 42. Run space out pups and terminate the two 0.25" control lines. All lines will be secured using stainless steel bands. Land tubing with 5000 psi on control line. Land the hanger and RILDS. Pressure test the control lines to 5000 psi and tubing hanger seals to 6500 psi. 43. Rig up manifolding (chicksan/hose ) to allow U tube to equalize from the 7" x 4-1/2" by 9 5/8" x 7" annulus to the 7" tubing. 44. Displace corrosion inhibitor (Corexit 7726 25 gals/100 bbls) pill down the 7" x 4-1/2" by 9 5/8" x 7" annulus to treat from +/-4680' MD to packer setting depth. Displace annulus with heated inhibited diesel equivalent to annulus capacity plus tubing capacity to a depth of 4000' TVD (4680' MD). Maximum displacement rate 3 BPM as per Baker recommendation. 45. Allow diesel to U-tube and equalize. RD U-tube manifolding. 46. Drop ball and rod to set packer. Ensure that the proper ball size is dropped to match up with the RHC sub located in the 4-1/2" 18.8# RN Nipple. ~. 47. Increase the tubing pressure to 5800 psi (maximum anticipated surface injection pressure) with 8.5 ppg completion fluid and hold for 30 minutes. Monitor tubing pressure for leaks. Record on chart. 48. Contact AOGCC inspector to witness test. Bleed tubing to 2000 psi. and maintain during MIT. Pressure test 9 5/8" x 7" and 7" x 4-1/2" annulus to 5800 psi for AOGCC required mechanical integrity test (MIT). Monitor tubing pressure for leaks. Maintain pressure for 30 minutes and record annulus test on chart. Bleed off annulus and tubing. Fax chart and AOGCC MIT form to ODE. 49. Back out and lay down landing joint. Set the TWC valve in ABB-VGI 13 5/8" x 7" 6500 psi tubing hanger. Nipple down BOPs. Nipple up the 13 5/8" 6500 psi x 7 1/16" 6500 psi ABB-VGI tubing head adapter and ABB-VGI 7-1/16" 6500 psi tree. Install all flanges and needle valves. 50_ Test the tubing head adapter and tree to 6500 psi. Confirm that there is no pressure on the annulus. Dry rod the "two way" check. 51. Ensure all valves are closed. RD and move off well. 3 , NS23 Permit to Drill \} ') Post-Riq Work: 1. MIRU slickline. Pull the ball and rod / RHC profile from 'RN' nipple below the new production packer. 2. Perforate -200' Ivishak formation. /' Estimated Spud Date: April 1 ,2003 Floyd Hernandez Senior Drilling Engineer 564-5960 4 , NS23 Permit to Drill ) I ') NS23 WELL PLAN SUMMARY I Type of Well (producer or injector): I Injector // NS23 1269' FSL, 647' FEL, Sec. 11, T13N, R13E, UM X = 659826 Y = 6031042 2588' FSL, 4105' FEL, Sec. 2, T13N, R13E, UM X = 656222 Y = 6037565 10,900' TVDrkb 2832' FSL, 4231' FEL, Sec. 2, T13N, R13E, UM X = 656091 Y = 6037806 11,375' TVDrkb I AFE Number: 1831306 I Rig: 1 Nabors 33E ,// I I Estimated Start Date: 14/1/03 1 Operating days to complete: I 34.1 I I MD: 113923 I I TVDrkb: 111375 I I RKB/Surface Elevation: (a.m.s.l.) I 56.0' /15.9' 1 I Well Design (conventional, slimhole, etc.): I Modified Big Bore I I Objective: 1 Ivishak Gas injector for pressure maintenance, EOR, and reservoir sweep I Northstar Slot: Surface Location: Target (top of SAG): 300' Radius Bottom Hole Location: Well Name: API Number: Well Type (proposed): BHP: EMW: BHT: MECHANICAL CONDITION: Cellar box: RKB to Cellar box: Rig Elevation: Conductor: ~ ~- ~ NS23 Producer 5175 psi @ 11,100' TVDss 8.96 ppg 254 OF @ 11,100' TVDss Elevation above MSL = 15.9' 40.1' (Estimated) RKB + MSL = 56.0' 201' MDrkb of 20", 169#, X-56 (pre-driven) 5 · NS23 Permit to Drill ), ') / MUD PROGRAM: Suñace Hole Mud Properties: Seawater Spud Mud 16" Hole Section From Surface to -3667' MD / 3200' TVD (-150' TVD below top SV6). Interval Density Viscosity YP Tauo Gel APIFL pH (ppg) (seconds) 10 sec Initial 8.8 - 9.0 100 - 200 50 - 70 >8 25 - 40 15 - 20 8.5 - 9.5 from -1555' *9.0 - 9.5/ 100 - 200 30 - 45 >6 15 - 25 4 -10 8.5 - 9.5 SV6 @ Interval TD *9.5 75 - 100 20 - 35 >6 1 0 - 25 4 -10 8.5 - 9.5 * Should gas hydrates be encountered, mud densities up to 10.2 ppg may prove necessary. Intermediate Hole Mud Properties: Seawater Polymer From Surface Casing Shoe to 11694' MD / 9536' TVD. Interval Density (ppg) PV Initial 8.7 - 9.3 10 -16 Top HRZ 9.6 - 9.8 10 - 16 Top Kuparuk to Miluveach 10.0 - 10.3 /' 10- 18 12-1/4" Hole Section YP 20 - 30 20 - 25 20 - 28 Tauo API/ HTTP FL 4-7 6-10 4-7 4-6/<12 4-7 4-6/<12 pH 8.5 - 9.5 8.5- 9.5 8.5- 9.5 Drilling Liner Hole Mud Properties: Inhibited KCL 8-1/2" Hole Section From Intermediate Casing Shoe to 13417' MD /10,930 TVD (top of Sag) Interval Density (ppg) PV YP Tauo API FL pH Miluveach & Kingak to top of Sag 12.5 -13.5 /' 10 - 25 20 - 25 4 - 7 4-6/<10 8.5 - 9.5 Production Hole Mud Properties: Seawater/CaC03 Drill-In Fluid From Intermediate Casing Shoe to 13932' MD / 11,376' TVD Interval Density (ppg), PV YP Initial/Final 9.1 - 9.3 7 8 - 12 20 - 25 6" Hole Section Tauo API FL 4-7 3-5 pH 8.5 - 9.5 DIRECTIONAL:(P17) KOP: Maximum Hole Angle: Close Approach Wells: Survey Program: ±400' MD Cantenary curve 1 °/1 00' to 2.5°/100' build ±38.0° Surface- 10' well spacing to well NS22 and NS24 Gyro will be used for initial surveys and kickoff Gyros as required from surface to +/-1000'. IFR+MS corrected MWD surveys from +/-1000' to TD. This is required for target sizing. SURFACE AND ANTI-COLLISION ISSUES: All wells pass the major risk rule. Suñace Shut-in Wells: See Northstar Anti-Collision and Well Shut-In checklist. 6 ') ') , NS23 Permit to Drill LOGGING PROGRAM: 16" Section: Drilling: GR/Directional - Gyro as needed to -1000' MD. IFR-MS corrected surveys Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) Open Hole: None Cased Hole: None 12-1/4" Section: Drilling: GR/Directional, Resistivity (real-time), PWD. IFR-MS corrected surveys Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) Open Hole: PEX and RFT's - Contingent on oil being present in the Kuparuk. Cased Hole: None 8-1/2" Section: Drilling: GR/Directional, PWD. IFR-MS corrected surveys Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) Open Hole: ~ Cased Hole: V ICBL suite prior to suspension 6" Section: Drilling: GR/Directional, Resistivity/Density/Neutron (recorded). IFR-MS corrected surveys Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology samples (100' intervals) Open Hole: None Cased Hole: None InteQritv Testina: Test Point Depth Shoe Test EMW Estimated Type Casing/Liner Test 13 3/8" Surface 20' min from 12 1/4" FIT 11.0 ppg EMW Target 3500 psi wi 9.3 ppg shoe / 9 5/8" Intermediate 20' min from 9 5/8" shoe FIT 12.8 ppg EMW Target 4750 psi wi 10.3 ppg 7" Drilling Liner 20' min from 7" shoe FIT 11.5 ppg EMW Target 3360 psi wi 12.8 ppg 4 %" Production Liner N/A N/A N/A 4370 psi w/8.65 ppg CASING/TUBING PROGRAM: Hole Size Casing/ W~t Grade Conn. Casing Casing Top Hole Btm Tbg C.D. ./' Length MD/TVDrkb MD/TVDrkb 20" 20" 169# X-56 WELD 201' Surface 201 '/201' 16" 13 3/8" 68# L-80 BTC 3666' Surface 3666'/3200' 12 %" 9 5/8" 53.5# L-80 BTC-Mod 11694' Surface 11694'/9536' 8 %" 7" 29# L-80 Hydril 1873' 11544'/9418' 13417'/10930' 511 6" 4-1/2" 12.6# L-80 Vam Ace 665' 13267'/10799' 13932'/11376' Tubing 7" 32# T-95 ðt 11500' Surface 11500'/9171 ' Tubing 4-1/2" TBD TBD 1728' 11500'/9171 ' 13228'/10767' 7 ) ) . NS23 Permit to Drill FORMATION MARKERS: Top MDrkb Pore Press. Formation (TVDss) estimated (Psi) (ppg EMW) Comment Top Permafrost 1,149 1220 542 8.65 Base Permafrost 1,519 1627 708 8.65 SV6 . top confining zone 3,002 3487 1375 8.65 Surtace casing point 3,144 3667 1439 8.65 SV5 . base confining zone 3,259 3812 SV4 3,563 4197 1628 8.65 SV2 . top upper injection zone 31882 4602 1771 8.65 SV1 . top major shale barrier 41363 5211 1988 8.65 TMBK . top lower injection zone· Top Ugnu 4}37 5685 2156 8.65 WS1- top Schrader Bluff· Base Ugnu 6.416 7812 2911 8.65 CM3· Base lower injection zone (top Colville) 6,928 8461 3141 8.65 THRZ· Top HRZ 8,647 10639 3915 8.65 BHRZ . Base HRZ 8}07 10715 3942 8.65 Top Kuparuk 8,832 10874 4265 9.29 ,o.~ Kuparuk C 9,011 11100 4428 9.45 Top Miluveach 9.431 11632 Intermediate casing point 9,480 11695 Intermediate logging point 9.480 11695 Top Kingak 91862 12179 Top Sag River 10.844 13383 !~.( Geol target #1 10,844 13383 Geologic Target #1 300' radius Intermediate casing point 10,874 13418 5087 8.95 q.! Top Shublik· 90 10,964 13522 5015 8.8 Top Ivishak 11,020 13586 Total Depth 11 J 100 13679 5192 8.95 Oil- Water contact 11.100 13679 5192 8.95 Total Depth 111320 13932 5294 8.95 Total Depth 11.320 13932 5180 8.76 8 , N523 Permit to Drill ') REQUIRED MATERIALS: L-80 Suñace: 3666' 1 - 13 3/8" 1 - 13 3/8" 17 -133/8" x 15 3/4" 1 - 20" x 13 3/8" 1 - 13 5/8" L-80 Intermediate: 11694' 1 - 9 5/8" 1 - 9 5/8" 1 - set 1 - 13 5/8" x 9 5/8" 173 - 9 5/8" x 12" L-80 Drlg Liner: 1873' 1-8 %" 1-7" 6 - 7" x 8 1/4" 1 - 7" x 9 5/8" 1 - 7" x 9 5/8" 1 -7" 1 - 7" L-80 Liner: 665' 1 - 4-1/2" 1 - 4-1/2" 32 - 4-1/2" x 5-3/4" 16- 4-1/2" x 5-3/4" 1 - 4-1/2" x 7" 1 - 4-1/2" x 7" 1 - 4-1/2" Completion: 11500' 1728' 160' 1 1 1 1 1 1 2 1 ') 13 3/8", 68# L-80 BTC HES Super Seal II Float Shoe (4.25" valve) HES Super Seal II Float Collar (4.25" valve) SV Rigid Centralizers ABB-VGI Fluted hanger - BTC down, 11 %" external ACME landing thread ABB-VGI Casing Head/Tbg head 9 5/8", 53.5# L-80 BTC-MOD HES Super Seal II Floa9 Shoe HES Super Seal II Float Collar HES Cement Plug Set ABB-VGI Casing Hanger SV Rigid Centralizers 7", 29# L-80 Hydril 511 BBL reamer shoe HES Super Seal II Float Collar SV Rigid Centralizers Baker Flex Lock Hydraulic Set Liner Hanger - Rotating hanger. Baker ZXP Liner Top Packer Baker HRD running tool Baker Landing Collar and plug set 4-1/2", 12.6# L-80 Vam Ace HES Super Seal II Float Shoe HES Super Seal II Float Collar RH Turbulators Stop bands Baker Flex Lock Hydraulic Set Liner Hanger Baker ZXP Liner Top Packer Baker Landing Collar and plug set 7",32# T-95 Vam Top HC 4 %" 18.8# L-80 Vam Top HC 4-1/2" 18.8# T-95 Vam Top HC 7" ABB-VGI tubing hanger 7" ABB-VGI adapter flange 7" ABB-VGI 7" 6.5K Swab Valve w/ tree cap (for suspension) 7" SVLN and 2 - 0.25" control lines 7" x 4 %" Baker packer S-3, Vam Top HC 4 %" WLEG (Self Aligning) 4 %" R nipples 4 %" RN nipple PERMAFROST: The 13-3/8" surface casing will be run approximately 1600' TVD below the permafrost to -3666' MD / 3200' TVD. The casing will be cemented to surface with a Premium 'G' with 2% calcium chloride tail slurry and a Permafrost IL' lead slurry. The tail slurry allows sufficient compressive strength to prevent the shoe from breaking down as well as an accelerator to decrease thickening time. The lead slurry is light slurry that contains a freezing point depressant which enables the cement to set up rather than freeze. 9 · NS23 Permit to Drill ) ) CEMENT CALCULATIONS: The following cement calculations are based upon a single stage job with gauge hole. Casing 113-3/8" Surface I Basis: Stage 1: Lead: Based on 200' cased hole capacity from surface to 200' MD, 2717' of gauge open hole Lead TOG: Surface Tail: Based on 750' of 16" gauge open hole x 13 3/8" casing + 80' shoe joint. Tail TOG: -2917' MD I Total Cement / Spacer Preflush Spacer Lead 20 bbl sea water 75 bbl Alpþ8'fpacer wei~hted to 1.0 ppg over mud weight 416 bbll ~ ~k I 2336 fe of 10.7 ppg Permafrost 'L' Gement. 4.15 Cf/æ",a ST 50° I BHGT 50°, TT = 6.0 hrs 97 bbl 1.'47 k I 542 ftj of 15.8 ppg Premium 'G' wI 2% GaGI2. 1.16 cf' -;-SHST 50° I BHGT 50°, TT = 4.0 hrs Tail Casing 19-5/8" Intermediate Basis: Stage 1: Lead: Based on 5272' of 12 1/4" open hole x 9 5/8" csg Lead TOG: At -4602' MD Tail: Based on 1821' of 12 %" open hole x 9 5/8" csg + 80' shoe joint. Tail TOG: At -9874' MD IStage 1: Total Cement I Spacer Preflush Spacer Lead 20 bbls sea water 50 bbl AiP... . ..spacer weiQhted to 1.0 ppg over mud MW 382 bbll . sk I 2146 ftj of 11.2 ppg Econolite. 3.24 cf/sk . ST 210° I BHGT 130°, TT = 4.0 hrs 138 bbl 6 sk 1774 ft.j of 15.9 ppg Premium 'G'. 1.15 cfl '., HST 210° I BHGT 130°, TT = 4.0 hrs Tail Casing 17" Drilling Liner Basis: Stage 1: Slurry: Based on 1723' of 8 %" open hole x 7" csg + 150' 9 5/8" csg x 7" csg liner lap + 200' 9-5/8" csg x 5" drillpipe above TaL + 80' shoe joint. Slurry TOG: At -11545' MD Stage 1: Total Cement / Spacer Spacer 50 bbl Aæspacer weighted to 1.0 ppg over mud MW Slurry 74 bbl/, 7 sk/417 ft.j of 15.9 ppg Premium 'G'. 1.50 cfl '"";"'BHST 250° I BHGT 150°, TT = 4.0 hrs Casing 14-1/2" Prod Liner Basis: Stage 1: Slurry: Based on 514' of 6 1/8" open hole x 4 1/2" csg with 50% excess + 150' 7" csg x 4 1/2" csg liner lap + 200' 7" csg x 4" drillpipe above TaL + 80' shoe joint. Slurry TOG: At -13268' MD Stage 1: Total Cement 1 Spacer Spacer 35 bbl ~spacer ~eighted to 1.0 ppg over mud MW Slurry 25 bbll k 1143 ftj of 15.9 ppg Premium 'G'. 1.50 cf ,BHST 250° I BHGT 150°, TT = 4.0 hrs 10 NS23 Permit to Drill ) ') WELL CONTROL: ~ A Diverter waiver has been requested on well NS23. To date, BP has drilled 20 development wells through the Northstar upper stratagraphic intervals and has not experienced any difficulty with shallow gas. 20 surface holes have been drilled and cemented to a common depth of approximately 3,170' tvdss depth. Each surface shoe has been set in the competent shale horizon approximately 150' TVD below the top of the SV6 formation marker. Well mud logs and seismic data do not indicate the presence of a shallow gas hazard. ~ Equipment to be Installed and capable of handling maximum potential surface pressures. (Schematics are on file with the AOGCC and MMS.) ~ 5000 psi working pressure pipe rams (2) ~ Blind/shear rams ~ Annular preventer ~ Based upon the calculations below, BOP equipment will be tested to 4800 psi. Suñace Section: · Maximum anticipated BHP: 1373 psi @ 2996' TVDss - SV6 · Maximum surface pressure: 1073 psi @ surface (Based on BHP and a full column of gas from TD @ 0.1 psi/ft) Intermediate Section: · Maximum anticipated BHP: 4428 psi @ 8827' TVDss - Kuparuk IC' · Maximum surface pressure: 3545 psi @ surface (Based on BHP and a full column of gas from TD @ 0.1 psi/ft) Drilling Liner Section: · Maximum anticipated BHP: 5084 psi @ 10868' TVDss - Sag River · Maximum surface pressure: 3997 psi @ surface (Based on BHP and a full column of gas from TD @ 0.1 psi/ft) Production Section: · Maximum anticipated BHP: ~æ' i@11275'TVDss-TotaIDepth · Maximum surface pressure: 15 si @ surface (Based on BHP and a full column . from TD @ 0.1 psi/ft) " · Planned BOP test pressure: 4800 psi (annular to 3500 psi) · Planned completion fluid: 8.5 ppg Seawater / 6.8 ppg Diesel DRILLING HAZARDS/CONTINGENCIES: HYDROGEN SULFIDE - H2S: ./' Northstar is not designated as an H2S drill site, however Standard Operating Procedures for H2S precautions should be followed at all times. ./' No H2S was detected at Northstar while drilling or testing the Seal Island A-01, A-02, or A- 03 exploration/appraisal wells. ./' No H2S was detected while drilling the NS10 waste disposal well, or any subsequent Northstar wells. Reference information below on file with AOGCC: ~ Northstar/Nabors 33E H2S contingency plan. ~ Well test hydrocarbon analyses for Seal Island A-01, A-02, and A-03. DISPOSAL: Annular Injection: There will be no annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be processed in the Grind and Inject Facility on Nabors 33E and will be disposed of in the NS10 Class I Waste Disposal Well. Fluid Handling: All Class I and Class II fluids will be processed by the Grind and Inject Facility on Nabors 33E and will be disposed of in the Northstar NS1 0 Class I Waste Disposal Well. 11 , NS23 Permit to Drill ) ) · SURFACE HOLE SECTION: Mudloggers will be rigged up throughout the entire section. No significant drilling problems have been identified in the surface hole interval based on offset data. Good hole cleaning and management of required mud properties are key to a successful interval. Minor tight hole conditions have been noted in the shale intervals immediately below the permafrost during short trips. Differential sticking could be problematic in this hole section adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods; tighten fluid loss properties of mud. Lost circulation has only been noted while drilling during hole opening runs and was most likely induced by poor hole cleaning. Losses have occurred while running and cementing surface casing. The NS27 experienced losses on the surface cement job at a rate of 12 BPM. The displacement rate was lowered to 10 BPM and full returns were re-established. Be sure to condition and thin mud appropriately prior to pulling out of the hole to run casing, and once on bottom with casing, bring circulation up slowly and reduce mud viscosities before pumping cement. Minor losses were seen on NS29 while running the 13 3/8" surface casing. Reduced running speed eliminated losses and the casing was cemented at 10 BPM displacement rate. Gas hydrates may be present near the base of the permafrost. Wells drilled in the 2000-2002 drilling season have not experienced hydrates. Mudloggers will be used continuously on NS23 to help identify and trend any increase in background gas readings. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. · · · · · · INTERMEDIATE SECTION: Mudloggers will be rigged up throughout the entire section. Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. No indications of shallow gas were seen while drilling during the 2000-2002 drilling season. Mudloggers will be used continuously on this well to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. A minimum of 9.0 ppg is recommended. The shallow intervals beneath Northstar are, by interpretation, not faulted. To be prepared for any potential lost circulation, a copy of the 'Non-Payzone Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the rig. Pressure While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent circulating density (ECD), minimize lost circulation due to packing off due to loading up the well bore with solids and provide for an additional well control tool to make sure the well does not become under-balanced. Differential sticking can be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable SV Sands. Gas in the Kuparuk is likely (5000 unit mud log show in NS13). Circulate as required. High mud weight should minimize the gas entry from the Kuparuk. Oil is not expected in the Kuparuk, however, if oil is found be prepared to run wireline logs to evaluate. ~ The kick tolerance for the 12 1/4" open hole section would be 18. bbls assuming an influx from the Kuparuk interval at -8725 TVD. This is the worst-cas . -nario based on a 9.96 ppg (0.5 ppg over the known pore pressure) pore pressure gradien , a fracture gradient (Fin of 12.5 ppg at the 13-3/8" shoe, and 10.3 ppg mud in the hole. · · · · · · · 12 ) ') NS23 Permit to Drill DRilLING LINER SECTION: · Mudloggers will be rigged up throughout the entire section. · Pressure While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent circulating density (ECD), minimize lost circulation due to packing off due to loading up the wellbore with solids and provide for an additional well control tool to make sure the well does not become under-balanced. · Gas in the Sag is possible. Circulate as required. According to Geology, the top of the Sag is poor, not porous/permeable rock. This, along with the higher mud weight should minimize the gas in the top of the SAG. · One (1) seismic-scale fault is likely (80% probability) to be encountered in this well bore, Fault 18. Penetration is expected at - 9390 TVDss +/- 400' TVDss; within the Miluveach Formation. Displacement on this fault at the point of penetration should be approximately 20-40 feet. This fault was penetrated by NS15 (in the Upper Kingak) without incident. Be prepared for any potential lost circulation, a copy of the 'Non-Payzone Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which c found on the Rig. · The kick tolerance for the 8-1/2" open hole section is nfin' (due to limited amount of open hole) assuming an influx from the Sag River interval. ]:1" IS the worst-case scenario based on a 9.45 ppg (0.5 ppg over the anticipated pore pressure) pore pressure gradient, a fracture gradient of 13.5 ppg at the 9-5/8" shoe, and 12.9 ppg mud in the hole. PRODUCTION SECTION: · Mudloggers will be rigged up throughout the entire section. Gas in the Sag River or Ivishak will be circulated out as required. · The drilling liner shoe will be drilled out with 9.3 ppg mud. The mud will then be displaced with a 9.1 ppg drill-in fluid. The mud weight will be increased to 9.3 ppg prior to tripping out of the hole. · Differential sticking is not anticipated but the drill string should not be left stationary for any length of time. · Potential losses will be treated with the "Pay-zone" loss circulation decision tree. · The well is planned penetrate the OWC. The Kavi will not be penetrated. The project Geologist will be in charge of picking TD. · The kick tolerance for the 6" open hole section is . fi e (due to limited amount of open hole) assuming an influx from the proposed TD. This na~io is based on a 9.45 ppg (0.5 ppg over the anticipated pore pressure) pore pressure gradl t, a fracture gradient of 11.5 ppg (based on FIT) at the 7" shoe, and 9.1 ppg mud in the hole. 13 NS23 Permit to Drill ) ) NS23 RiQ-site Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE "'-f Mudloggers will be used continuously on NS23 to help identify and trend any increase in background gas readings ~ Gas hydrates may be present near the base of the permafrost. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to .....450 to 500 gpm and keeping the mud temperature cool. ~ Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. No indication of shallow gas was seen in any previously drilled Northstar wells. . Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. "'-f Differential sticking could be problematic in both the surface and intermediate hole sections adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods; tighten fluid loss properties of mud. "'-f Severe losses have been seen in the intermediate section with a higher mud weight (11.6 ppg). The well design has been changed to alleviate this problem. The new casing design sets the 9 5/8" casing in the Miluveach and drills out with an 8 %" assembly to the Top Sag to allow an appropriate cushion for mud weight increases in the Jurassic shale interval. However, lost circulation has been seen in both the 12 %" and 8 %" hole sections. Be prepared for any potential lost circulation situation. The 'Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the Rig. "'-f Packing off due to improper hole cleaning can lead to stuck pipe. The PWD data, pick-up/slack-off weights and other drilling parameters must be monitored at all times. If in doubt, stop and condition the hole prior to drilling ahead or tripping. "'-f Bit balling has been experienced in the Miluveach. The mud properties and PDC bit selection will be closely monitored to minimize potential balling. "'-f One (1) seismic-scale fault is likely (80% probability) to be encountered in this well bore, Fault 18. Penetration is expected at - 9390 TVDss +1- 400' TVDss; within the Miluveach Formation. Displacement on this fault at the point of penetration should be approximately 20-40 feet. This fault was penetrated by NS15 (in the Upper Kingak) without incident. Be prepared for any potential lost circulation, a copy of the 'Non-Payzone Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the Rig. ..J The Kingak shale, in the offset Seal Island wells drilled by Shell, experienced severe hole instability. The casing shoe at the base of the Kuparuk, higher mud weight and lower angles will help with hole conditions. ..J Conglomerate drilling in the Ivishak can lead to lost circulation, packing off due to unconsolidated formation and directional problems due to deflection of the drill string off of large rocks. Key drilling parameters must be monitored at all times. Do not drill ahead if a potential problem is detected. Severe lost returns were experienced on the NS29 in the Shublik and Ivishak. The LCM decision tree will be maintained on the rig as well as in the Master Well Plan. ..J Northstar is not a designated H2S pad. ./ . CONSULT THE NORTHSTAR PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 14 TREE: ABB-VGI 7" 6.5ksi ) WELLHEAD: ABB-VGI13-5/8" Multibowl6.5ksi )IGINAL KB. ELEV = 55.8' KB-BF. ELEV = 40.4' BF ELEV = 15.4' 7"32# H RQ SVLN @ 2000' TVD (Incaloy-925 P-11 0 Vam Top HC) 5.963" 10 6.8PPG DIESEL FREEZE PROTECTION AT +/- 4000' TVD (4680'MD) NS23 - Proposed 13 3/8", 68#/ft, L-80, BTC @ 3666' M 0 ~ 7", 32#/ft, T -95 Tubing 106.094" .- Tubing Drift 5.969" Capacity: 0.0361 bbllft 4 Joints of 4-1/2" 18.8#/ft 13CR-95 Vam Top HC across the 7" liner top and between the 7" T-95 and 4-1/2" L-80 tubing ~ r 9-5/8" 53.5# L-80 BTM-C @ 11694' MD 4.5" R NIPPLE (3.437" 10) , 18.8# 9CR-80 Vam Top HC @ 13205' MD I E 4.5" R NIPPLE (3.437" 10) , 18.8# 9CR-80 Vam Top HC @ 13250' MD 4.5" RN NIPPLE, (3.260" No-Go) -------:! 18.8# 9CR-80 ~ Vam Top HC@ 13261' MD 7" I 29#1ft L-80, H yd ril 511 @ 13417' MD ~ PBTD @ 13928' MD TO @ 13932' MD L DATE 3/21/03 REV. BY COMMENTS FH ~~23 ~roposed ~ .. / ~ - 7" LINER TOP @ 11544' MD 4 1/2",18.8#1ft; L-80 Vam Top HC .-- TU BING 10: 3.640" Tubing Drift: 3.515" CAPACITY: 0.0129 bbllft . -;;- - 7" PACKER, @ 13225' MD .- 4.5" 12.6# (3.958" ID)13CR-80 ,------- E WLEG, @ 13272' MD 4.5" LINER TOP @ 13267' MD .. 4.5" 12.6#, L-80 Vam Ace Northstar W~~ ~ : NS.~3 API NO: 50-0~9- BP Exploration (Alaska) õ I KSE KOP Sid 1/100 Bid 2/100 Crv 2.5/100 Top Perm Sase Perm Report Date: Client: Field: Structure I Slot: Well: Borehole: UWl/API#: Survey Name I Date: Tort I AHD I DOlI ERD ratio: Grid Coordinate System: Location LatlLong: Location Grid NJE YIX: Grid Convergence Angle: Grid Scale Factor: NS23 Proposed Well Profile - Geodetic Report Mlu_. March 13, 2003 Survey I DLS Computation Method: BP Exploration Alaska Vertical Section Azimuth: Northstar d Vertical Section Origin: Northstar PF / NS23 I-ty stu Y TVD Reference Datum: NS23 _I b _I 1 TVD Reference Elevation: NS23 Feas Sea Bed I Ground level Elevation: 50-029- Magnetic Declination: NS23 (P17) S06 I March 13,2003 Total Field Strength: 46.713° /7733.97 ft /5.646 10.68C Magnetic Dip: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: N 70.49135092, W 148.6933160S Magnetic Declination Model: N 6031041.560 ftUS, E 659826.260 ftUS North Reference: +1.23169248° Total Corr Mag North -> True North: 0.99992902 local Coordinates Referenced To: Station ID MD (ft) 0.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1219.95 1300.00 1400.00 1500.00 1600.00 1626.31 1700.00 1800.00 1900.00 End Crv 1973.11 NS23 (P17) report.xls Incl (; 0.00 0.00 1.00 3.00 5.00 7.00 9.20 11.53 13.91 16.33 18.77 19.26 21.22 23.68 26.15 28.63 29.28 31.10 33.59 36.07 37.89 Azim I (0) 305.00 305.00 305.00 305.00 305.00 305.00 313.48 318.64 322.07 324.51 326.33 326.64 327.75 328.88 329.81 330.59 330.78 331.26 331.83 332.34 TVD (ft) 0.00 300.00 399.99 499.93 599.68 699.13 798.13 896.49 994.03 1090.56 1185.90 1204.77 1279.87 1372.28 1462.97 1551.75 1574.77 1638.47 1722.94 1805.03 332.67 1863.43 VSec (ft) 0.00 0.00 0.78 3.88 10.07 19.36 32.34 49.62 71.16 96.92 126.85 133.32 160.89 198.99 241.06 287.03 299.76 336.80 390.30 447.40 NI-S (ft) 0.00 0.00 0.50 2.50 6.50 12.50 21.50 34.50 51.48 72.41 97.25 102.67 125.95 158.46 194.70 234.63 245.73 278.15 325.19 375.65 EI-W (ft) 0.00 0.00 -0.71 -3.57 -9.29 -17.85 -28.64 -41.05 -55.04 -70.59 -87.67 -91.26 -106.25 -126.29 -147.76 -170.60 -176.84 -194.79 -220.27 -247.00 491.37 414.66 -267.30 Schlumberger Private Page 1 of 2 DlS (°/1000) 0.00 0.00 1.00 2.00 2.00 2.00 2.50 ~.50 2.50 2.50 Minimum Curvature I Lubinski 332.320° N 0.000 ft, E 0.000 ft KB 55.8 ft relative to MSL 15.670 ft relative to MSL 26.007° 57553.264 n T 80.953° April 01, 2003 BGGM 2002 True North +26.00r Well Head "--- Grid Coordinates Northing I Eastlng (OOS) (ftUS) 6031041.56 659826.26 6031041.56 659826.26 6031042.04 659825.54 6031043.98 659822.64 6031047.86 659816.83 Geographic Coordinates latitude I longitude N 70.49135092 W 148.69331609 N 70.49135092 W 148.69331609 N 70.49135228 W 148.69332189 N 70.49135775 W 148.69334527 N 70.49136867 W 148.69339203 659808.15 N 70.49138506 W 148.69346200 659797.17 N 70.49140965 W 148.69355020 659784.48 N 70.49144517 W 148.69365164 659770.13 N 70.49149155 W 148.69376600 659754.14 N 70.49154873 W 148.69389312 659736.53 N 70.49161659 W 148.69403274 659732.82 N 70.49163140 W 148.69406208 659717.34 N 70.49169499 W 148.69418462 659696.60 N 70.49178381 W 148.69434844 659674.36 N 70.49188281 W 148.69452395 659650.67 N 70.49199189 W 148.69471066 659644.19 N 70.49202221 W 148.69476167 659625.55 N 70.49211078 W 148.69490841 659599.07 N 70.49223928 W 148.69511671 659571.26 N 70.49237713 W 148.69533523 2.50 6031450.35 659550.13 N 70.49248370 W 148.69550119 3/13/2003-10:00 AM 6031053.67 6031062.44 6031075.17 6031091.84 6031112.43 2.50 2.50 2.50 2.50 2.50 6031136.90 6031142.24 6031165.19 6031197.26 6031233.02 2.50 2.50 2.50 2.50 2.50 6031272.45 6031283.41 6031315.44 6031361.92 6031411.79 Grid Coordinates Geographic Coordinates I Station ID MD Incl Azim TVD vSec NI-S EI·W I DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/10Oft) (ftUS) (ftUS) SV6 3486.39 37.89 332.67 3057.77 1420.63 1240.23 -693.90 0.00 6032266.50 659105.91 N 70.49473897 W 148.69898916 13-3/8" Csg pt 3666.30 37.89 332.67 3199.77 1531.11 1338.38 -744.62 0.00 6032363.53 659053.10 N 70.49500709 W 148.69940391 SV5 3812.01 37.89 332.67 3314.77 1620.59 1417.87 -785.70 0.00 6032442.11 659010.32 N 70.49522423 W 148.69973983 SV4 4197.19 37.89 332.67 3618.77 1857.12 1628.01 -894.29 0.00 6032649.85 658897.25 N 70.49579827 W 148.70062785 SV2 4601.38 37.89 332.67 3937.77 2105.31 1848.51 -1008.23 0.00 6032867.84 658778.60 N 70.49640061 W 148.70155968 SV1 5210.82 37.89 332.67 4418.77 2479.56 2180.99 -1180.04 0.00 6033196.52 658599.70 N 70.49730883 W 148.70296488 TMBK 5684.70 37.89 332.67 4792.77 2770.55 2439.51 -1313.63 0.00 6033452.09 658460.59 N 70.49801501 W 148.70405757 WS1 7812.05 37.89 332.67 6471.77 4076.89 3600.09 -1913.35 0.00 6034599.43 657836.11 N 70.50118520 W 148.70896389 CM3 8460.78 37.89 332.67 6983.77 4475.26 3954.00 -2096.23 0.00 6034949.30 657645.68 N 70.50215190 W 148.71046033 THRZ 10638.81 37.89 332.67 8702.77 5812.72 5142.22 -2710.24 0.00 6036123.96 657006.32 N 70.50539742 W 148.71548562 BHRZ 10714.84 37.89 332.67 8762.77 5859.41 5183.70 -2731.67 0.00 6036164.97 656984.00 N 70.50551071 W 148.71566104 - Kuparuk 10873.22 37.89 332.67 8887.77 5956.66 5270.10 -2776.32 0.00 6036250.38 656937.51 N 70.50574670 W 148.71602654 KupC 11100.02 37.89 332.67 9066.77 6095.93 5393.83 -2840.26 0.00 6036372.70 656870.93 N 70.50608465 W 148.71654996 TMLV 11632.17 37.89 332.67 9486.77 6422.71 5684.15 -2990.28 0.00 6036659.71 656714.71 N 70.50687760 W 148.71777810 9-5/8" Csg Pt 11694.26 37.89 332.67 9535.77 6460.84 5718.02 -3007.78 0.00 6036693.19 656696.49 N 70.50697011 W 148.71792137 TKNG 12178.27 37.89 332.67 9917.77 6758.05 5982.07 -3144.23 0.00 6036954.23 656554.41 N 70.50769131 W 148.71903852 Drp 1/100 12594.31 37.89 332.67 10246.13 7013.53 6209.04 -3261.52 0.00 6037178.61 656432.28 N 70.50831122 W 148.71999887 12600.00 37.83 332.67 10250.62 7017.03 6212.14 -3263.12 1.00 6037181.67 656430.61 N 70.50831969 W 148.72001197 12700.00 36.83 332.67 10330.14 7077.66 6266.01 -3290.96 1.00 6037234.93 656401.62 N 70.50846682 W 148.72023992 12800.00 35.83 332.67 10410.70 7136.90 6318.64 -3318.15 1.00 6037286.96 656373.31 N 70.50861056 W 148.72046256 12900.00 34.83 332.68 10492.29 7194.73 6370.02 -3344.69 1.00 6037337.75 656345.67 N 70.50875090 W 148.72067988 13000.00 33.83 332.68 10574.87 7251.12 6420.12 -3370.58 1.00 6037387.28 656318.71 N 70.50888773 W 148.72089188 13100.00 32.83 332.68 10658.42 7306.06 6468.93 -3395.80 1.00 6037435.53 656292.45 N 70.50902104 W 148.72109839 13200.00 31.83 332.68 10742.92 7359.54 6516.44 -3420.35 1.00 6037482.50 656266.89 N 70.50915080 W 148.72129942 13300.00 30.83 332.68 10828.34 7411.53 6562.63 -3444.21 1.00 6037528.17 656242.04 N 70.50927696 W 148.72149481 Sag River 13382.82 30.00 332.68 10899.76 7453.45 6599.88 -3463.45 1.00 6037564.99 656222.01 N 70.50937869 W 148.72165236 End Drp I Tgt 13382.83 30.00 332.68 10899.77 7453.46 6599.89 -3463.46 1.00 6037565.00 656222.00 N 70.50937872 W 148.72165244 / 7" Csg pt 13417.47 30.00 332.68 10929.77 7470.78 6615.28 -3471.41 0.00 6037580.21 656213.72 N 70.50942075 W 148.72171754 -- Shublik 13521.40 30.00 332.68 11019.77 7522.74 6661.44 -3495.25 0.00 6037625.85 656188.89 N 70.50954683 W 148.72191277 Ivishak 13586.06 30.00 332.68 11075.77 7555.07 6690.17 -3510.09 0.00 6037654.25 656173.44 N 70.50962529 W 148.72203429 OWC 13678.44 30.00 332.68 11155.77 7601.26 6731.21 -3531.29 0.00 6037694.82 656151.36 N 70.50973738 W 148.72220790 TD 13932.47 30.00 332.68 11375.77 7728.27 6844.05 -3589.59 0.00 6037806.38 656090.66 N 70.51004557 W 148.72268534 Leaal Description: Northina (Y) rftUSl Eastina (X) mUSl Surface: 1269 F8L 647 FEL 811 T13N R13E UM 6031041.56 659826.26 Target: 2588 FSL 4105 FEL 82 T13N R13E UM 6037565.00 656222.00 BHL: 2832 FSL 4231 FEL S2 T13N R13E UM 6037806.38 656090.66 8chlumberger Private NS23 (P17) report.xls Page 2 of 2 3/13/2003-10:00 AM I I I II KOP Bid 11100 I / 300 MD 300 TVD I V 0.00' 305.00' ~z I 0--- ---Ff¿~~-----¡---------------- I '~;~~1~~9TVD I i 7.rYJ' 305.00' az I - 19depãrture - -¡ T-;;¡' P;-rm 1220MD 120STVD- End Cry -.j i ~19T3MD 1ã63TVD- I S-;"'Pe,m1626MD1575TVD '--1- ':~;~~:P;~~;::":::,"::~:""""""""r"-' ,. I / 3666 MD 3200 TVD11 37.69' 332,67' az -+ 1531 departure J -1 =~'v= = = = = = = J::::::::= -+ - - - - - - - - - ~sV;¡ 4197MD 3619TVD- 4000 ..........=_...,,=..,=.....::~--:--46Õt-Mi):oo9ë.fiTe.....:::_...=... 7.;...."":::::"..";:::::_...::::..""::::.......:::_".d,..::::._.:::;,....,:::;-......=....,:::.."..::::......:;::,...::;;:::,....:;;;,...;;;:;",.::::;;" -...,'''..,-..........''.. I I - - - - lV15iITMÕ44Ï9TVõ - - - - - - - l - - - - - - - - - - - ITMBK š68s MD 4793TVD- '"l I ¡ I I ,·"I-i··"· iwS1 7812 Mõ 6472 TVD - I ----t~~~~®--------l I I I I 1- .. . -..,..---..--t- - ..!!:~~·~P.tllt~..._.._"..... I I ~ ~~~;M~32~~:e~VD I I 6461 departure ====1 ~~~fiAB~~=1= ========= -+ _l{u~ru~08~'M~ ~T..':'.D J _ _ _ _ _ _ _ _ I t<upC 11100MD 9087TVD J ~ ~~:.:~~ 10246TVD ì -TM"CV Tl63TMtY1W!TTIIU I ~' - - l37 89"'" 33767' az : I -: l> - 1 0000 ~-"-=--=4--'-_=-7--=-=_=--d~'''Ld-=-=-=_=-7-=--''"1··7_-'-_- - =- _.C-~7. ~~:~œoo,,' 30:00' 33268' az ~ ! 7453 departure - =,"~g PI =13m MD 10930 TVD 30.00' 332.68' az 7471 departure 2000 _. ...- +-' Q) - .ææ g:æE ~ ~ II ..8 .£: CO ~~ .......r-- .r;.1'-: ë.~ ())........ Oca -~ ~~ :e~ ~ > ())~ ::JW L.. ~ 6000 _.. 8000 _. 12000 -- ) ') VERTICAL SECTION VIEW Client: BP Exploration Alaska Well: NS23 (P17) Field: Northstar Structure: Northstar PF Section At: 332.32 deg Date: March 13, 2003 Schlumberger r--- . --r Hold Ang e 37.89° t·- ---------- --------- J. - i -Sa"ORiver 13383l'ID TOOOUTXQ; - - - - - - -, - - l~'~MÕ"~fio~'" '""iJ''£~W¡¡@ ,,'1'10 "," - --I· I TD ,~MO '11376TVD 30.00' 332.68' az 7728 depar1ure I o I ¡ I 2000 I 4000 I 6000 ~ 8000 Vertical Section Departure at 332.32 deg from (0.0, 0.0). (1 in = 2000 feet) "'..".,...-......",..."'...-"..".. , ¡' ~...,.._.".....".. "........."..... ..- --. , .. -..- 6000 NI I I .,...j I"'·" I I I I I I 1-·..- . ..,_. .. - 4000 I I I ."..... i ~....,..., t I Ii I I . 1-- . . I I 1----1- , I I I I I ¡ , '....' "" " 1000--..--- ! J' . I / :;~'",~:."" ¡_______.__ l I (}/ "1" ,<ow , ,__".__.___..___ I I <l" ,\ ¡ I I --- _._._-L.. \! I : ---------- ' ' , ._ __,___ ___ ! End Cry I i II ....------ __L..!~?~~ 1863 TV I ' , ' ".... m<ii"/'- 1 000 1 I' "" ""w ! I ,~,,~,~ I ' 700MQ 699TVD ~ Bid 21100 , "'" ".00" ~ """" ,.._ J. 12N..18.W . .~ 100" 400TVD I· I" ,::'~'~ ¡ .=.t""~ I · .' '''HVO~ -3000 I .::' ¡~OO"~ ... -2000 I -1000 -0 - 2000 - 3000 - 5000 - 7000 lehlulDblrDlr EAST »> «< WEST I o I -4000 0-.. I ~ ::J o (f) V ~ 2000 -......-... o , I I 1'-" 5000 _.... ,'. -:5 =õ- ~. .."..,...,,,.,.....,1J,.....,.. .., , tfJ. ~ '61 ~o 3000 -.........."".,........-. ^ ^ ^ I ~ c:::: o z Ii True North Mag Dee ( '" "" ",,-1 13383MD 10000TVD I 30.00' 332,68' az 6600 N 3463 W Drp 11100 I 12594MD 10246TVp 37.89' 332.67' az I 6200 N 3262 W 7" C¡g PI 6000 -,····-t~:wMf-32~~~IY.º...,........,..,-,... 8615 N 3471 W 7000 _I~ª?.j..º..Jm~.1:yº.,. 30.00' 32,68' az 6844 N 3590 W -2000 . -3000 . -1000 -4000 Alaska VIEW BP Exploration NS23 (P17) Northstar Northstar PF 1 in = 1000 ft 13 -Mar- 2003 PLAN Client: Well : Field: Structure: Scale: Date: ') ') ) BP Exploration Alaska Anticollision Report :.::,:.;.::F.ÇR}.~Þ>,'.ed.;r·~.~e·a.:.:.;,,:.Y.·~....·::.·s:.;,:.'..·.¡,··t.'.:e:... ,.:.:..............11.: 'r~t~j, "/" ,,~~ :;N9ðb~t~(~F · '; ::;::=:,:~~:~:~:::~~t~i",¡g,~RiN$d3r;' "',, ) . , . . NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 40.20 to 13932.47 ft Maximum Radius: 3000.00 ft Survey Program for Definitive Wellpath Date: 3/18/2002 Validated: No Planned From To Survey ft ft 40.20 1000.00 Planned: Plan #17 V1 1000.00 13932.47 Planned: Plan #17 V1 Casing Points Version: 26 T oolcode GYD-GC-SS MWD+IFR+MS Reference: Error Model: Scan Method: Error Surface: Tool Name Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Gyrodata gyro single shots MWD + IFR + Multi Station 3666.30 3199.77 13.375 16.000 13 3/8" 11694.26 9535.77 9.625 12.250 95/8" 13417.47 10929.77 7.000 8.500 7" 13932.47 11375.77 4.500 6.125 4 1/2" Summary Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Seal Island Seal Island Seal Island Seal Island Seal Island NS06 NS07 NS08 NS09 NS10 NS12 NS13 NS14 NS15 NS16 NS17 NS18 NS19 NS20 NS21 NS22 NS24 NS25 NS26 NS27 NS29 NS31 NS32 NS35 SEAL-A-01 SEAL-A-02 SEAL-A-02 SEAL-A-03 SEAL-A-04 NS06 V34 NS07 V33 NS08 V18 NS09 V14 NS10 V17 NS12 V25 Plan: Plan #1 NS13 V12 NS14 V11 NS15 V19 NS16 V36 Plan: Plan #1 NS17 V12 NS18 V12 NS19 V14 Plan: Plan #8 NS20 V1 0 NS21 V46 NS22 V13 NS24 V15 Plan NS25 V6 Plan: Pia NS26 V22 NS27 V29 NS29 V22 NS31 V14 Plan NS32 V2 Plan: Pia Plan NS35 V1 Plan: Pia SEAL-A-01 V4 SEAL-A-02 VO SEAL-A-02A V4 SEAL-A-03 V4 SEAL-A-04 V4 'f~rl~lf~.: 397.86 149.64 299.76 446.65 544.58 398.32 398.45 448.15 399.00 497.45 398.73 449.04 349.05 449.81 748.15 49.26 549.74 550.14 700.77 650.92 1934.93 853.30 807.06 1288.58 1482.20 1483.92 1483.81 1480.70 1540.14 Ohšef' ·':.Mb<:: , 'iift," 400.00 150.00 300.00 450.00 550.00 400.00 400.00 450.00 400.00 500.00 400.00 450.00 350.00 450.00 750.00 50.00 550.00 550.00 700.00 650.00 1900.00 850.00 800.00 1250.00 1450.00 1450.00 1450.00 1450.00 1500.00 i¡~1;~~l 171.57 7.32 161.40 3.12 149.96 5.50 145.35 7.60 124.29 8.58 105.41 7.76 103.59 7.11 88.03 8.17 81.73 7.24 71.15 10.11 62.48 6.55 49.09 9.00 39.01 6.44 30.97 7.34 15.99 13.51 10.07 1.36 10.96 9.56 19.72 9.84 24.10 11.50 35.49 12.14 49.62 39.54 69.18 15.17 79.22 14.88 130.40 30.28 192.95 26.39 169.07 27.82 171.46 24.46 178.14 22.68 227.39 26.45 ..·;~~~:Mt}~~~~~~, 164.26 Pass: Major Risk 158.28 Pass: Major Risk 144.47 Pass: Major Risk 137.76 Pass: Major Risk 115.77 Pass: Major Risk 97.66 Pass: Major Risk 96.48 Pass: Major Risk 79.87 Pass: Major Risk 74.49 Pass: Major Risk 61.04 Pass: Major Risk 55.94 Pass: Major Risk 40.10 Pass: Major Risk 32.57 Pass: Major Risk 23.64 Pass: Major Risk 2.54 Pass: Major Risk 8.71 Pass: Major Risk 1.42 Pass: Major Risk 9.91 Pass: Major Risk 12.61 Pass: Major Risk 23.37 Pass: Major Risk 15.81 Pass: Major Risk 54.01 Pass: Major Risk 64.35 Pass: Major Risk 101 .31 Pass: Major Risk 166.58 Pass: Major Risk 141.27 Pass: Major Risk 147.03 Pass: Major Risk 155.51 Pass: Major Risk 200.98 Pass: Major Risk Site: Northstar PF Drilling Target Conf.: 99% Description: Sag Tgt Map Northing: 6037565.00 ft Map Basting: 656222.00 ft Latitude: 70030'33.763N Shape: Circle '\ , Target: S06 Tgt )ell: NS23 Based on: Planned Program Vertical Depth: 10844.00 ft below Mean Sea Level Local +N/-S: 6599.88 ft Local +B/-W: -3463.45 ft Longitude: 148°43'17.949W Radius: 300 ft liDO lOOO I. 5'100 5800 5100 5500 5500 54-00 5300 5200 5100 ~ 0 0 D 0 0 0 0 0 0 0 0 0 D 0 0 0 0 0 0 0 ~ ~ CD I LD Ul J (Y) N 0 U / (Y) (Y) (Y) (Y) (í) (Y) (I) (Y) (Y) N ~ ~ / I I I I I I I I I I ~ ~ / "'-~ NÒTVAUDAFrER 120r5f.YS· ~~\::~\.::?:::::~'~.~::::~;"1j~.~~~::~~~:;~:~.~;S:(~~,.. . '. ~t.ß~ ::.. .................... ",H.' .... i·'\ð~~~~1~:Ù~~~;;:~~:;~~:it~: **:511(r:$1qo,OO******* AMOUNT CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 No. p055029 AI;,.",:,:' ~:: Go,,;;, G:':;:¡;;¡,:.;,,;on 1'\ ';.2:\:';i.~ M n R C) 4· 20'O~ì ~'i~J""'¡ '- ~ J r<:D H NET VENDOR DISCOUNT CHECK NO. 055029 DATE 3/12/2003 III 0 5 50 2 g III I: 0 I. ~ 2 0 j ß g 5 I: O. 2 ? ß 9 b II' ALASKA OIL & GAS CONSERVATION COMMISSION '. 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 DATE Ma~ch tg,'g003 B p.'. r;...,.. l..··.·. ~UI.t. .. ...~.ftl.... ft', "'."" ",..·.ÎI ill, ...., "J! ·]4.." ,.." . .< . - ::)..(,/1,1 11tH':",,,, ....1'1...... NATIONAL CITY SANK Ashland, Ohio PERMIT TO DRILL GROSS TO THE ORDER OF: PAY: BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 TOTAL ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. '-~15 d '3; DESCRIPTION INVOICE / CREDIT MEMO 3/12/2003 INV# CK030603B / DATE p055029 ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/1 0/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a. conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY ~,/JÆ WELL NAME,/l/S 2,~; PROGRAM: Exp _ Dev _ Redrll_ Re-Enter _ Serv 2é:- Wellbore seg_ FIELD & POOL S:7 0,.,4$ c=> ("5 INIT CLASS / - :J /^ 11 ( ~ GEOL AREA <6/,6 UNIT# //'! ~ rJ r:> ON/OFF SHORE cl.f " ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . 'Y N (Service Well Only) 13. Well located wlin area & strata authorized by injection order #.23... A N (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. œ N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ~ N 16. Surface casing protects all known USDWs. . . . . . . . . . N 17. CMT vol adequate to circulate on conductor & surf csg. . . . I 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 19. CMT will cover all known productive horizons. . . . . . . . '.' . N 20. Casing designs adequate for C~ T, B & permafrost. . . . . . . . N . J _ I _ ~_ 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . ,~ N !UC<.l.)orS ~ t::.. 22. If a re-drill, has a 10-403 fo.r abandonment been approved. . .. ~ Ailk 2.3, Adequate wellbore separation proposed.. . . . . . . . . . . . œ N 1., 1 24. If diverter required, does it meet regulations. . . . . . . . .. .~ iN - W q",¿\J èý 1Ï~t?~~ ~d 25. Drilling flUid. program schematic & equip list adequate. . . . . .. . N ñL1.4 µ¿ 1"-' r~. s p pc¡ 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N '-f IS 3' 27. BOPE press rating appropriate; test to 4-800 psig. N M S. P ~-~(èg Js.¿ , 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 29. Work will occur without operation shutdown. . . . . . . . . . . _ I R.. 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y CbV 31. Mechanical condition of wells within AOR verified. . . . . . . . -v-N-/\1/k- Y@ JfAhA, APPR DATE ~/~5 APPR DATE WGfr jÎ2<;;/Ð3 (Service Well Only) GEOLOGY APPR DATE df: 3J~ (EXPIOra~ "'Only) ( 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . .. . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . .. ...... 36. Contact namelphone for weekly progress reports. ...... í ( GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Comments/Instructions: RP~ TM JH JR SP RR WA / MW Ds63(2.S/Ó] Rev: 2/25/03 SFD_ \welLperm it_checklist ) ') Well Historý File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to sim.plify finding information. information 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. I I I I ( ( I I I I I I I I I I I I I t}03-050 sper'r''!I-sun [J RILL I N G 5 E R V I c: E 5 BP EXPLORATION ALASKA END OF WELL REPORT NORTHST AR NS23 OC"'- 2. 1 ., ! I' .... ": f' "'..." . ." ,.,.....".., ;:···(·,r¡··\~\f';,;1it~\~~~.,"i '\ ï,:~,.,,·~i¿ ,~\ { II." .¡:'., "'I~J'·\,¡; "<-'" ,I, \";'. ·....\..i.I... ¡ "... ,..'¡""" < blt\R'ClI;)~'\:¡.'C~ ~#~; '~Io ~,.,.. .....,¡ ... Am~¡on~iY'; I I I I T ABLE OF CONTENTS I I 1. General Information I 2. Daily Summary 3. Daily Operations ( 4. Show Reports I 5. Morning Reports 6. BHA's ( 7. Bit Record I 8. Mud Reports 9. Survey Record I 10. Formation Tops I 11. Formation Evaluation Logs sperr'v-sun J:I RU..'-I N (5 51: R\I U:: 1::5 I I I I ( I I ( I ( I I I GENERAL WELL INFORMATION Company: Rig: Well: Field: Borough: State: Country: API Number: Sperry-Sun Job Number: Job Start Date: Job End Date: North Reference: Declination: Dip Angle: Total Field Strength: Date Of Magnetic Data: Wellhead Coordinates N: Wellhead Coordinates W: Vertical Section Azimuth: SDL Engineers: Company Representatives: Company Geologist: r i I I I I I Lease Name: SSDS Unit Number: State: Borough: BP Exploration Alaska Nabors Alaska Drilling No. 33-E Northstar NS23 Northstar North Slope Alaska United States 50-029-23146-00 AK-AM-0002371818 Apr01,2003 May 09, 2003 True 26.007 deg 80.953 deg 57553.241 nT APRIL 01, 2003 North 70 deg 29 min 28.86 see East 148 deg 41 min 35.94 see 332.320 deg Doug Wilson Mark Lindloff Reg Wilson Tom Mansfield Gavin Kidd Bob Clump Lance Vaughn Joe Polya Mike Dinger Ken Lemley I Rick Matson Northstar 107 Alaska North Slope spe......l..,v- sun r:JRH_L.1 N G seR\JIc:e:5 I I I I I I I i I I I I I I I I I I BPExploration Alaska Daily Summary 04/01/03 Finish moving rig from NS19 to NS23 slot. Preparing to spud. Nipple up riser, Pickup 16" MX-C1 bit #1. 04/02/03 Pickup motor and bit #1, run in hole and tag ice at 50'. Clean out conductor to 122' MD. Pull out of hole and pickup drilling BHA #1 (16" Bit #1 MX-Cl, TFA=1.031). Run in hole. Finish cleaning out conductor and drill 30' of rathole to 231' MD. Run Gyro. Pull out of hole and Pickup BHA #2 with MWD ( rerun bit #1 ) Run in hole and drill to 999' MD with gYrO. Pull out of hole to check Gyro, approaching hardline for existing well collision. Directional attempts unsuccessful. Run in hole to 465' MD and perform open hole sidetrack. Maximum gas for this interval was 25 units from diesel contamination. 04/03/03 Run in hole to 500' after checking directional tools. Sidetracked from 544 to 818' MD, gyroing every connection.. Repaired top drive. Continue drilling / sliding with gYro's every connection to 1854' MD. Top of Permafrost at 1210' MD, 1196' TVD. Base of permafrost at 1575' MD. 1524' TVD. Maximum gas in this interval 27 units at 1652' MD with a mud weight of 9.3 ppg. First indication of methane gas reading in excess of 100 ppm at 1150' MD.. 04/04/03 Drill 16" hole from 1854 ft to 3686' MD, 3206' TVD, section total depth. Circulate sweep to clean hole. Trip out of hole to 400' MD. Trip in hole to make sure sidetrack was good. Pull out of hole and laydown BRA #2. Rigup to run 13 3/8" casing. Top of the SV6 marker at 3506' MD, 3066' TVD. Maximum gas 37 units at 2316' MD. Maximum ROP for interval was 1128 ftIhr at 563' MD. Bit #1 statistics= 3485 feety, 17.6 hrs, and 203K revolutions. 04/05/03 Drill From 1854' To 3686.1' MD. Circulate sweep to clean hole. POOH to 400', RIH to make sure side track was good. Lay down BHA #2. Rig up 13.625 casing tools. SV6 3506' MD, 3066' TVD. TD 16" section 3686.1' MD 3206' TVD. 04/06/03 Continue to Rig up casing tools, Run 13 3/8" casing, last 5 joints tight, land a 3665', rig up cement Head, slowly establish circulation, circulate and condition, Pump cement as per well plan, bumped plug, nipple down riser and begin to nipple upo BOP's. 04/07/03 Continue N/U BOP's. Test BOP's, P/U BRA #3. RIR to Shoe. Currently slipping and cutting drill line. 04/08/03 Displace well with new seawater polymer mud while drilling out 20' of new formation to 3708. Perform FIT to 12.5 ppg EMW. Continue drilling F/3708 T/6472 with average gas of72 units and max gas of 392 units. SV5 3838' MD, 3324' TVD, SV4 4247' MD, 3644' TVD, SV3 4534' MD, 3870' TVD, SV2 4743' MD, 4036' TVD, SV1 5239' MD, 4430' TVD, UGNU 5682' MD, 4784' TVD. 04/09/03 Drill F /6472 T /8629 with an average gas of 150 units and a maximum gas of 1163 from 6673' . Begin pulling to shoe, Top Drive down for repairs. Schrader Bluff 773?' MD, 6383' TVD. Colville 8404' MD, 7094' TVD. 04/10/03 Repair Top Drive. Rigged up G & I with pits and monitor. 04/11/03 Work on Top Drive. I I I I r I I I I I I I [ I I I I I BP Exploration Alaska Daily Summary 04/12/03 Complete Top Drive drive repair, RIH to shoeCirculate out 400 bbls of solids contaminated mud from open hole annulus. Added 900 bbls of new GEM mud while circulating. Torq after dilution 21 K to 22K at 150 RPM on bottom. Drilling to 9420, torq running between 24-26 K. Add 1 % Torq-trim, torq reduced to 23 to 24K. Currently running at 24.5K. Drill to 9733' MD. 04/13/03 Continue drilling F/9733 to 10200'. Lost 50 bbls, increased mud weight to 10.0 ppg. Hole took 30 bbls more fluid at 10350. Continue drilling to 11414' md. Back ground gas running 600-700 units. Repairing top drive at report time. HRZ @ 10767' MD, 8786' TVD. KALUBLIK @ 10849' MD, 8850' TVD. KUP ARUK @ 10899' MD, 8890' TVD. KUP ARUK C @ 11072' MD, 9028' TVD. 04/14/03 Work on Top Drive. TD 12.25" section. Circulate and pump sweep. Top Drive failed. POOH. and spot Steal Seal across Schrader Bluff. Continue to POOH. Lay Down BHA#3. Rig up to run Wire line logs. Miluveach @ 11488' MD, 9362' TVD. TD 12.25" hole @ 11537' MD, 9402' TVD. 04/15/03 Wireline log. Logs stopped at 4062'. POOH and rig down wireline. Decision made not to attempt Pipe Conveyed logs. Made up "kill string" and RIH to 13 3/8" shoe. Make repairs on top drive. 04/16/03 Repair Top Drive. 04/17/03 Continue repairs on Top Drive. POOH w/ "kill string". RIH with BHA #5 with LWD for mad pass and wellbore c1eanout. 04/18/03 RIH, tight @ top ofHRZ. Increased MW to 10.7. Mad passed from TD to 11150'. Backream to 10950' +/-. Spotted 70 bbl pill (Baranex/Barotrol). Backream and pump out of hole. 1269 units maximum gas while reaming. 04/19/03 POOH. Rig up and run 9 5/8" casing. 04/20/03 Finished running and landing 9 5/8" casing to 11,516'. Cemented casing. Set and tested pack off. Performed down squeeze on 9 5/8" X 13 3/8" annulus. 04/21/03 Test BOPE. Make up BHA #6 and run in the hole. Cut and slip drilling line. Wash and ream from 11271' MD to 11329' MD. 04/22/03 Wash and ream from 11329' MD, to 11430' MD. Condition mud to 12.6 ppg. and pressure test casing to 4600 psi. Drill out float equipment, rathole, and 20' of new hole to 11558' MD. Perform FIT ( unable to hold target of 14.5ppg, New ECD hardline 14.0ppg). Drill new formation from 11558' MD to 11843' MD. 04/23/03 Drill ahead from 11843' MD to 12310' MD. Kingak @ 12135' MD, 9889' TVD. 04/24/03 Drill 8 ~"hole from 12310 to 13461' MD, 10982' TVD, that became 8 ~"hole section Total depth.. Lost returns. Pull to 9 5/8" casing shoe and established full circulation up to 7 bbls/ min. Start run in hole to bottom. Top sag River 13438' MD, 10962' TVD. Maximum gas was 250 units at 13222' MD. Bit #3 statistics= 1924 feet, 39.4 hours and 580K revolutions. I I I I I ( \( I I I ( ( BP Exploration Alaska Daily Summary 04/25/03 Ran in hole from 9 5/8" casing shoe. Hole tight. Spot 25 bbl LCM pill. Pull out of hole. Tight after 50' from bottom pump out to 9 5/8" casing shoe at 2.5 to 3.5 bbls/min rate. Circ bottoms up at shoe. No losses observed while tripping or circulating. Trip out of hole. Lay down HWDP and BHA. Rig up to run 7" liner and run same. 04/26/03 Run 7" drilling liner. Pickup 1 stand of drillpipe and circulate string and liner volume. Continue running 7" liner to 11452' MD and circulate string and liner volume. Start in open hole and begin washing liner to bottom at 12090' MD. 04/27/03 Washed 7" drilling liner to 13446' MD at 0430 hours. Circulated 1 string and liner volume (270 bbls). Maximum gas observed was 149 units. Unable to unlatch drillpipe from liner to cement. Cut and slip drilling line. Rig service. Start trip out of hole with liner. 04/28/03 Finish pull out of hole. 7" drilling liner left in hole. Perform BOP test. 04/29/03 Run wire line to determine top of 7" drilling liner, found at 11282' MD. Top offill inside liner at 13168' MD. Finish wireline. Run in hole with cleanout assembly to clean out fill inside 7" liner. 04/30/03 Run in hole with clean out assembly. Tag fill at 13228' MD. Wash to 13349' MD. Pumped high viscosity LCM sweeps while washing fill. Pumped a high viscosity sweep at 13349' MD. Circulated at 15 bbl/min and rotated at 130 rpm while circulating sweeps until hole cleaned up. Attempt to push liner down was unsuccessful. Trip out of hole and pick up a Fas Drill packer. Run in hole with same. Maximum gas during circulating 12 units. 05/01/03 Run in hole to 13348' MD, fill pipe and break circulation. Set Fas Drill plug at 13343' MD. Space out with pup joints, rig up cement head, establish circulation- no returns. Rig down cement head, sting into plug, still unable to circulate. Trip out of hole to 11187' MD. Slip and cut drilling line. Service top drive and drawworks. Pull out of hole to surface. Rig up and run wireline and perforate 7" drilling liner from 13259' to 13264' MD. Rig down wireline. 05/02/03 Rig down wireline. Run in hole with Fas Drill drilling assembly and 4" drill pipe. Change to %' equipment and run in hole to 11185' MD. Break circulation prior to entering 7" liner. Run in hole to 13240' MD.. Rig up Baker cement head. Break circulation- pumping up and bleeding off back pressure. Established returns pumping at 3 spm. Slowly stage up pumps to 25 spm- packed off - no returns. Mud weight fell from 12.6 ppg to 12.3 ppg while staging up. pecided to circulate and condition mud to 12.6 ppg before attempting to reestablish circulation through perforations. Maximum gas of 325 units seen at 13199' MD while pumping at 25 spm (bottoms up). 05/03/03 Circulated and conditioned mud to 12.6 ppg in and out. Made up cement head, stung into Fas drill packer and attemted to circulate. Leak off pressure at 1350 psi and step rate injection pressure to 4 % bbl/min. Plan for cement squeeze job. Pump cement. Maximum gas during squeeze job 44 units. Continued to circulate 100 units bottoms up after squeeze job. No cement returns were seen at surface. Pull out of hole 4 stands. Inspect traveling block-bad sheave found. Repair traveling block sheave. Unstring drilling line to thread same off of bad sheave onto unused sheave ( 10 lines used in 12 line block ). 05/04/03 Restring drilling line through traveling blocks and crown sheaves. Pull out of hole and pick up BRA #10 (Bit # 5 6" Baker Mill). Run in hole to mill out Fas Drill packer I I I I I I : I I I I I ! I BP Exploration Alaska Daily Summary 05/05/03 Continue to run in hole with BHA # 10 to top of 7" liner. Circulate mud until weight in and out was 12.6 ppg. 213 units of gas was observed at bottoms up. Continue run in hole to 13085' MD. Washed down to 13207' MD. Mill on Fas Drill, float collar and landing collar from 13209' to tag shoe at 13434' MD. Circulated high viscosity sweep at 14 bbl/min. From 13209' to 13434' and concurrent circulation out 0.35 lbs of scale and metal shavings were noted at possum belly magnets. 121 units of gas was observed at bottoms up. Monitored well, pumped dry job and tripped out of the hole. Lay down BHA #10. Junk basket contained metal from Fas Drill plug, landing collar and float collar. Rig up wireline to run USIT / cement bond log. 05/06/03 Continue to rig up wireline. Run USIT / CBL over 7" liner. Run Fas-Drill bridge plug on wireline, Test choke while wirelining. Rig down wireline. Flush BOP stack with Johnny Wacker. Test BOP's. 05/07/03 Continue testing BOP's. Pick up BHA #11. Run in hole and set packer and polish top of7" liner. Test packer-OK. Pull out of hole. Cut & slip drilling line. Pickup BHA #12 (6" Bit EP4970 TFA= 0.516), mud motor and MWD. Trip in hole with BHA #12. 05/08/03 Continue to run in hole with to 13195' MD. Lost Hi-line power and switched to rig power. Wash down to Fas-Drill plug at 13225' MD and drill out same. Displace well with 9.2 ppg mud Dril-In fluid. Washed down and tagged 7""liner shoe at 13434"MD. Drill shoe and clean out rathole and 20"ofnew formation to 13481' MD. Perform Formation Integrity Test to 11.3 ppg EMW. Drill 6" hole from 13481' to 13654' MD. Top of Shublik formation at 13552' MD, 11060' TVD. Top of Ivishak formation at 13657' MD, 11150' TVD. Maximum gas seen in this drilling interval was 596 units at 13481' MD. 05/09/03 Drill 6" hole from 13654' md to Total depth of 13981' MD, 11434' TVD. Circulate and condition hole. Perform MAD pass to 7" liner shoe. Maximum gas at bottoms up was 178 units. Maximum gas while drilling 6" hole in this interval was 288 units at 13762' MD. Pulled 20 stands to 11550' MD. Opened PBL sub to circulate at a higher rate and circulated 12500 strokes. Hole cleaned up with 130 units of maximum gas on bottoms up. Trip out of hole. Lay down BHA # 12 .BHA #12 statistics = 520 feet, 19.1 hours and 201k revolutions. Continue MU BHA#l Hold Pre-Spud Meeting Notes: Continue move to NS23. ****ACCEPT RIG @ 00:00 hrs on 4-1-03*** Note: (Rig move accept time compensated for move back and NS22 wellhouse removal). Level up rig. Rig Up.- Close in cellar. - Berm rig. - Position walkways and stairs. - Leveling walking areas in sub structure around wells. NU surface riser. Identified down scoping riser is too short to reach adapter receptor. - Pull riser and place in pipeshed. Decision made on new plan forward for NU surface riser. - PJSM -- Non Routine Operation/HACL - Spot in cellar and NU lower risers. -Measure and cut off 7" of surface riser. - NU surface riser. Fill & test riser with sea water. PJSM. - Install mousehole and iron roughneck track. Move wireline sheaves to floor. PJSM for rigging up for GYRO. - Rig up SWS wireline and GYRODATA tools. RIH wi 1 std of 5" DP and tag ice at 52' in surface conductor. P JSM. -PU Motor and 16" bit for clean out of conductor from 52' to 121' md Allowing room to PU HWDP and stand back in derrick). POOH. PJSM. - MU 24 jts HWDP & stand back in derrick. PJSM for MU ofBHA #1. BHA # 1 consists of the following: - 16" Hughes MX-C1 (3x20 & 1x12 Jets), - 9-5/8" PDM-1.83 deg, - Orienting Sub, NM Stab, 2x Monel LC, NM Stab Operations Breakdown BP Exploration - Northstar NS23 Daily Operations (I.A.D.C) I I I I I 'I I 04/02/03 I 00:00-01 :00 1.00 01. 00-02.00 1. 00 I 14:45-15:00 0.25 15:00-15:30 0.50 15:30-16:00 0.50 16:00-18: 15 2.25 18:15-18:45 0.50 18:45-20:30 1.75 ( 20:30-21 :00 0.50 21 :00-22:45 1.75 22:45-00:00 1.25 07:30-14:45 7.25 05:30-06:30 1.00 06:30-07:30 1.00 02:00-03:00 1.00 03:00-05:30 2.50 Time Elapsed (hrs) Time 04/01/03 00:00-02:00 2.00 16:45-19:00 2.25 1. Notify Control Roon1 to shut in NS-2'+ @ SSSV for downhole close approach. 2. Conduct 07 Drill -- Shallow Gas without Diverter Drill Clean out conductor. Note: Conductor oriented in favorable direction 0.71 inclination & 305 azimuth @; 206' md. Drlg f/ 230' - 329' md. Gyro @. 327' md. LD BHA#l. MU BHA#2 and RIH to 280' md. Wash fj 280' - 329' md -- circulate red n1ud sweep. Drill Ahead 16" surface hole from 329' - 999' md. - Gyro survey on each connection Surveys: MD (') Sur Depth (') Inclination (deg) Azi (deg) 456356 1.11 271.97 547 447 1.99283.74 637 537 4.26 280.09 728 627 5.93 280.55 819717 6.08 283.62 908 808 6.81 285.38 999 899 9.70 284.27 Each slide indicating build in inclination- no directional response. Run new GYRO tool for confirmation. At 999' md (903.8' survey depth): 9.47 incl & 282.14 Azimuth. Note: DD cannot go further without breaking hardlines at 1100-1400' and 1700- 2100' rod. POOH to check for tool problem or reason for lost orientation. - At surface find orientation 50 deg off. Rill wi BHA#2 and check torque on connections. - Found Handling Sub on the bottom ofMWD without proper torque. - Shipping instructions indicated that this connection was not torque. - Standard practice is that Anadrill paint stencils labels "loose" on all connections that require rig to torque up. Note: Confer with Anchorage Engineering on plan forward and decision made to open hole side track at 500' md. Torqued connection to 48K ft-Ibs. Rlli to 460' md. Run Gyro Survey. - At 357.8' survey md, 0.93 degs inclination & 284.73 Azi wi 167 deg TF. SURF DRILL REAM N HMAN Orient tool face to low side and trench from 460' to 500' md wi 140 TF. Time drill from 500' to 503' md. 02:00-02:15 0.25 02:15-04:00 1.75 04:00-04:30 0.50 04:30-07:00 2.50 07:00-07:15 0.25 07: 15-16:45 9.50 19:00-20:30 1.50 20:30-21 :30 1.00 21 :30-22:00 0.50 22:00-22:45 0.75 22 :45-23 :30 0.75 23:30-00:00 0.50 ' 04/03/03 00:00-03:00 3.00 03 :00-08 :00 5.00 08 :00-1 0:30 2.50 10:30-11 :30 1.00 11 : 3 0-12 : 3 0 1.00 Time drill from 503' - 520' md. Drlg fl 520' - 818' md -- Gyro each connection. Trouble Shoot Top Drive -- Unable to operate breakout wrench. Note: Bad output relay module -- critical spare was defective. Blow down top drive, Run Gyro, make connection and attempt to slide -- unable to set top drive brake. Troubleshoot and repair TD brake. PJSM -- RU Surface Casing Equipment & Franks Tool. Rill with 88 jts of 13-3/8" 68# L80 Btrc Casing. Circulate and Condition for Cement Job: SURF CASE CIR P Note: Held Pre-Tour, Crew Change, PJSM for Cement Job and HES Preparation for job. Pump 5 bbls SW and test lines to 3000 psi. Pump 75 bbls of Alpha Spacer @ 10.4 ppg. Drop Bottom Plug. Mix and Pump 450 bbls of 10.7 ppg Lead Cement. Mix and Pump 100 bbls of 15.9 ppg Tail Cement. Drop Top Plug and Displace cement with 538 bbls. Notes:- Final 30 bbls pumped were SW to aid RD csg running equip. - Circulated -150 bbls of cement to surface. - Bumped plug with 2450 psi (500 psi above FCP) - Rig pumps @ 94.3 % efficiency. - RES meter @ 90.1 % efficiency. Rig down celnent head, spiders, & LD jt. Blow down all lines. Clear floor off casing running tools and clean drip pan. PJSM. Rig down turnbuckles, riser, and mousehole. LD casing bails. PU drilling bails. Install master bushings. 20:00-20:30 0.50 16:30-17:30 1.00 17 :30-19:00 1.50 19:00-20:00 1.00 04/05/03 00:00-01:30 1.5 01:30-11:00 9.50 11:00-13:00 2.00 11 : 00-13: 00 2.00 13 :00-13:30 0.50 13 :30-15:00 1.50 15 :00-15:30 0.50 15 :30-16:30 1.00 Drlg f/ 1856' to 2045' md. Circ Red Mud Sweep. GYro Survey on Wireline. Drlg f/ 2045' to 3686' md. Circ and Cond Mud for running casing -- monitor well. TOR 5 Stands. Note: Pump dry job and blow down lines. TOR to 400' md (above OR sidetrack pt). Orient TF to 140 and TIH to 1100' md. - Smooth hole no drag. - No trouble with BHA going into sidetrack. TOR to DC's. Rack back DC's. LD BRA#2. - Stab's have normal clay buildup. - Bit in good shape (Graded: 1-1- WT -A-E-I-PN- TD) PU Landing Jt and hanger. -Drift riser due earlier modification. 22:30-00:00 1.50 19:00-20:00 1.00 20:00-22:30 2.50 16: 15-18:00 1.75 18:00-19:00 1.00 04/04/03 00:00-01 :00 1.00 01 :00-01 :30 0.50 01 :30-02: 15 0.75 02: 15-14:00 11.75 14:00-15:45 1.75 15:45-16:15 0.50 Slide fron1 818' to 999' n1d. Drill ahead 16" surface hole fl 999' to 1856' md. - Avg ROP rotating is 518 fph - A vg ROP sliding is 126 fph. - Gyro survey every other stand. Drilling parameters: - WOB from 8 K to 25 K lbs - Total Flow 800 to 900 gpm wi 2200 psig SPPon. - Rotating 40 rpm wi 7000 ft-Ibs torque. 0.50 11.00 12:30-13 :00 13 :00-00:00 I I' I I I I I I -I - Operations 51 \Vells NS22 and NS 24 for heavy lift. 20:30-22:30 2.00 P JSlVl for ~D lower riser sections. - ND lo\ver riser sections and relocate them in cellar at well slot NS25. 22:30-00:00 1.50 P JSM for 0JU .-\BB Vetco Grey Multibo\vl \VH. - NU WH and test to 5000 psig. - NU Drilling sweep on annulus. 04/06/03 00:00-00:30 0.5 Set test plug in tubing spool. Note: Obtain pennits for heavy lift. 00: 3 0-02: 00 1.50 NU BOPE. Note: Set clock forward one hour for DLS Time -- Lost one hour -- 1.5 hour task and 23 hour day for 4/6/03. 03:00-05:30 2.50 Finish NU BOPE. 05:30-06:00 0.50 RU testing equipment and fill stack. 06:00-10:00 4.00 Test BOPE -- 250/4800 psi 5 minutes per test. Note: AOGCC Field Inspector Chuck Sheve waived witness for test @ 2000 hrs on 4/4/03. 10:00-11 :00 1..00 RD Test Equipment and Blow Down Lines. 11 : 00-11 : 3 0 0.50 Pull Test Plug and Install Wear Ring. Note: Adjust mop and clean rig floor. 11 :30-12:00 0.50 Hold Pre-Tour Meeting with Day Tour crew while Morning Tour Crew eats lunch in preparation for back logic class. 12:00-14:00 2.00 SAFETY C Held Back Logic Training with both crews. 14:00-17:00 3.00 MU BHA#3 & Surface test Rotary Steerable and MWD tools. 17:00-18:00 1.00 Failed DWOB on MWD tool. LD and PU spare tool from pipe shed and surface test -- program error. 18:00-18:30 0.50 Break Connection on floor and reprogram MWD tool while BRA is in rotary. Test after reprogramming is good. I 18:30-20:00 1.50 Continue MU BHA#3 to Jars. Rffi wi HWDP. MU 12-1/4" Weatherford Ghost Reamer 998' md behind bit. MU dart valve sub. I 20:00-21 :30 1.50. Rffi wi BHA#3 on 5" DP to 3579' md. Wash down last stand. 21 :30-22:30 1.00 SI pipe rams and pressure test casing to 3500 psig for 30 mins. I - 6.95 bbls to pressure up.- Bleed off and blow down Top Drive. 22:30-00:00 1.50 PJSM. Slip and cut drilling line. I 04/07/03 00:00-00:30 0.50 Finish Slip and Cut drilling line. 00:30-02:00 1.50 Service top drive and drawworks. I 02:00-02: 15 0.25 Pump 100 bbls hi-vis pill followed by new 8.7 ppg drilling fluid. 02:15-04:30 2.25 Drill Float track and rathole while displacing well to new 8.7 ppg drilling fl ui d. I 04:30-04:45 0.25 Drill 20' of ne\V fro to 3708' rod. 04:45-05 :00 0.25 Perfonn FIT to 12.5 ppg EMW (633 psi with 8.7 ppg fluid). Bleed down kill line. I 05:00-12:00 7.00 Drilling fï 3708' - 4777' rod with RSS tool. RSS tool responding well to downlinks. 12 :00-00:00 12.00 Drilling fl 4777' - 6474' rod with RSS tool. I RSS tool responding well to downlinks. 04/08/03 00:00-12:00 12:00-19:30 19:30-20:00 20:00-22:00 22:00-22:45 22:45-00:00 1.25 Drilling ahead 12-1/4" Intermediate hole f/ 6474' - 7601' md. Drill 12- L4" f/ 760 I' - 8349' md. Atten1pt to shim Top Drive IBOP Actuator Roller Assembly. Drill ahead 12-1/4" from 8349' - 8629' md. Troubleshoot Top Drive. Notes:- Clicking sound coming from upper bearing area and not the gear box. * Clicking sound rate increased proportionally to rpm speed. - NAD Slope Mechanic due to rig this am to troubleshoot. Suspect upper bearing. Pump sweep in preparation to POOH to Shoe to further evaluate top drive problem. Note: Added Algecide to mud system. 12.00 7.50 0.50 2.00 0.75 04/09/03 00:00-01 :00 1.00 01 :00-01 :30 0.50 l 01 :30-02: 15 0.75 " I 02:15-03:30 1.25 r' 03:30-06:15 2.75 I 06: 15-06:30 0.25 06:30-10:45 4.25 I 10:45-12:00 1.25 12:00-16:00 4.00 19:00-23:00 4.00 Continue circulating and conditioning mud for trip to shoe. - Add Algicide Treatment. Monitor well and pull 3 stds to 8163' md. - PU WT= 280 K lbs & SOW= 185 K lbs. - Pump dry job blow down lines. - Blow down lines. POOH from 8163' to 8069' md. - Hole tight and swabbing. Back ream from 8069' to 7600' md. - Back ream wI 15 rpm and wI 45 spm. - Quit back ream at 7600' md- Depth where GHOST REAMER had reamed to. Monitor well. POOH from 7600' to 3648' md (into 13-3/8" shoe). Monitor well at shoe. Troubleshoot Top Drive. - Mike Carr wI Nabors out to troubleshoot Top Drive. - Top Drive has broken Pinion Gear. Move 72 stands ofDP from the off drillers side to drillers side of pipe rack. PJSM. Clear out space for parts storage on rig floor. - Remove saver sub & pipe handler. - Remove lower and upper safety valves. - Remove link assembly and torque arrester. PJSM. - Remove blower hoses and extend counter balances. - Separate the top drive from swivel and pull quill shaft out of top drive. - Hook up slings to remove motor. Swing open top drive exposing motor for removal. Hold initial A TP meeting with On Site Safety, Mike Carr- NAD wlaster J\'lechanic, Steve Edwards- Quadco, Night and Day TP's, Night and Day Wellsite leaders, AlC crane operator, and MTT. PJSM. - Disconnect the hydraulic service loop. - Remove blower motor and duct. 16:00-19:00 3.00 16:00-19:00 3.00 - Remove compensator valve assembly. - Remove wiring for traction and blower motors. - Rig up slings to remove top drive motor. 23 :00-00:00 1.00 PJSIvL - Work on removing mounting bolts for traction motor. 04/10/03 00:00-07:00 7.00 PJSNL Remove TD traction motor from cradle and set down on rig floor. 07:00-08:30 1.50 Remove brake assembly and electrical equipment from motor. 08:30-09:30 1.00 P JSM. Move and set motor on VLE cart. 09:30-10:30 1.00 Steam clean TD. Spot new motor on ground by VLE. Gather up AlC crane crew. 10:30-12:00 1.50 PJSM. Conduct Mini ATP Meeting with all parties involved with crane picks. Set old motor down on ground. PU new motor to floor. 12:00-17:00 5.00 PJSM. Position TD motor near rotary table. .. Install heaters & attach lugs to power cables. \ Tuboscope MPI Quill Pin & Splines.. ok. Install Blower motor to blower assembly. Circulate hole 6000 strokes..-mud in good condition..- circulated out dry I J jobs. Turn on centrifuge. 17 :00-19:30 2.50 Continue work on TD. PJSM for picking up TD motor and placing into bolt up position. [ I PU motor into position. 19:30-20:30 1.00 PJSM wi scaffolding crew. I Rig up scaffolding around and underneath top drive. 20:30-00:00 3.50 Remove primer form motor mounts. Work TD motor into place. I Install pins and bolt up motor. 04/11/03 ( 00:00-01 :30 1.50 Align motor & bolt motor in place. 01 :30-03 :30 2.00 Bolt up all equipment around the motor. 03:30-06:45 3.25 Hook up all hydraulic lines. Tie wire all bolts. Remove and log in all tools. 06:45-07: 15 0.50 RID scaffolding and clean up the work area. 07:15-08:00 0.75 Close and bolt TD carrier. RID slings used to PIU motor. 08:00-09:30 1.50 Stab quill shaft into bull gear. 09:30-12:00 2.50 Wire blower motor and heaters. Work on oil pump. Steam clean pipe handler pieces. Note: Hole took 11.5 bbls in 12 hours. 12:00-17:30 5.50 Continue wiring Top Drive. Ready parts for installation. Connect TD to swivel and install link assembly. Change oil in swivel. Check mop timing. Circulate Bottoms up and test mud lines. Take drilling parameters just below 13-3/8" shoe. - 150 rpm wi 5000 ft-Ibs torque. - UP Wt= 165 K, SOW= 150 K, RT= 160 K -lbs. - Old mud system 9.3 ppg wi 65 visco - Blow down all lines. Rill to 8541' md- slm. - No tight spots I no fill. Wash last stand to bottom- precautionary. Take parameters. - 150 rpm wi 17500 ft-Ibs torque. - Up wt= 260 K, SOW= 205 K, RT= 230 K-Ibs. Mud swap to GEM system. - Using vac truck support. Drill ahead from 8629' to 8679' md. - Torque on 21.5 Kft-lbs wi 150 rpm - Flow 952 gpm wi 2500 psig PP on & 2412 psig PP off. - 9.5 ECD - WOB 15 K, PUW = 275 K, SOW= 208 K, and RWT= 230 K Ibs. - ROP= 110 fph. Drill ahead 12-1/4" Int hole fJ 8679' to 8964' md. -Torq on 19-24 K ft-Ibs & Torq off 17-20 K ft-Ibs wi 150 rpm - Flow 952 gpm wi 2550 psig on and 2500 psig off. - 9.65 ECD - WOB 15 K, PUW= 288 K, SOW= 208 K, and RWT= 240 K lbs. - ROP 30-220 fph. Drill ahead 12-1/4" hole fJ 8964' to 9342' md. - Torq on 23-24 K ft-Ibs & Torq off 19-21 K ft-Ibs wi 150 rpm - Flow 954 gpm wi 2850 psig on. - 9.70 ECD - WOB 15 K, PUW= 340 K, SOW= 190 K, and R WT =245 K lbs. - ROP 130-150 [ph. 15:30-19:45 4.25 I I I I I 03:30-07:00 3.50 l 07:00-07:30 0.50 I ¡ 07:30-12: 15 4.75 07:30-12:15 4.75 I 12: 15-12:45 0.50 I I 12:45-15:30 2.75 01 :30-02:30 1.00 02:30-03:30 1.00 04/12/03 00:00-01 :30 1.50 Install blo\ver hose. Add oil to TO. Install Torque Tube Assembly and compenstor linkage. Wire Tie all bolts. P JStvI. Install TO oiler 1110tOL Install Pipe Handler. MU Kelly hose and saver sub. Function TD. PJSM. Inspect top drive looking for leaks and tools, etc. Check TD torque function - vs - SCR room torque reading good. Install bails and pipe elevators. Change oil in swivel. 22:00-23:00 1.00 23 :00-00:00 1.00 21 :30-22:00 0.50 17:30-21 :30 4.00 19:45-00:00 4.25 Drill ahead 12-1/4" hole fl 9342' to 9752' md. - Torque on 24-26 K ft-Ib - PU\V's Increasing 10K lbs per stand. *** ADD torque trim at 1 % at 9400'.*** - Torque reduced to 24-25 K ft-Ibs and holding steady. 04/13/03 00:00-10:30 10.50 10:30-12:00 1.50 Drill ahead 12-1/4" wi RSS from 9752' to 10538' md. - Increasing MW from 9.2 ppg to 10 ppb while drilling ahead. - MW increase was accomplished wi 600 bbls of BARAN EX spike fluid that was bleed into system. Developed losses at 30 to 40 bph. - Mix and pump LCM sweep and circulate. - Stopped losses. Drill ahead 12-1/4" wi RSS from 10538' to 11414' md. - 4000+ units gas when cap rock Kuparuk tiC" drilled (Top ofKuparuk "C" @ 11072' md- 9028' tvd rkb. MW was gas cut to 8.8 ppg at worst levels. Background gas came down to 600-700 units while drilling ahead. - At 22:25 hrs: Cutting samples show fluorescence from Kuparuk "C". Samples continued fluorescence from 11100'- 11160' md. Mud pump #1 end cap developed leak. Derrickhand and motonnan working on #1 pump. 2) Top Drive oil motor quit. Mechanic and Electrician troubleshooting. 12:00-23:30 11.50 I \ 12:00-23:30 11.50 23:30-00:00 0.50 I I 04/14/03 00:00-01 :30 1.50 Oil pump on Top Drive doesn't appear to be working. - Continue circulating while Mechanic and Electrician troubleshoot- can't repair - no back up available. - Decision made to drill ahead. Drill ahead 12-1/4" intermediate hole f/ 11414 to 11537' md. - Top Miluveach picked at 11488' md. - TD depth of 11537' md includes 20' rathole for running 9-5/8" casing. Pump 50 bbls of hi-vis weighted (12.2 ppg) sweep. - Pump surface to surface with minor excess cuttings returned to surface. - Condition MW from 10.0 ppg to 10.2 ppg. Monitor well and pump dry job. POR wi BHA #3 for OH logs. Pulling 20 - 40 klbs from 11,150' to 10,980 ft. Could not progress past ledge at 10,915'- overpull gradually upto 100 klbs- no go. Pump past and wipe out several times. Perform D-l Drill. PJSM for rig up to spot steel seal at 8300' md. Spot 135 bbls of steel seal LCM pill across Schrader Bluff interval. - Pump dry job and blow down lines. Continue POR to 13-3/8" casing shoe. PJSM for removing inspection plate to inspect pinion gear on TD. - Drain Top Drive gear oil. Pull inspection plate and find that pinion gear is off the shaft. Continue POR to HWDP. - LID dart sub and Weatherford Ghost Reamer. Reamer is 3/8" I 01 :30-05 :30 4.00 I 05:30-11:00 5.5Q ( 11:00-11:30 0.50 I 11 :30-15:00 3.50 I 15 :00-15 :30 0.50 15 : 3 0-16: 15 0.75 I 16: 15-17:30 1.25 17:30-19:30 2.00 I 17:30-19:30 2.00 19:30-20:30 1.00 I underguage on tlat portion of blades & 1'4" under on the beveled section of the blades. - Nlonitor \vell and Fill Trip Tank. 20:30-20:45 0.25 Stand back H\VDP. 20:45-21: 15 0.50 Plant turned off I-solar. Lost power- regain power. 21: 15-23 :30 2.25 Lay down BHA#3. Bit in excellent condition and graded: 1-1-\VT-T-X-I-NO-TD. 23:30-00:00 0.50 Clear and clean rig floor. 04/15/03 00:00-01 :00 1.00 Clear rig floor of 12.25" BHA. 01 :00-02:00 1.00 P JSM -- Rig up wireline 02:00-05:30 3.50 Wireline logs stopped at 4062' MD. POR. 05:30-07:00 1.50 Change hole finder on wireline. RIH. Tagged up at 4062' MD. POH. 07:00-08:00 1.00 Rig down wireline. Decision made not to attempt Pipe Conveyed MD because of the hard ledge at 4,062 ft. Decision made to conduct top drive repair, make L WD I Iwiper trip and make one more attempt at MDT wire line before running 9.5/8" . 08:00-09:30 1.50 Clear floor of casing tools in preparation for top drive. repair. -I 09:30-10:00 0.50 PJSM -- Testing BOP's 10:00-11 :00 1.00 Pull wear bushing and set test plug. 11 : 00-15: 00 4.00 Test BOP's to 250 psi low and 4800 psi high. I 15:00-16:00 1.00 Blow down lines. Rig down testing equipment. Install wear bushing. 16:00-18:00 2.00 PJSM -- Pick up and make up BHA #4 (kill string). Rill to 13 3/8" shoe in case of well control while repairing the top drive. I 18:00-22:00 4.00 P JSM -- Start dismantling top drive. Remove pipe handler, elevator, bails, torque stabilizer, link tilt assembly, compensators, kelly hose, "s" pipe, safety valves. Pull quill shaft through I top drive. Rig up the pick up slings. 22:00-00:00 2.00 PJSM -- Erect scaffolding around rotary for accessing top drive. Remove blower ductwork and blower assembly. remove motor access covers for I rigging up pick up slings. Sling motor and connect to pick up lines. Pull 2k, ready to remove the four motor mounting bolts. I 04/16/03 00:00-07:30 7.50 Rig down oil pump. Disconnect electrical wires. Remove mounting bolts. f Lift motor. Rig down scaffolding. Set motor on floor. Finish rigging down electrical supports from the motor. Place motor on VLE cart. Pull pinion gear from gear box. I Entire shaft broken apart. No damage to the teeth. 07:30-08:00 0.50 PJSM -- taking top drive motor off with rig and crane crews. 08:00-10:00 2.00 Send old motor off the floor using VLE and AlC crane. Bring new motor I to the floor. 10:00-14:30 4.50 Dress new motor with brushes and blower support brackets. Install motor heaters, mounting plate, and top drive brake. 14:30-15:30 1.00 P JSM -- Position motor at rotary table. Rig up slings to motor for raising to final installation. Heat shrink motor electrical wires. 15 :30-16:00 0.50 PJSM -- Rig up scaffolding. I 16:00-17:00 1.00 Line up and bolt in motor. 17:00-18:30 1.50 18:30-22:00 3.50 lVlake electrical connections on motor. Install winding access covers. PJSM -- Install blower duct and blower assembly. Swing in top drive and button up top drive. Rig down scaffolding. P JSM -- Lower quill through top drive. Hook up compensators and connect top drive to swivel. Install temperature probe and remove pinion gear inspection plate. 22:00-23:30 1.50 23 :30-00:00 0.50 04/17/03 00:00-09:30 9.50 Continue top drive repair. Finish putting on oil inspection plate. Install link adapter, link tilt, upper and lower mop valves, saver sub, safety valve, actuator, and pipe handler. Add 9 gallons of oil to gear box. Install S pipe and kelly hose. Hook up air and hydraulics. Adjust counter balance. Finish rewiring oil pump. Test rotation of blower motor. Check top drive rotation. Make up to drill pipe, check make up and break out. Condition mud and circulate. Cut and slip 102' of drilling line. Run replacement wiring for top drive oiler motor. POOH and lay down BRA #4. Make up BHA #5 for wellbore cleanout prior to running logs. RIB with HWDP. PJSM -- Hang blocks to inspect the block shieve. Suspect of being loose, all ok. Continue to Rlli to the shoe at 3660' MD. Fill pipe and get drilling parameters. NOTE: 60 rpm; 9150 ftlb torque; 890 gpm; 1930 psi 164k PU; 141k SO; 148k ROT 22:00-23:00 1.00 Continue to Rill to 3972' MD. Make up top drive to ream. NOTE: Ream from 3972' MD to 4090' MD 80 rpm; 950 gpm; 2400 psi Blow down top drive and lines. Continue to RllI. 09:30-10:30 1.00 10:30-12:00 1.50 12:00-13:00 1.00 13:00-15:30 2.50 15:30-20:00 4.50 '\ 20:00-20:30 0.50 I 20:30-21 :30 1.00 21 :30-22:00 0.50 I I I 23 :00-00:00 1.00 I 04/18/03 00:00-03 :30 3.50 I I I I 03 :30-04:30 1.00 I Trip in hole to 10,778' MD. Bridged off. NOTES: 1. Tagged up at 10,692' MD. Began to pump and ream at 80 rpm, 15k torque, 860 gpm, and 3400 psi. 2. Pump and ream continually. 3. Work tight hole- temporally stuck several times. 4. Bottoms up returned at 10,810' MD. Thick mud blinded shakers. 1000 units of gas (high reading of 1250 units). 5. HRZ picked rrom 10,767' MD to 10,849' MD Ream to 10,880' MD. Hole packing off and sticky. NOTES: 1. Decision to pull up above the HRZ and weight up the mud system to hold back the shales. 06:30-09:30 3.00 09:30-19:45 10.25 2. Kuparuk picked from 10,899' MD to 11,488' NID Back ream out of HRZ NOTES: 1. Hole continually packing off and sticky. 2. Hit a No-go at 10,822' MD. Worked repeatedly. Broke free after 1.5 hours. 3. Rotated one stand out and pumped out the next two (three total, stands 105, 104, and 103). 4. Mixing Barite for mud weight up (targeting 10.7 ppg). Condition mud and circulate. Weight up from 10.2 ppg to 10.7 ppg. Wash and ream from 10,770' MD to 11,537' MD. HRZ was OK. Rotary stalling repeatedly from 10,949' to 11,000'- no packing off. NOTES: 1. MAD pass from 11,150' MD to 11,537' MD while washing and reamIng. 2. At 11,474' MD: 88 rpm, 20k torque, 830 gpm, 3300 psi, 330 PU, 215 SO, and 270 ROT. 3. At TD (11,537' MD): 100 rpm, 21k torque, 850 gpm, 3400 psi, 340 PU, 210 SO, and 265 ROT. POOH from 11,537' MD to 10,594' MD NOTES: 1. Parameters: 90rpm, 21k torque, 815 gpm, 330.0 psi 2. First stand out (57'): pumped and rotated. 3. Second stand out: pumped and rotated; top drive stalling. Halfway up the stand decided to stop rotating and pump out. This worked much better, breaking over at 4o.Ok. 4. Top of Kuparuk pulling tight- breaking over easy going down and cleaning up with wipe. 5. Could not dry pull through the HRZ- with pumps on the overpull was 20-30 Klbs- did not need to backream. 04:30-06:30 2.00 I 19:45-00:00 4.25 , \ ! I ( I 04/19/03 I 00.:00-03 :0.0 3.0.0. 11 I 03:00-04:00 1.00 I 04:00-06:00 2.00 06:00-08:00 2.00 I 08:00-10:00 2.00 10:00-11 :00 1.00 11 :00-12:30 1.50 I 12:30-13:45 1.25 I 13 :45-15: 15 1.50 I Continue to POOH to 8300' MD. NOTE: 1. Pulling wet with pumps off and no rotation. 2. Had to pull slow to about 10,000' MD, then the formation relaxed and allowed for nonnal tripping speed. Spot steel seal pill. Pump 12.7 ppg dry job. Continue to TOOH to the 13 3/8" shoe at 3666' MD. Monitor well. POOH to BHA. Lay down BRA. Clear rig floor to remove Anadril source. Continue to lay down BHA. Pull wear bushing and set test plug. Change out upper BOP rams to 9 5/8". Rig up to test door seals. Test door seals to 3500 psi for 15 minutes. Rig down from pressure test. P JSM -- Remove bails. PJSM -- Make up Franks Tool PJSM -- Install long bails PJSM -- Rig up casing tools 15:15-15:30 0.25 PJSìVl on running 9 5/8" 53.5 ppf casing. 15 :30-19:30 4.00 Run 9 5/8" 53.5 ppf casing with centralizers to 2730' MD. 19:30-20:45 1.25 PJSJ\;1 -- Lay down Franks tool and change out rubber cup. Circulate a string volume (2000 strokes) at 460 psi. 20:45-21: 15 0.50 Continue to RIH with casing to 3650' J\;ID (13 3/8" shoe). NOTE: PU at shoe = 240k 21:15-22:15 1.00 Circulate string volume (2500 strokes) at 460 psi. 22: 15-00:00 1.75 Continue to RIH with casing to 4867' l'vlD. NOTE: PU at 4615' MD = 275k Hole still taking some fluid as Rill. 04/20/03 00:00-11 :30 11.50 Rill with 9 5/8" casing from 4867' MD to 11516' MD. NOTE: 1. Lay down joint #118 for damaged box threads (replaced with joint #285 between joint #173 and #174). 2. Losses were consistent at approximately 1 bph. However, the hole took about 6 bbls at Schrader Bluff. \ 3. Casing went down without incident until joint 276. The string would packoff, circulation would be established, the pipe would fall, then packoff again. This cycle repeated throughout the joint for nearly 2 hours. I J 4. Once this joint was run in, the landing joint was made up. This joint went down relatively incident free. 5. Floating centralizers were run one per j oint from joint # 1 to # 174. I 6. The fmal weight of the string in the slips was 345k (including 70k for the top drive). 11 :30-12:30 1.00 Condition and circulate mud. I 12:30-13:00 0.50 Land 9 5/8" casing. 13:00-13: 15 0.25 Rig down franks tool. 13:15-13:30 0.25 Rig up cement head. I 13:30-14:00 0.50 Circulate at 10 bpm with 890 psi in preparation for cement job. 14:00-16:30 2.50 Pressure test cement lines to 3000 psi for 15 minutes. Pump cement. NOTE: II" I 1. Pump 50 bbls of 11.2 ppg Alpha spacer. 2. Pump 363 bbls of 11.2 ppg Lead slurry. I 3. Pump 143 bbls of 15.9 ppg Tail slurry. 4. Cement pumped at 5 bpm, limited by G&I pump for water supply. Will look into condition of pump as this limitation is irregular. I 16:30-18:00 1.50 Displace with rig pump at 10 bpm. NOTE: 1. Plug bumped with 95.60/0 efficiency (7818 strokes). I 2. No losses. 3. Approximately 25 bbls of Alpha spacer returned to surface, no cement returns. I 18:00-18:30 0.50 Rig dovin cement head and landing joint. 18 :30-19:30 1.00 Install packoff and test to 6500 psi for 15 minutes 19:30-20: 15 0.75 Change out drilling sweep on wellhead. Clear rig floor. I 20: 15-20:45 0.50 Rig up to 13 3/8" x 9 5/8" annulus. Change out to short bails. Wash and ream from 11329' MD to 11430' MD, cleaning hole. Condition mud and circulate until MWin = MWout at 10.6 ppg. Pressure test casing to 4600 psi for 30 minutes with 10.6 ppglmud. Blow down mud lines. NOTE: 141 strokes to 4600 psi consistent delta P every 5 strokes. Drill float equipment. NOTES: 1. ECD = 13.7 ppg EMW 2. Packing off periodically 3. Rotary stalling out 4. Picking up to 400k max. 5. Torque at 23k - 26k 6. 130 SPM I 2200 PSI 7. ROT = 240k; PU = 325k; SO = 190k Drilling up rathole and 20' of new hole to 11558' MD NOTE: 1. Packing off, stalling rotary, 50 - lOOK drag while cleaning rathole. Nfade several trips through rathole cleaning up. Pumped 2 nut plug sweeps \vhile drilling 20' of new hole due to bit balling. Perfonn FIT NOTE: 1. Targeting a FIT of 14.5 ppg EMW; however, it broke over to 800 psi after 1 minute (14.25 ppg EMW) and to 710 psi after 10 minutes (14.1 4/21/03 00:00-01 :30 1.50 01:30-02:30 1.00 02:30-03:30 1.00 03:30-08:00 4.50 08:00-09:00 1.00 09:00-12:00 3.00 12:00-13 :30 1.50 13:30-14:00 0.50 14:00-15:00 1.00 15:00-15: 15 0.25 15: 15-15:45 0.50 15 :45-21 :30 5.75 21 :30-23 :30 2.00 23 :30-00:00 0.50 I 4/22/03 00:00-01 :30 1.50 [ 01 :30-02:00 0.50 02:00-03:00 1.00 I, 03 :00-10:00 7.00 I ( I I 10:00-15:30 5.50 I 10:00-15 :30 5.50 I 15:30-16:15 0.75 I Continue flushing annulus with 10.6 ppg mud. 230 bbls total. Seawater line hose fitting parted at factory end. Discharged onto 13.8 KV cable. Safeout and change over to rig power. Rig up to test BOPE. Pressure test BOPE; 250 low 4800 high. Pull test plug. Set wear bushing. Blow down lines. Trouble shoot and change out top drive oil pump. Make up BRA #6 drilling assembly. Shallow test MWD & RSS. Continue making up BRA #6. Rill with 9 stands ofRWDP. Lay down 12 joints ofRWDP. Change liners to 5.5" on MP #1. Rill with 5" drillpipe to 11329' MD. Tagged up on cement (approximately 7 bbls left on top of plug at 11430' MD). Cut and slip drilling line. Check brakes. Wash and ream from 11271' MD to 11329' MD, cleaning hole. Pressure test lines to 3000 psi. Flush 13 3,8" x 9 5/8" annulus with 10.7 ppg mud at 1 bpm with 920 psi. NOTE: Broke over at 1500 psi at 1/2 bpm. Install test plug. Change out upper rams. Service top drive. Begin work to change out liners to 5.5" on #2 mud pump. 20:45-21 :00 0.25 21:00-00:00 3.00 16: 15-00:00 7.75 ppg EM\V). 2. Perfom1ed FIT twice to confirm no surface leaks on first attempt. 3. The ne\vly established ECD hardline is 14.0 ppg. Drill new fom1ation from 11,558' MD to 11.843' MD. NOTE: 1. Bit balling initially, cured with walnut sweeps. 2. Rap extremely low (2-15 fph); however picked up after approximately 30'. 3. Sweeps brought back over 2 lbs of metal shavings thought to be from the bit; however, the potential exists that the NBR opened in casing \vhile drillng up the float equipment. 4. Ditch magnets are being checked every 3 hours and metal returns are diminishing. 4/23/03 00:00-01 :30 1.50 01 :30-02:00 0.50 02: 00-04:00 2.00 04:00-04:30 0.50 04:30-12:00 7.50 I ! I 12:00-15:00 3.00 15:00-15: 15 0.25 I 15: 15-00:00 8.75 I II , 4/24/03 00:00-18:00 18.00 I I I 18:00-19:30 1.50 I 19:30-22: 15 2.75 I Drilling with 8.5" RSS & 9" NBR fl 11843' -- 11879' md. Note: RSS responding to downlinks. Experienced problems with top drive oil pump -- pulled to 9-5/8" casing shoe to diagnose problem. Determined oil lines plugged with silicone -- drained oil, cleaned lines and Reservoir and refilled. Rill to resume drilling. Drilling with 8.5" RSS & 9" NBR f/ 11879' -- 12126' md. Notes: - 305k PU; 215k SO; 250k ROT - RSS responding to downlinks. Drilling with 8.5" RSS & 9" NBR f/ 12126' -- 12310' md. Note: RSS responding well to downlinks. Service top drive. Drilling with 8.5" RSS & 9" NBR f/ 12310' -- 12682' md. Notes: 1. ECD's staying below 13.9 ppg EMW 2. 0.5% EP I 1.0% torque trim. 3. RSS responding well to downlinks. Drill ahead from 12687' MD - 13461' MD. TD of hole section. Notes: Drill 22' into the Sag river. Lost circulation. Likely caused by a fault for vug down hole. Prior to losing circulation, ROP was 25 fph then drilled 105 fph for about 10 feet and back to 25 fph. Losses occurred while drilling 105 fph at approximately 2.5 bph. Lost circulation. Circulated at 2 bpm, losing 2.4 bpm (150 bph) for a total of 195 bbls lost. Stopped circulating and lined up on the trip tank. Established static losses at 0.7 bpm (42 bph). Decision to POOH to the shoe to eliminate risk of differential sticking.j POOH with 21 stands to 11,462' MD -- lost 22 addtional bbls \vhile POOH to shoe/Total Losses are 195 bbls. Notes: 22:15-24:00 1.75 - First 7 stands pulled without incident. - Stands 8 and 9 pulled tight and required signifícant \viping (12,700' - 12,850'). - Stands 10 - 17 pulled relatively easy \vith signs of ledges that required wiping -- ledges did not go away. No signs of swabbing. - Stands 18 and 19 pulled tight and required signifícant wiping with tendency to swab. Rill from shoe to TD 04/25/03 00:00-02:30 2.50 Trip in hole with drilling assembly to spot LCM pill at 13,448' MD. Notes: 1. RIH with pumps off. 2. Very ledgy with 450k max overpull and 125 min slack off. 3. Significant trouble at 12,700' MD, 13,000' MD, and 13,200' MD to TD at 13,448' MD. - stacking up numerous times even when attempting to wipe. - ledges in these areas would not wipe out -- repeated overpulls. 4. Hole took approximately 5 bbls during the trip in (less than 2 bbls per hour). Spot LCM pill. Notes: 1. Pill contained 30 ppb Barofibre and 10 ppb of Walnut. 2. Pumped at 32 spm I 2.7 bpm 1750 psi 3. Chased with 2600 strokes. 4. No losses observed while pwnping on bottom. Trip out of the hole to the 9 5/8" shoe at 11,517' MD. Notes: 1. Layed down the single without incident. 2. Tried repeatedly to pull the first stand, but would not go. Overpull to 475k. Decided to begin pumping out of the hole. 3. Started pumping at 2 bpm and 600 psi. Started to packoff. Adjusted pumps and POOH with pumps between 40 and 60 strokes for rest of trip. 4. Pulled out with some packing off and overpulls of 450k until approximately 12,500' MD. 5. Pulled better with frequent wiping until 11,600' MD. 6. Pulled good to the shoe from 11,600' MD except had overpulls of 450-475K last two stands to get into shoe. 7 . Necessary to reduce pump rate to 12 to 24 spm on last two stands up into shoe to prevent packing off. Condition and circulate at the shoe. Monitor well. POOH 3 stand wet -- hole not swabbing. Note: Lesson Learned about pull rate required to break fluid couple with pipe for the high break back yield formula for this intermediate fluid. Pulling too slow equates to swab similar to pulling too fast -- 120 and 110 see per stand swabbed while 90 sec per stand pull without swabbing. Pump dry job and blow down. POOH to the HWDP. Monitor well at HWDP. POOH and lay down HWDP with correct hole fill. LID BRA #6. Clear floor. 02:30-04:30 2.00 " l I I 04:30-10:30 6:00 I I I [ I , [ 1 0: 3 0-12: 3 0 2.00 12:30-12:45 0.25 [ I 12:45-13:00 0.25 13:00-17:00 4.00 r 1 7: 00-1 7: 15 0.25 17:15-17:45 0.50 17:45-19:30 1.75 I 19:30-20:00 0.50 ¡r '1 I I I I I I I I I 20:00-21 :00 1.00 21 :00-21 :30 0.50 21 :30-00:00 2.50 PJSNl -- RU casing tools. P JS~1 on running 7" liner. Rill with 7" 29# Hydril 511 liner assembly with reamer shoe. Notes: 1. Centralized shoe track and three joints below the liner equipment (above the 9 5/8" shoe). 2. Centralizers are floating. 8 total. 3. PU 125k; SO 108k with pipe full, liner in the hole, with one stand of 5" drillpipe. 04/26/03 00:00-02:30 2.50 02:30-03:30 1.00 03 :30-04:00 0.50 Rill with 7" 29# Hydril 511 liner (joints #24 - #54). Make up liner hanger assembly. Mix Pal Mix (set up 30 minutes). Run one stand of 5" drillpipe. Circulate one liner volume (80 bbls). Notes: PU = 125k; SO = 108K Rlli with 5" drillpipe to 11,452' MD (shoe at 11,517' MD). Notes: Filling pipe every 10 stands. No losses. Circulate a drill string and liner volume at shoe. Notes: 1. 241 bbls pumped at 80 spm I 1050 psi 2. PU = 320k; SO = 200k; ROT = 245k 3. At 15 rpm, torque = 18k ftlbs Rlli with 7" liner to 11,797' MD. Notes: 1. Stack up with 45k, 60k, 85k, and 11 Ok lbs. 2. Slowly making progress working liner through ledges to 11, 824' MD. Rlli with 7" liner to 12,105' MD. Notes: 1. Stack up with 11 Ok lbs. Unable to work past ledge. 2. Pump at 24 spm and rotate at 40 rpm to work past ledges. Rlli with 7" liner to 12,952' MD. Notes: 1. Stack up with 45k, 85k, and 11 Ok lbs. 2. Unable to work pipe past ledge or obstruction. 3. Pump at 24 spm and rotate at 60 rpm to work liner past ledge/obstruction. Rill with 7" liner to 13,310' MD. Notes: 1. Stack up with 45k, 85k, and 11 Ok lbs. 2. Unable to work pipe past ledge or obstruction. 04:00-11 :00 7.00 11 :00-12:30 1.50 12:30-13:30 1.00 13:30-15:30 2.00 15:30-19:00 3.5Q 19:00-00:00 5.00 04/27/03 00:00-04:30 4.50 Rill with 7" 29# L80 Hydrill 511 liner. Notes: 1. Ream liner from 13,330 - 13,445' MD. 2. 29 spm / 450 psi. 3. 40 to 50 rpm with 25K to 27K torque. 4. Torque reduced -300/0 with addtion of 0.50/0 and 2.00/0 EP Mud Lube and Torq Trim. respectively. 04:30-05 :00 0.50 05:00-07:00 2.00 09:00-12:00 3.00 Rig up Baker cement head. Establish circulation up to 5.5 bpm at 950 psi. Note: As rates were staged up, there were some tendencies to pack of[ however, the pressure would break over after a few minutes. PJSìVl -- Test cement lines to 4500 psi. Set hanger and attempt to release. Notes: 1. Drop hanger setting ball. Pump down at 5.5 bpm. 2. Pressure up to 2300 psi at 2870 strokes to set hanger. 3. Set down to 110k lbs (90K slack off). 4. Pressure up to 3200 psi, bled pressure to zero and PU to verify release of liner weight -- not released. 5. Repeat Steps 3 and 4 with 40K down in attempt to release-- unsuccessful. 6. Set down and pressure up to 4250 psi to blow ball seat in landing collar (attempting to set hanger in case of over pinning). Still will not release. Try to emergency release from hangerlpacker assembly. Notes: 1. Pick up 5' pup to allow for more downstroke. 2. Work 20k ftlbs of left hand torque into pipe for mechanical emergency release. 3. Lay down 5' pup and pickup 15' pup for more travel room. 4. Work down to 13,461' MD and slack off to 90k lbs. 5. Pick up to 200k lbs with 10k ftlbs of torque. Still not released. Continue trying to release from hanger I packer with no success. Notes: 1. Working 10K left hand torque down hole in hopes of emergency release. Rig down cement head in preparation for POOH. PJSM -- Cut and slip 102' of drilling line. Adjust brakes. Lubricate rig -- Service top drive and crown. POOH with 7" liner. Notes: 1. Pulled up with 450K on first stand. Slacked off and pulled free with 425K. Slacked back off and when pulled back up weight fell off to 330K. 2. Pulled 30' but could not get out without swabbing. Decided to pump out of hole. 2. Pumping at 24 spm 1270 psi / with 270 hookload. 3. Aireated fluid coming out of the drill pipe at connections. 4. No losses and no swabbing. 07:00-09:00 2.00 ~ I· 12:00-19:00 7.00 I I 19:00-20:00 1.00 20:00-21 :00 1.00 21:00-21:30 0.50 I 21 :30-22:30 1.00 22:30-00:00 1.50 f I I I I 4/28/03 00:00-03 :00 3.00 I I POOH with 5" drillpipe from #114 - #99. Notes: 1. Starting to pull faster (according to Sperry Sun schedule), no s\vabbing or losses. 2. Pumping at 24 spm I 270 to 110 psi. 3. Hookload was 260k at 12,290' MD; 240k at 11,800' MD. 4. Fluid coming out of the drill pipe at connections no longer showing signs of air; looking more like u-tubing. 03 :00-04:00 1.00 Monitor well. Pump 14.6 ppg dry job. Blow down lines. Clean rig floor. 04:00-09:00 5.00 Continue to POOH to liner running tool. No liner. 09:00-09:45 0.75 Inspect and lay down tool. Notes: 1. All parts accounted for to include drill pipe wiper plug. 2. Sent back to Baker for inspection. -- Still tearing it down at report time; however, did confinn that the hydraulic release mechanism was sheared. 09:45-10: 15 0.50 Clean floor. Pump out stack. Pull wear ring. 10:15-11:00 0.75 Set test plug. Rig up for BOP test. Fill stack. 11 : 00-18 : 15 7.25 Test BOP's. Rig down, pull test plug, blow down lines, drain stack, and clear floor. Notes: 1. Test 5" 2. Test 7" (no test on top Rams) 3. Test 4.5" 18:15-19:15 1.00 PJSM -- pull mouse hole and riser. 19: 15-19:45 0.50 Secure rotating ring off upper ram doors. 19:45-20:30 0.75 Change out 4 1/2" x 7" ram on east side and pull ram out of west door. 20:30-21 :30 1.00 PJSM -- Rig up to pull the pit-side door and pull ram out of west door. 21 :30-22:00 0.50 Rig up and pick new door. II; 22:00-23:15 1.25 Install new ram door and new 4 1/2" x 7" ram and door seal. 23: 15-00:00 0.75 Nipple up riser, mouse hole, turn buckles, and rotating ring. ;-, 04/29/03 I 00:00-01 :00 1.00 Continue installing turn buckles and lift ring on hydril. 01 :00-02:00 1.00 Run Junk Catcher Sub. I I RU BOPE Stack Jetting Tool and Flush Stack. Pull Junk Catcher Sub. 02:00-05:30 3.50 Pressure Test BOPE Stack to 2501 4800 psig. I 05 :30-06:30 1.00 Pull test plug. Set wear ring. RID BOPE testing equipment. 06:30-07:30 1.00 PJSM. RID SWS wire line for drift and liner correlation runs. 07:30-09: 15 1.75 Trouble shoot wireline toolstring (GR tool). . 09: 15-09:45 0.50 Change out toolstring. I 09:45-14:30 4.75 Run #1 (GR/CCLI wi 5" sinker bar max OD). I - Find liner top at 11282' elmd. - Tag fill @ 13168' elmd. - POOH fl sample bailer run. 14:30-15 :00 0.50 MU BHA #2 (CCL wi sample bailer wi 2.125" max OD). I 15 :00-18:00 3.00 WL Run #2. - Tag fill @ 13222' elmd. I - Slack off several times and fill sample bailer. - On surface - recover finely ground shale from bailer. * See pictures sent in with forv.rard plan. I 18:00-18:30 0.50 Rig DO\Vll S\VS wireline. 18:30-19:45 1.25 PJSM for MU BHA #7. MU BRA #7 which consists of the following: 6" OD Bit (no jets); 3 jts 4" HWDP; Jar; and 2 Jts 4" RWDP. [ 19:45-22:00 2.25 PU 63 jts of 4" DP. 22:00-22: 15 0.25 Check swivel. Note: 1) Bottom seal on swivel has slight hydraulic oil. 2) Fix requires removing pipe handler. 3) 10 to 12 hour repair -- Tool Pusher feels this can be repaired during prep for drilling hiatus. 22: 15-00:00 1.75 RIH wi BHA #7 -- clean out assembly. 04/30/03 00:00-02:00 2.00 RIH wi clean out string from 7762' md to 12988' md. -- Find Top of liner at 11288' md. Set down 10 K lbs and PU off liner top. Run through liner top without any trouble. -At 12988' md, PUW= 290 KJ SOW= 210 K lbs. 02:00-03:00 1.00 Wash from 12988' md to 13349' md (landing collar). - Top offill @ 13330' md. 03 :00-06:00 3.00 Circulate Hi-vis sweeps x 3 while reciprocating and rotating. - Rotated at 130-150 rpm. - Circulated at 16 bpm. - Finely ground Kingyak, Miluveach, and Sag cuttings were returned across shakers (Size varied from coarse to down to powder). 06:00-07:00 1.00 Monitor well. - Set down on landing collar and attempt to move liner down hole 3 x IS by slacking off 50 K lbs. No movement. 1(1 ..,I - Pwnp dry job. 07:00-13:00 6.00 POOH wi 5" DP to 4" DP. I' - SLM 5" DP- no change from previous talley. I 13:00-13: 15 0.25 Monitor well. 13:15-14:00 0.75 POOH wi 4" DP to BRA #7. - SLM 4" DP- no change from previous talley. I / 14:00-15:00 1.00 Lay down BRA #7. 15:00-16: 15 1.25 Clear floor. PJSM. MU BRA #8 (7" Fas - Drill Pkr). I 16:15-16:45 0.50 Dry hole tree in cellar was found to be starting to tip over because of subsidence. NS24 was SI and dry hole tree was secured. .. -- P JSM for moving dry hole tree. Move dry hole tree. I 16:45-18:00 1.25 PJSM. Pull test tugger lines. 18:00-19:00 1.00 RIH wi BHA #8 (7" Fas-Drill Pkr) on 4" DP. 19:00-00:00 5.00 PJSM. RIH wi 5" DP. I 05/01/03 00:00-01 :30 1.50 RIH wi Fas- Drill Pkr from 12330' - 13348' md. I 01 :30-02:00 0.50 Fill Pipe and break circulation. PJSM for RU TD head. I 02:00-02:30 0.50 Set Fas- Drill Pkr at 13343' md (element depth) I Top of Plug @ 13341' md. - Fas Drill took 4 attempts (25, 20, 20, 25 turns to right). Slacked off 20 K I lbs and then 40 K lbs onto pia. - Suspect slips were coated with solids which had to be worn off. 02:30-04:00 1.50 RU cement head. I 04:00-04:30 0.50 Sting out ofFas- Drill and establish circulation inside the liner up to 5.5 bpm \v/ 1040 psig. 04:30-05 :30 1.00 Spot 75 bbls of 12.6 ppg Hi-vis sweep inside 7" liner. 05 :30-07 :30 2.00 Sting back into Fas-Drill and attempt to circulate around 7" liner without success. - Slack off and place 20 K lbs on Fas- Drill. - Break circulation and pressure up to 2500 psig. Bleed off and pressure up to 1500 psig - 4 times - not able to establish any type of circulation. Pressure up to 4000 psig and to 4500 psig-- no circulation established. - 4500 psi applied to top of Sag with 4500 psi and 12.6 ppg mud is 20.5 ppg EMW -- Float Track is plugged. 07:30-08:00 0.50 Rig Down manifold and cement head. 08:00-09:30 1.50 MU top drive and rotate. Notes: - Rotate setting tool to extend stinger on more time. - Sting back into Fas -Drill and attempt to circulate one more time without success. 09:30-11 :30 2.00 Trip out of 7" liner without pumping dry job- leaving hi-vis pill in 7" liner. 11 :30-12:00 0.50 Monitor well. Clean rig floor. 12:00-13: 15 1.25 PJSM. Slip and cut drilling line. 13: 15-14:00 0.75 Service top drive and drawworks. [ r 14:00-14:30 0.50 Monitor well. Slug well. Blow down top drive. 14:30-17:00 2.50 Trip out of hole wi 5" DP. 1 7: 00-17: 15 0.25 Monitor well and change out elevators. r 17:15-18:15 1.00 Trip out of hole wi 4" DP. 18:15-18:30 0.25 Lay down Fas-drill plug setting tool. 18:30-18:45 0.25 Clear floor. I 18:45-19:30 0.75 P JSM. Rig up wireline. - Clear floor and cellar area. Arm gun. 19:30-23:45 4.25 Rill wi 5', 4.5" RSD, 12 SPF perforation gun. I / - Tie into SWS Depth Determination Log Dated 29-MAY-03. - Tag Fas-Drill Plug at 13342' elmd. - Perforate gun from 13259'- 13264' rod. Very little weight change. Log I off 3 collars. POOH. - At 200', Clear rig floor and cellar area. Surface - All shots fired. 23 :45-00:00 0.25 Rig down wireline. II I 05/02/03 00:00-01 :00 1.00 RD wireline. Bring Tools to Rig fllor. I 01 :00-01: 15 0.25 MU BHA #9 (7" EZ-Drill, running tool, plug catcher sub). 01:15-02:30 1.25 Rill wi BRA #9 on 4" DP. I 02:30-04:00 1.50 Change to 5" equipment. - Break down cement heads. 04:00-07:30 3.50 Rill wi 5" DP to 11185' - above liner. I 07:30-08:00 0.50 Break circulation prior to entering 7" liner. 08:00-09:00 1.00 Rill to 13240' md- just above perforations. 09:00-09:30 0.50 RU Baker Cement Head. I 09:30-10:00 0.50 Break circulation and set RES EZ-Drill at 13210' md. 10:00-15 :00 5.00 Attempt to establish circulation through perforations in 7" linerfrom 13259'-13264' md. I - Choose 1100 psi as max pressure not to exceed based on EMW I I I l I 22:30-23:45 1.25 calculations of 14.6 ppg @. top perf (13259' md/l 0804' tvdrkb) and 1.+.4 ppg @. 9-5/8" casing shoe (11517' md/9386' tvd rkb). - Perform Pressure Cycles while monitoring bleed pressure as follows: * Press up to 700 psi & bleed to 300 psi for six cycles (Cycle time improving from 10 minutes to 9 minutes) -- very slight sign of returns into flow line. Lined up on trip tank 1 to measure returns. * Press up to 800 psi & bleed to 300 psi for 6 cycles (cycle time reducing from 9 minutes to 8 minutes) -- extremely slight stream ofretums improving with time and resulting in full returns measured in trip tank 1. * Press up to 900 psi & bleed to 500 psi for 6 cycles (cycle time improved from 7 minutes to 4 minutes) -- returns rate visually improving with full returns measured in trip tank 1. * Press up to 1000 psi & bleed to 700 psi for 4 cycles (cycle time improved from 5 minutes to 2 minutes) -- returns rate visually improving with full returns measured in trip tank 1. psig. Established circulation while continuing pressure bleed cycles. * Press up to 1000 psi & bleed to 800 psi for ten cycles (Cycle time improving from 2 minutes to 1 minute) -- returns rate visually improving with full returns measured in trip tank 1. * Well started circulating while attempting to increase the pressure to 1100 psi -- broke back and started circulating @ 3 spm (0.25 bpm) with 1020 psi and full retuns. Establish circulation. - Initially at 3 spm (0.25 bpm wi 850 psig). - Continued slowly increasing rate in lspm increments to 1 bpm into trip tank without any losses. - Switch over to active system pit 1 E. Continued circulating at 1 bpm wI 1060 psig. Slowly increase rate to 1.7 bpm wi 1680 psig. - Increase rate to 1.75 bpm wi 1720 psig and begin to have slight losses (5 bbls in 10 min). Losses quit and pressure reduced to 1600 psig. - Slowly increased rate to 2.1 bpm and developed pack off wi pressure spike to 1760 psig. Back off rate and pressure still trying to climb. Quit pumping and pressure not falling off. Bleed down and attempt to regain circulation 2 times at miminum without getting returns. Discussion with core rig team on rig floor to review data leading up to pack off and discuss forward plan. - Decision to Perform Step Rate Test to establish injection rate for Pumping Cement Job without returns. Suspected that pack off was occuring at Liner/Hanger/Packer and formation was breaking down @ 9-5/8" casing shoe which had LOT data for 14.4 ppg EMW. - Plan to set balance cement plug on top of EZ drill in event that decision is made to not run cement bond log based on poor results of cement job. - Mud Engineer informed WSL that :Nl\V in closed circulating system L Pit and Pit IE had lightened to 12.2 ppg. * Approximantely 75 bbls of 12.2 ppg drilling fluid had been circulated into drill string. * Additional light spots ranging from 12.4 to 12.5+ had been circulated. * Good consistent MW in and out would be required to perform forward plan. - Decision to unsting from EZ drill and circulate and condition mud while 15:00-15:30 0.50 I I 15:30-22:30 7.00 I I ( I I I I I I I I pumping max acceptable rate of 5.5 bpm through EZ drill setting tool stinger.condition MW back to 12.6 ppg (MW had slipped down 12.1- 12.2 I ppg in and 12.3- 12.4 ppg out. Condition surface mud in Pit 1 to 12.6 ppg. 23 :45-00:00 0.25 Bleed pressure down to 300 psig and sting out of EZ-Drill. I Circulate and condition mud while adding barite to achieve consistent MW in = MW out + 12.6 ppg. - Held discussion with Mud Engineers regarding maintaining proper mud I weight. 05/03/03 I 00:00-03: 15 3.25 Sting out ofPKR. - 5.5 bpm wi 850 psig (12.6 ppg = MW in = MW out) 03:15-03:30 0.25 Decision made to take single out of string since it is evident that the liner I is not going to move downhole this will make cement head LD safer and more efficient regarding dumping 4 bbls of cement on top ofEZ Drill. - MU cement head and sting back into EZ Drill Pkr I - Set 20 K lbs on EZ drill. 03 :30-04:00 0.50 Attempt to establish circulation without success. - Leak off occured at 1350 psig. I 04:00-05 :00 1.00 Perform step rate injectivity test: Rate (SPM) (BPM) PSIA 6 0.5 1440 I 12 1.0 1510 18 1.5 1550 242.0 1610 30 2.5 1700 36 3.0 1760 42 3.5 1840 I 48 4.1 1950 54 4.6 2050 605.1 2140 *Total bbls pumped 20 bbls. Bleed back 10 bbls. * ISIP= 1370 psig. I 05 :00-06: 15 1.25 Held Planning MeetingIPJSM for cementing thru EZ Drill with no returns. - Revised Forward Plan while crews ate lunch. - Moved fluid between rig & G&I in preparation for cement job. I 06: 15-06:30 0.25 Sting out of EZ-Drill PKR. - Well is static. - Close hydril. I 06:30-07:30 1.00 Pump cement job as per plan while holding back pressure with choke to prevent cement from falling away in drill pipe: 1) Pump 10 bbls sea water. Test lines to 4500 psig. I 2) Pump 35 bbls 13.0 ppg Alpha spacer. 3) Mix ,and pump 85 bbls 15.9 ppg tail cement. 4) Pump 7 bbls of sea water. I 5) Drop dart. 07:30-08:00 0.50 Displace cement wi 89.6 bbls with 12.6 bbls mud. - SD pump and close choke. I - Sting into EZ- Drill. I I I 08:00-08:30 0.50 I 08:30-11 :30 3.00 I 11 :30-12:00 0.50 I 12:00-12:30 0.50 12:30-00:00 11.50 I I I I 05/04/03 00:00-01 :00 1.00 I 01 :00-04:00 3.00 04:00-05 :30 1.50 ( 05 :30-06:00 0.50 06:00-07:30 1.50 07:30-08:30 1.00 I 08:30-09:30 1.00 09:30-11 :00 1.50 11 : 00-13 : 15 2.25 - Bleed annulus to 0 psig and open hydril. - Continue displacement with 116 bbls of 12.6 ppg mud. - Good cement lift (4 bpm wi a pressure increase from 1500 psig to 1900 psig). Increase rate to 5 bpm wi 2440 psig at 2430 total strokes. Rig down the cement head and single. Rig up on top drive. Circulate hi vis sweep and shear wiper dart out at 2650 psig @ 2493 strokes. - Circulate at 5.5 bpm wi 875 psig while reciprocating 35' without any rotation. Monitor well and pump 3.3 ppg over dry job. POOH 4 stds. Inspect traveling block sheaves. -Find one sheave bad. -Hang blocks and inspect further. Sheave bearing is found to be worn out. - Make plan for repair. Decision made to restring blocks and utililize unused sheave. - Formulate plan and gather tools for job. - Order out e-line string up cable. - Spool on 2600' e-line onto drawworks. Braise to drlling line. - Unstring blocks. 13:15-14:00 0.75 14: 00-15: 00 1.00 15 : 00-15 : 15 0.25 15:15-16:30 1.25 16:30-17:00 0.50 17:00-18:00 1.00 Shift change. Review plan for restringing the blocks. Hold PJSM. String e-line out of the bad sheave and through the spare @ crown & blocks. Braise e-line to drilling line. P JSM for stringing drilling line through sheaves and back onto drum. String drilling line through all sheaves and back down to drum. Place wraps on the dead man. Spool of the 2600' of eline. Secure drilling line on drum. Slip line. Unhang blocks, grease sheaves, make several test runs while observing sheaves, secure oil pump prower supply line. POOH wi BRA #9. - D 1 Drill. - High winds causing electrical line to top drive oil pump to blow into Kelly hoses - creating hazard in that it may get caught and possibly parting.. PJSM. Disconnect eletrical supply line from TD oiler pump. POH to 7900' md. Lost dry job- pipe pulling wet. Pump dry job. POH wi BHA #9. - Find worn couplings on 5" DP. PU cement head. Make service breaks. Lay back do\vn. Lay down two worn singles. PU 2 singles from pipeshed. Continue POH to 4" DP. Monitor well and change handling equipment. I I 18:00-19:45 1.75 POH wi 4" DP and Lay down EZ-Drill setting tool stinger running assembly. I 19:45-20:00 0.25 Clear and clean floor. 20:00-22: 15 2.25 MU BHA #10 -- 6" - 6 bladed mill. 22:15-23:00 0.75 TIH wi 69 jts 4" DP. I 23 :00-00:00 1.00 TIH wi BRA #10 on 5" DP. 05/05/03 I 00:00-02:00 2.00 Rlli from 5673' - 11275' md (just above 7" liner top at 11288'). 02:00-03:30 1.50 Break circulation. MW out= 12.0- 12.2 ppg. Condition MW in= MW out = 12.6 ppg. I - Circulation rate 170 spm (14.4 bpm) wi 3200 psig. - While circulating, Rig Electrician reconnecting power supply for TD oiler I pump (had been secured during high-winds yesterday). - On btms up some finely ground Kingyak and Sag cuttings came across shakers. I 03:30-04:15 0.75 Attempt casing test. Leak off occured at 800 psig or 14.2 EMW at 9-5/8" shoe. 04: 15-06:00 1.75 Continue Rill wi 13085' md. I 06:00-06: 15 ' 0.25 Wash down to 13207' md. - No cement on plug? 06:15-16:30 10.25 Mill on EZ Drill Pker f/ 13207' md. Chase EZ drill down to 13239' md- Top of cement. Continue to mill on EZ-Drill, Fas-Drill, Landing collar, '"' and Float collar. -- Tag Reamer shoe at 13434'. md. I 16:30-17:30 1.00 Circulate Hi-Vis sweep at 560 gpm wi 3600 psig surface to surface. 17:30-18:00 0.50 Monitor well. Pump dry job. 18:00-22:00 4.00 TOH wi 6" milling assembly. ( - PU Wt offbtm 350 K lbs. - At 13216' md - overpull60 K lbs. RllI wi see 10 K bobble down. Pick I up through without any trouble. Run stand through area without any trouble. Continue POOH. 22:00-23:00 1.00 Swap over to 4" equipment. Monitor well. Continue POH. 23 :00-00:00 1.00 Swap over to 3.5" equipment. LD BHA #10. Clear & clean rig floor. I -- Good recovery in boot baskets. -- 6" mill somewhat cored in center. I 05/06/03 I 00:00-01 :00 1.00 Remove tools from VLE. Spot up E-liner. Load up equipment and sheaves. 01 :00-01 :30 0.50 PJSM for picking up logging tools. I 01 :30-02:30 1.00 RU wireline. String e-line. MU & test logging tools. 02:30-03:00 0.50 Wireline crew that had taken over Unit was not told that counter wheels had not been changed over for bigger line.- Change counter wheels. I 03:00-15:00 12.00 Run #1: Log USIT -CBL across 7" liner. - Place log on Interact system. Log evaluated by Anchorage Engineering (Cumulative total of 87' of cement above Sag). I I I - USIT sonde would not work below 13392' md (Impellar would quit spinning). I - Log Primary Depth Controllog.- POOH w/ USIT. 15:00-17:00 2.00 Break and lay down logging tools. Bring H.ALCO Fas Drill BP & running tools to floor. I 17:00-22:30 5.50 Run #2: J\tfU 7" Fas Drill BP. - Rill and tie into Primary Depth Control Log. - Set HALCO 7" Fas Drill BP at 13250' elmd (above squeeze I perforations). Log off. RIH and tag Fas Drill.- POOH. 22:30-23:00 0.50 P JSM. RD wireline. 23 :00-23 :30 0.50 P JSM. Pull wear bushing. Function rams to dislodge any metal from I inside ram cavities befor pull bushing. 23:30-00:00 0.50 PJSM. Drain stack. Rig up to P- Test BOPE to 250 psil 4800 psig. I 05/07/2003 I 00:00-04:30 4.50 Pressure test BOP's 2501 4800 psig and Hydril to 3500 psig. Test 4" & 5" floor valves.- AOGCC Rep: 1. Crisp waived witness. 04:30-05 :30 1.00 Pull test plug. Run wear bushing. RD BOP testing equipment. I 05 :30-06:00 0.50 PJSM. Prepare to MU BHA #11. - Adjust IBOP valve while preparing. 06:00-07:00. 1.00 MU BRA #11. - 7 2/5" polish mill, Stop Sub, 9-5/8" casing scraper, and 6 jts of 4" HWDP. I 07:00-12:00 5.00 Rill wi BRA #11 on 4" and 5" DP to 11283' md (just above 7" liner top at 11288' md). 12:00-13:30 1.50 Tag 7" liner top and set 'ZXP' liner top packer. Utilizing wt only no I rotation. - Did not see shear with the three attmepts to set. PJSM. Test liner top packer to 3460 psig for 30 mins. I 13 :30-16: 15 2.75 Pump dry job. POOH wi 5" DP to 4" DP wI BRA #11. 16: 15-17:00 0.75 POOH wi 4" DP to BRA #11. 17:00-17:30 0.50 LD BRA #11. I 17:30-18:00 0.50 Clear and clean rig floor. 18:00-18:30 0.50 Service top drive. 18:30-20:00 1.50 Slip and cut drilling line and service drawworks. « 20:00-22:45 2.75 PJSM. MU BRA #12 (6" HTC EP4970 bit, 4.75" PDM SSS- 1.15 deg, 1 ADN4, ARC5, MWD - Slimpulse, PBL Sub) 22 :45-00:00 1.25 Change to 4" handling equipment & Rill wi BHA #12. 05/08/2003 00: 00-00: 3 0 0.50 Rill wi 4" DP and BHA #12. 00:30-06:30 6.00 Change over to 5" equipment and Rill wi 5" x4" DP and BHA #12 (6" bit). - Didn't see any bobbles when entering 7" liner top. 06:30-07:30 1.0 Lost Hi-line power from OPS (Intakes plugging from Hoar Frost-Turbine quit). Fire up rig engines and have Electrician back feed to G & 1. 07:30-08:00 0.50 Wash down and tag HES 'Fas-drill' BP @ 13229' md -- Drill ont Fas-drill. 08 :00-1 0:30 2.50 PJSM. Pump 70 bbls Hi-Vis Spacer and displace well to 9.3 ppg mud. 10:30-12:00 1.5 Wash down and Tag 7" Reamer Shoe.- Drill shoe fJ 13434' to 13436' md. I I 12:00-12:30 0.50 12:30-14:00 1.50 I 14:00-14:30 0.50 14:30-00:00 9.50 r I I 05/09/03 00:00-11 :30 11.50 I [ 11 :30-12:00 0.50 I 12:00-16:00 4.00 16:00-17:30 1.50 I 17 :30-19:30 2.00 Drill shoe and rat hole to 13461' md. Drill 20' new formation 13461'- 13481' rod. FIT test to 1140 psig and leak off occured. -- LOT = 11.35 ppg EM\V wi 9.35 ppg MW Drill ahead 6" production hole from 13481'- 13654' md. Drilling parameters: - ROP from 15 to 60 fph. - WOB= 25 K lbs, 80 rpm wi 14-15 ft-klbs torque, 90 spm or 320 gpm wll800 psig. - ROW= 268 K lbs, PUW= 305 K lbs, and SOW= 236 K 1bs. - BRA showing slight dropping trend 19:30-22:30 3.00 22:30-23:30 1.00 I 23:30-00:00 0.50 I 05/10/03 00:00-03:00 3.00 I 03:00-03:30 0.50 I 03:30-04:00 0.50 04:00-11 :00 7.00 [ I I I Drill ahead 6" production hole fl13654' - 13981' md (11434' tvd rkb). - Total ROP for run is 34.3 - Final hole Incl. of 28.17 and azimuth of 326.06 degrees. Drilling parameters: - WOB of25, ROW of275, PUW of320, & SOW of240 K lbs. - Total flow of320 gpm wi 1900 psig. - 80 rpm wi 15000 ft-Ibs torque. Take final survey and take slow pump rates. MADD pass fl TD to 7" shoe @ 150 fph. Wipe hole back to 13,480 ft. Hole slick. Monitor well. POOH to 11576' md which places PBL sub (2-ported) 100' below 7" liner top at 11288'. Drop PBL opening ball. Pump sweep. Chase sweep staging pumps up to 18 bpm. - Hole is clean - drop PBL closing ball. - Flowcheck well. Pump dry job. Drop rabbit into Std #90. POR wi 5" DP to 4" DP. Monitor well while changing over to 4" handling equipment. - POOH to 4" HWDP. LD 4" HWDP. Lay down BRA #12. - Down load data. - Bit graded 4-8-BT-G-E-l-WT-TD. PJSM for rigging up to run 4.5",12.6 ppf, L-80 liner, Vam-ace threads with 2.875" inner string. R U to run liner. MU float equipment. - 7' of shoe track. Check floats. - Run 19' jts of 4.5", 12.6#, L-80, Vam-ace Liner. - Torque turn each jt which had 2x RHT and stop rings. - Stop short of filling liner with 9.3 ppg viscosified pill. MU up and run 25 jts and 6' pup jt of2.875" fox inner string, space out 4.5 ft above LC. - Fill up 2.875" x 4.5" annulus with 9.3 ppg viscosified pill. - MU Baker liner hanger - 'ZXP' liner top pkr assembly. - Mix up and add Pal mix. Let mix set up for 1/2 hour. RD casing running equipment. RU to Tlli wi drill pipe and to fill string volume after making up 1 st stand ofDP. Rill wi 4.5" liner on 4" DP, filling after 10 stds. Rill wi 4.5" liner on 5" DP to top ofT' liner. Rill wi 4.5" liner through 7" liner to the 7" shoe. - Didn't see the liner top. Circulate String Volume at 7" shoe. - PUW= 314 K and SOW= 235 K lbs at shoe. Rill wi 4.5" liner into open hole to 13975' md without any problems. MU cement head and cement manifold. - Rlli to 13980' md- touch down on fill. - Break circulation at 0.5 bpm and stage up rate in 0.5 bpm increments to 1.5 bpm by midnight. I I 11:00-11:30 0.50 11 :30-12:30 1.00 I 12:30-14:00 1.50 14:00-19:30 5.50 I 19:30-21 :00 1.50 21 :00-22:00 1.00 I 22:00-23 :00 1.00 23 :00-00:00 1.00 I I I I I I I I I I I I I I I I I sperry-sun DRilLING SERVICES Show Report Well Name: NORTHST AR NS23 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: REG WILSON Report Delivered To: KEN LEMLEY Depth (MD) 11 060 to 11085 ft (TVD) # 9018 to 9038 ft Show Report No, 2A DatefTime: 4/14/2003 ( I I Interpretation: Steam still analysis indicates the Kuparuk "C" would produce gas. Drilling Mud contained 5.0 % lubricants. No oil odor/sheen visually present in steam still samples. Sandstone in samples ( 11050-11100' MD) had 0-10% tluorescents,and a brt yel, instantaneous milky white cut was noted. [ Depth 11075 ft Gas x Units 734 Mud Chlorides (ppm) = 19K ---r=lõwiiñë------Süëiíõñ-------si1õw-----------------------------------------------. ppm ppm ppm (Steam Stili PPM's in 1000's) C1 20.8 5.61 = 15.2 - -- C2 2.53 0.87 1.67 - -- C3 1.63 0.85 0.78 - - C4 1.19 0.85 = 0.34 - - C5 0.85 0.79 = 0.06 --PrõëfuCtTõñ------=-----=----------------------------------------------. Analysis [X1Gas nOil nwater pqNon-Producible Hydrocarbons 2 % Depth 11080 ft Gas x Units # 1558 Mud Chlorides (ppm) = 19K ---Fiõwiiñ'ë-------Süëiíõñ-------=si1õw-=--------------------------------------------. ppm ppm ppm (Steam Still PPM's in 1000's) C1 48.1 5.61 = 42.5 - -- C2 4.71 0.87 = 3.84 - -- C3 2.54 0.85 = 1.68 - - C4 1.51 0.85 = 0.65 - -- C5 0.84 0.79 = 0.05 --Prõ'duCtTõñ------=-----=----------------------------------------------. Analysis fXlGas nOil nwater nNon-Producible Hydrocarbons 3 % Depth 11085 ft Gas x Units 1914 Mud Chlorides (ppm) = 19K ---f=lõwüñ'ë-------süëtrõñ-------=si1õw-----------------------------------------------. ppm ppm ppm (Steam Still PPM's in 1000's) C1 68,2 5.61 = 62.5 - - C2 6.18 0.87 = 5.31 - - C3 3.58 0.85 = 2.73 - -- C4 2.03 0.85 = 1.17 - - C5 1.18 0.79 = 0.39 --Prõ'ductTõñ------=-----=----------------------------------------------. Analysis fXlGas nOil nWater nNon-producible Hydrocarbons 4 % Depth 11090 ft Gas x Units 3320 Mud Chlorides (ppm) 19K ---Fiõwiiñ'ë-------Süëiíõñ------Si1õw-----------------------------------------------. ppm ppm ppm (Steam Still PPM's in 1000's) C1 48,6 5.61 = 43.0 - - C2 5.61 0.87 = 4.75 - - C3 3.51 0.85 = 2.66 - - C4 2.25 0.85 1.40 - - C5 1.37 0.79 = 0.58 --Prõ'du-cftõñ------========----- Analysis x Gas Oil C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 I % -"_. - --.--------- - ,.,---,-'--'''-'- -" I Hydrocarbon Ratios C1/C2 9,1 C1/C3 19,6 ClIC4 45,1 C1/C5 266.8 1000,0 . Gas ------,,,- -.------'- -.-..--.--..-- ....-.-.--.- -~.__.. ----,-.---...-- ----. ------,--.-----.. .. ------....--.---- --.---- NPH 100,0 I I Hydrocarbon Ratios C lIC2 11 .1 ClIC3 25.2 C1/C4 65.0 ClIC5 866.9 10.0 _._,~~~.__._-.---,_.~,..._...- --.---.---- Oil _..._. .-.....-.'''-...,-.--..-....-...-...-... .., NPH 1.0 ._._.__.__._.__._,_._~..__~.___..'"__"'_____._._.'_~h_.______ ______._______,._..._.._"._,.. _~_.__..___.. C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 I _h_.,,~_ _,.._._~.__,___..__._..__.._.._,_._.'.R._..·.'R_~...____,__,._._._._.,_...__.,..___,______.._..__,....______ --.-.--..-,..-,--- I Hydrocarbon Ratios C1/C2 11,8 ClIC3 23.0 ClIC4 53,3 ClIC5 162.5 1000.0 ____~_.___~__~....,~,_,__'"_~_____,___.._.___.__.._____._no _.._~._.___.___.___~_._.~_.._._.__._ -~~",._..~_._--_._---- _...~-,._--_...~-_._-,_..,.._..._..._-,_._-~ -_._--_..........~...,._.......,-".-._~.,""--- -.._-~."-".,-,~~.,,.".._---.~._.~-..._.._-- __.~_.._._ _..__... ".. ._. ...._. .~...~____..~.. _...___..........,.._ ...~.__..~_.~.m. ..__..~_. .__ .___"_..,_...~~_..~___~.____.._...__ __~._.___._.._...._._.__..__..__...._,.._ ..,,____._.._._....~...m._..'..____~_ ..___..___".,,__..__.____,__..__ - . .....--,,'.--..- --.."..-.-,-.- .....-..--,-----.----...-...,.-,,--. ---_._-----,_.,-_..---,-- __.__n_._____"______·~~_·_,···_..· ,.._____~_,_____~_,.._,..."_...~.._ ________,.._.....____......._~.._... NPH -----.---.--.-..--"..-.-,,-.....---..--- ...~...._.".__.---_._,,- ~ "," ..-- ---.--.- -_.-._._--~-'''_...-'''_._._......_...._-- Gas 100.0 Hydrocarbon Ratios C1/C2 9.1 C1/C3 16.2 C1/C4 30,7 C1/C5 74.5 10.0 . - _.._._"..."'-,,.,~,...-- ---.-_...... ------.-.-..-- ------- __" _..______._..____. __h____~._·_ Oil ._--~_._._,_... .._._..._....._....~....-"..._....._"'--,_. .---.-----..-.-.... ---.'".-"-.........--- _...._._._-~.._- --------...------- --_.- --....---- _.__._"-_._"'--,-_.~.~ - --."'''.-----------,-.-... ._.---~--_.._--------....,- .-------------.--.--. ---..-..------.,--- ."....--,...---.-.....-...,-.-.,-"" ---. ----------------------------------------------. NPH 1.0 ._____.___~_,.._._._._.h_.~..'''...____. .__._____'"_~_._ .. ....._.._" __~ __'._h.....·~.._·__·___..___,··__·'"_··_·_ sperry-sun DRILLING SERVICES Show Report Well Name: NORTHST AR NS23 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: REG WILSON Report Delivered To: KEN LEMLEY Depth (MD) 11100 to 11150 ft (lVD) # 9050 to 9090 ft Show Report No. 1 B DatefTime: 4/14/2003 Interpretation: Steam still analysis indicates the Kuparuk "C" would produce gas & oil. Drilling Mud contained 5.0 % lubricants. No oil odor/sheen visually present in steam still samples. Sandstone in samples ( 14100-14200' MD) had 20-30% yel fluorescence, .and a strong milky white, intstantaneous cut. I % Depth 11100 ft Gas x Units 3912 Mud Chlorides (ppm) = 19K ---FiõWirñã-------šüëiiõñ------sh"õy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 164.9 5.61 159.3 - -- C2 16.90 0,87 16.04 - -- C3 8.92 0.85 = 8.07 - - C4 4.61 0.85 = 3.76 - -- C5 2.19 0.79 = 1.40 - -- --Prõaüctiõ-ñ------------------------------------------------------------------------- Analysis nGas nOil nwater f'qNon-Producible Hydrocarbons 2 % I Hydrocarbon Ratios C1IC2 9.9 C1/C3 19,7 C1/C4 42.4 C1/C5 114,1 I I Depth 11115 ft Gas x Units # 4525 Mud Chlorides (ppm) = 19K ---¡:rõwlfñã-------šüëflõñ-----=-Šhõy¡.::---------------------------------------------- ppm ppm ppm (Steam Still PPM's In 1000's) C1 73.7 5.61 = 68.1 - -- C2 10.25 0.87 = 9.39 - -- C3 6.50 0.85 = 5.65 - -- C4 3.92 0.85 3.07 - -- C5 2.29 0.79 1.49 - -- --Prõaüëi¡õ-ñ------------------------------------------------------------------------- Analysis XGas nOil nwater nNon-Producible Hydrocarbons 3 % Depth 11120 ft Gas x Units 4338 Mud Chlorides (ppm) = 19K ---FiõWirñã-------šüëiiõñ-----~-h"õy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 66.4 5.61 = 60.8 - -- C2 9.93 0.87 9,06 - -- C3 6.76 0.85 = 5.91 - -- C4 3.87 0.85 = 3.01 - -- C5 2.30 0.79 = 1.50 - -- --Prõaüctiõ-ñ------------------------------------------------------------------------- Analysis XGas XOil nwater nNon-Producible Hydrocarbons 4 % I Hydrocarbon Ratios C1/C2 7.3 C1IC3 12.1 C1/C4 22,2 C1/C5 45.6 I I I Hydrocarbon Ratios C1IC2 6,7 C1IC3 10.3 C1/C4 20.2 C1IC5 40,5 Depth 11150 ft Gas x Units 1691 Mud Chlorides (ppm) 19K ---¡:iõ,¡¡;¡rñã-------šüëfiõñ-----=-Š-h"õy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's In 1000's) C1 29.2 5.61 = 23.5 - -- C2 5.37 0.87 = 4.50 - -- C3 3.83 0.85 = 2.98 - -- C4 2.48 0.85 = 1.63 - -- C5 1.69 0.79 = 0.90 - - --Prõaüct¡õ-ñ------------------ Analysis x Gas x Oil Hydrocarbon Ratios C1IC2 5.2 C1/C3 7.9 C1IC4 14,5 C1/C5 26.2 ---------------------------------------------- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 1000.0 NPH - -. 100.0 ..-,:"""."'" :;¡¿~;¿~~=~~~~ .~ Gas ........-...--. .",-,-~-.",,"-,- 10.0 ...._.._,_.__"'._.m~.._.._._" --~.-.-"-"----' -,---'~,~-~---_.". Oil _.._.._.,._. -...,,-...-·,·-·..-·.._··_·-1·· NPH 1.0 C1 C2 . ... .......... ,.. -.-"......-.,-"" _..,-,,-,..-,--- .__..."-,'"....,",, ...--.",---. Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 ._..-.-,-"._---~.."....~-_.-.,._------ 1 000.0 .".'"_____.__..~"_.___"'... _____,_,"'_... "__,___.____.._____.___._____"". _....._,._.__.__.._......._....._u___.__.··.._ -.--.----..--...--. _......,.".__,."._....____,_,._._._,.__..._'._.,M.. ".. ,,_..,.",_______.__ _. ",........_..__ .._ ..__,,,,,,._.__,.",..,_._.,.__,.. ._ ......_--.-..... ._-_.,---",,,-_.._.,,---,." " -,-_._.._,."_.~., '''--''-'--'''-'''-'"---''---''--'-''''---'''- .-.-.-...-.--..--..----.. --_....._...._~.,_.-._.._,....._. ._-,,--,- .----.--.-.--.-..-----.-.-- ._- NPH .- ,.-..--.....-...----.--------". .--.--.-..-,..-..-.---..------...- ._._--..._..-...._.......-....,,-----.._.~.... ....____._.~__.____,,_.__~.... .___.....______.....__..__..._ ~,____._..__,..._..__....__..m._..._ 100,0 -- -- ..... \ -- ~~;;::;;;.;:~;;;ö......~~-':i:-- ~..::~~=-~=:::::::: :::::=:,::,=::-:::::-,==:=:~ __.._._n______..___._.._~___._. '__'_"_""__""'~_._""'_' __.__. .._.... ... _.____,,_, ._, _ ,..._. . .._n_.._._ Gas .----.----".-.....,...-.--.."...-........-- .- -..-.._-"-...,,...__....- .__.._,,~. --,..-..--..".-.,.-. 10.0 Oil .. .... .....---.....-...-....-.--- - ..............-..-..-....---..-.- ------_.__._._~_. _.-..-- .... .-.--.-- -----.-..----.-..- _.-- ,.--- -.. -.._IIIIIIII. '"......_.........__ __........_.__..._. NPH 1.0 I sperry-sun DRILLING SERVICES Show Report Well Name: NORTHST AR NS23 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: DOUG WILSON Report Delivered To: KEN LEMLEY 13462 to 1351 0 ft 10982 to 11024 ft Show Report No, 2 DatefTime: 5/9/2003 Depth (MD) (TVD) I Interpretation: Steam still analysis indicates this portion of the Sag River would produce oil and samples showed 10% clean porosity. Drilling Mud contained 2.0 % lubricants. No oil odor/sheen visually present in steam still samples. Samples ( 13500-13550') had 30% of a bright yellow fluorescence and a fair to good moderately milky yellow cut fluorescence cut. A trace of tan stain was present in the samples. % I Depth 13480 ft Gas x Units 596 Mud Chlorides (ppm) = 18k ---FiõwiTñ¡-------§üëtiõ-ñ------sl1õy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 27,5 2.64 24.8 - -- C2 3.52 0.58 = 2.94 - -- C3 3.04 0.78 = 2.26 C4 2.68 0.74 = 1.95 - -- C5 1.82 0.53 = 1.29 - -- --Prõduëïío-ñ------------------------------------------------------------------------- Analysis XJGas XJOil nwater nNon-Producible Hydrocarbons 2 % I Hydrocarbon Ratios C1/C2 8.4 C1/C3 11.0 C1/C4 12.8 ClIC5 19.2 [ Depth # 13500 ft Gas x Units # 387 Mud Chlorides (ppm) = 18k --'FiõwiTñ¡-------süëiiõñ-----=-sl1õy¡.=---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 19.5 2.64 = 16.8 - -- C2 3.44 0.58 = 2.86 - -- C3 3.23 0.78 = 2.45 - -- C4 2.78 0.74 = 2.04 - - C5 1.66 0.53 = 1.13 --Prõduëïiõñ------=-------=---------------------------------------------- Analysis XJGas XJOil nWater nNon-Producible Hydrocarbons 3 % I Hydrocarbon Ratios C1/C2 5.9 C1/C3 6.9 C1/C4 8.3 ClIC5 14.9 I Depth ft Gas Units Mud Chlorides (ppm) = --1=iõWiTñ¡-------ši.ic"tiõñ-----=-sti'õy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 1.0 0.00 = 1.0 C2 1.00 0.00 = 1.00 - - C3 1.00 0.00 = 1.00 - -- C4 1.00 0.00 = 1.00 - -- C5 1.00 0.00 = 1.00 - -- --Prõduëïío-ñ------------------------------------------------------------------------- Analysis nGas nOil nWater nNon-producible Hydrocarbons 4 % ( Hydrocarbon Ratios C1/C2 1.0 ClIC3 1,0 C1/C4 1.0 ClIC5 1,0 I Depth ft Gas Units Mud Chlorides (ppm) = --'FrõwiTñ¡-------§üëiiõñ-----=-S-ti'õy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) 1.0 0.00 = 1.0 - -- 1.0 0.00 = 1.00 - -- 1.0 0.00 1.00 - -- 1.0 0.00 = 1.00 - -- C5 1.0 0,00 1.00 --Prõduëtiõ¡;------=------ Analysis C1 C2 C3 C4 Hydrocarbon Ratios C1/C2 1.0 C1/C3 1,0 C1/C4 1.0 C1/C5 1.0 ---------------------------------------------- 1000.0 NPH 100.0 Gas C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 - -. --- - - - -- -----:.~---:;¿;¡¡o:""""....""': - , - , - ..- ;':'.~:""~ -. .-- ---... -.-......... --..-.---.-.-- _____,.,,,,._._.__._. .,,___~_..._,,__ "_..__'h _._. . ._.._....".____.._. "__,,,__._.__~. 10.0 ~=;;~~~:-;'f~;i~~ Oil- - ..-..--.,.-.-,--.--....- .----.,---..----.....- C1 C2 -'-'~ - --'- _.._...__._.._-,...._-..._-_...~. Hydrocarbon Ratios C1 C1 C1 - - C3 C4 C5 NPH 1,0 1000.0 NPH 100,0 Gas 10.0 Oil NPH 1.0. ..._.h_...~..___h..'.'_.....,_.,..__..,.._~..._.,_.. ,._,.....__..""._.,..__._...__,,___,,_. ____._._""_~....._._ _,___..___.__. m n n____.."..."...__._........._ __ _ _ _......__.._....__.____..n.__._.n.____ ._.._.._ _" . .-- .---.,--... _._......._",._.._-"'-._~--- ----_._--------_.~-~- ... ... -- \ . ..._...,....... ~...._.~.._._....._h. _,_____..._.._..__._..._.__..._.._.._.,_._...__... . -.. --'-"'''-'-''-'-'-"'---'-'''-- .h_~"__.'__"_..___,___......._'_'__"'_ _.._____.,,_...._.._____.,,__.__. __h___._____.__ ...-_1 ...-...- -_...-:.... - _~ h~ _.___.__.__. '._'_"'_._~'_"R_'_ _ ___, _ ...... ....___._.._.._.._. _.,..,__._..'R" ..__.__..__._"._.... ..___ . ----..-.--- .--.--.-.-.-- ._-,,--_.__.,,----.-,--_.- ...__._ _ __,,_,,_,.........'"_..__._"_____m__ __._... __...__. O.'h__'_". ,___"... n."_._",,'.,_ n... _ ._ ~.__ ,_. .__.__..______ n. ..__~..... ._h.._....,._..___,,__...._h.__ . _._._m'__'_ .___,,_..... '_"'"_"n'__ _ ._ '_.___0 -......-,--------.-- -I(IIII!II---..----....--'-,...---. ,,_ - . . . sperry-sun DRilliNG SERVICES Show Report Well Name: NORTHST AR NS23 Location: NORTHST AR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: DOUG WILSON Report Delivered To: KEN LEMLEY 13657 to 13900 ft 11149 to 11362 ft Show Report No. 3 DatefTime: 5/9/2003 Depth (MD) (lVD) Interpretation: Steam still analysis indicates the Ivishak is wet, due to negative line slope and there is a thin oil bearing zone at 13760' MD. Drilling Mud contained 1.0 % lubricants. No oil odor/sheen visually present in steam still samples. Samples ( 13650-13900' ) showed trace to 10% yellow fluorescence with a trace yellow white cut fluorescence at 13800 sample.. I % Depth 13665 ft Gas x Units 207 Mud Chlorides (ppm) = 18k --FiõW1rñã-------§üëtlõñ------§-ti'õy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 9.4 2.64 6.8 - - C2 1.50 0.58 = 0.92 - -- C3 1.61 0.78 = 0.83 - - C4 1.73 0.74 = 0.99 - -- C5 1.29 0.53 = 0.76 - -- --Prõëiüë'fiõ-ñ------------------------------------------------------------------------- Analysis nGas IXlOil IXlwater nNon-Producible Hydrocarbons 2 % Depth 13750 ft Gas x Units # 130 Mud Chlorides (ppm) = 18k ---¡:rõwirñã-------süèiìõñ-----=-Šhõy¡.::---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 11.6 2a64 = 8.9 - -- C2 1.18 0.58 = 0.60 - -- C3 1.09 0.78 = 0.31 - -- C4 1.24 0.74 = 0.50 - - C5 0.98 0.53 = 0.46 --Prõëiûclío-ñ-------------------=---------------------------------------------- Analysis nGas nOil nwater nNon-Producible Hydrocarbons 3 % Depth 13760 ft Gas x Units 288 Mud Chlorides (ppm) = 18k ---Fiõwlrñã-------§üëiìõñ-----=-Šhõy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 34.0 2.64 = 31.3 - -- C2 3.83 0.58 = 3.25 - - C3 2.93 0.78 = 2.15 - -- C4 2.54 0.74 = 1.80 - -- C5 1.60 0.53 = 1.07 -Prõaüë'fío-ñ------=-=-------=---------------------------------------------- Analysis nGas ['qOil nwater nNon-producible Hydrocarbons 4 % Depth 13900 ft Gas x Units 171 Mud Chlorides (ppm) = 18k --FiõW1iñë-------Šüèilõñ-----=-Šhõy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) 5.1 2.64 = 2.5 - -- 0.6 0.58 = 0.03 - - 0.8 0.78 = 0.03 - -- 1.1 0.74 = 0.36 - -- C5 1.1 0.53 = 0.53 --pñDëiüctiõ-ñ------=-=------ Analysis I Hydrocarbon Ratios C1/C2 7.4 C1/C3 8,1 C1/C4 6,8 ClIC5 8.8 I I Hydrocarbon Ratios ClIC2 15,0 ClIC3 29.3 C1/C4 17,9 C1/C5 19.6 I Hydrocarbon Ratios C1/C2 9,6 C1/C3 14.6 ClIC4 17.4 C1/C5 29.3 [ Hydrocarbon Ratios C1/C2 82.0 C1/C3 -82.0 C1/C4 6,8 C1/C5 4.6 C1 C2 C3 C4 ---------------------------------------------- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 --.. -. -~_....~--_.---_._- ~-_..---~--_._.__._- ..---- 1000.0 --------- ._-_.~---.- -- NPH 100.0 --- --- ..;....-...,.... --.-- _..._~:"...~.....~.._._- - u__ ___"_' __.._~_ ____ ~ _ _ __._..___ _.___ - ~-_.._....._.-._--_.- .._-_.~_. -- Gas ~.. -II 10.0- - - - - . _ ._.._. ____._u.. _u___ .._,_..__.__,___,_,_ ".~~.~_ ~..,__ _'R.__ ___....._,__.__. __.._.__.___.. .___..__._..____.__ Oil .___,_n'_""'___h._ '~_h"_"'_"_""_,""" NPH 1.0----·- --....--..--......---.- _..._,,-_._-.-----..-_..~---_...__.._.__..._~. - -.-.---..--.---.-.---.---- - -. .. --.... '-"-'---'-'--"'-'-- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 _......._--_.._._-------_..-~-,,- --. .---..----.-"--.---,..-.-.--..--.....,.,,----- -,--".,--.-----.---...,.-.... --..,...-..-...------.....-.,,-- 1000.0 -- -... -_._..-_..-..".-.--..--""---_.._----_._..__..~._-"' .-....,_..-_........_--.. -------~_....--_.._._-,~. -----.-- __.."...___...... _.·_""...._____..__·~_..h..._. _ ...~,,__..... _.."... ,___.______.._~ _..__..._,__".__.__,_.,..____ ... . .... ....._..."~._....___.__ .,__._""__,"...,._.__._"._...._._."._....._,..,,_ _____.._.___..._._h.~_. ...__..m._'_'_,,_...._ . ..... --.-...-.-. .._-,-,,---,-_....__..~...__._.."'._-_.. -..- -.- -.--,---.----......------ U'__ ._.___..____.____.h.._' .. .... .-. .,,--..-....--""..--.----,---..-...-- _.,,_.._,......~..-------.-"'---_._.~. .._..__...~-_._....."...."...__.__...,.._- NPH 100.0 --' -- --- ~- --- --~--- - - ~~-~..::~~.:::::.. ;.. ---- ~ - . - -.--..,,-- ._-_...~.__.._.._.~----- ~-- Gas 10.0 ---------.------.-"....---.-, --.--.---.-------,-.-..-......,----.-. ---..-.----,--.---.--..---- u _n.".... _._ _._.. '_"_'_"'_' ____. "_.,, ______.__".__ _._.___._._.,.._,,___ ._... ... ____'__'_ ___."""..__ Oil __,,_~__"__R ------- --~ ---.-..-.--...-,---.--.--- -------...---.--,--.-- .----..---------------- ---.._" ----....---.----------.-...-...-.. - ... ~~--_..-._--_.--._-_.__..- .._...,-_._---",~.-._-~_.-._------ .-..--..-.--..------ ---.-.-----.----.--- _.~._..._. .-----,-.-"..-..-----.,,-- NPH 1.0 _.~~__._.~____..~.·.'h...._.___.._____ _.,___",___._.,_,__..__._..____. "'_._._..__....~.._____..__._,____ I I 5per"~Y-5un Customer: Well: Area: Lease: Rig: Job No.: c:::; R i L..L IN G 5 E"A V I c: e 5 Mudlogger's Morning Report BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 1 4/2/2003 201 o P/U BHA Polya / Clump Current ~,<,\~".~'!j,,;:,."'t';\,;:;';·~·..~.;,~,J~·~ ,;'~,I' '~·...':·r', ~'; .~':'~':"-^t,;,,~·'~t~~·:~<':~;,.~\, r~~~~\:~'~~·"; ~:~,oi~'i.~... ·,,-,¡'i ,'. '" ¡~', ,; . ~.,~,; :'~/~~~ì~'"<?:.;i:":~~'\';';'~·'\I;'·,~'.~":,~,:,"-~ ::;: .:J";'T,'; '.~ '; '".' ~;,.;:,.: Bit No.: Wt On Bit: 24 hr Max ftJhr @ units @ deg F @ 201 Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm A V @ DP psi AV @ DC 24 hr Avg ftJhr ( 19 unit~ ( ( R.O.P. Gas * 19 Temp Out ft/hr units Deg F ."1'1I.;,-:".;1''' ", ~-I -,j"...... ..,..." .' r .,,,:"~ -... '" -·"1(;r1:;..:': :..¡;'-~.,' :'.·\I'~"'~' ....., ',. ,'. ,," ... 'ió:,p.. Mud Wt In Mud Wt Out 9.05 ppg 9.05 ppg Visc 150 secs API filt 11,5 ml HTHP Mud Wt at Max Gas PV 22 cP YI 58 Ibs/100ft2 Gels 16 / 16 / 31 Ibs/100ft2 pH 9.2 Sd --- Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to , ",j~'::~]LI.~:.Jl'I,~".."I.,LL1.D.[,.,._IL,.", Current Lithology: % 19 .' ..:~. ....,'.' ,~~,'r':;" .,,':~~"'~~:;b.:'~~',/:~~'1:'~~'~~.i'..'::~~':.~:_~~-'~\'-:':~\~~4:;~..~'f1~~·.;;~'.~-.' ,~~.~-;.~ ~:,~t'..:J~,t·~\;;:'''\:~\f}r.,~:\..~~.¡"¡.(~~~~'·-'!·~'''rJ~,,,..,f.~~'-'«:r;' ":~ .''-;:1.: ....::.~ :.~. ...-.:I!,.·:~",,-';'~::'4~';~/If~·~~,i'i~.-::'t/~:t?:'¡~> . ¥""~ :"7,;·$":'~~,,,,~~'~. .~''i.'':~:'r,~¥·-::'- I I I I I I Type: MX-C1 Bit Size: 16 Jets: ~ x ~ RPM: Hrs. On Bit: Total Revs on Bit: .. ..," (,U:,::LI:L~;;I~;:D';r::Jl:l\::::(~"." 1 x 12 \ TFA: -- Footage for Bit Run Mud Cut: ppg Trip CI: 18000 Mud Cut: ppg Short Trip CI: to Feet of Fill on Bottom: ! [ IT nil ~r~:=1Sa~D'u_''''lIV~"....."JD~-;;a;;;:- % % % %LCM I~-·. gpm gpm fpm fpm Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ~ ~ Drilling Breaks Depth Drill Rate Gas % Lithology 1 before during after before during after Sst Sltst Cgl to to to to ~!:¡ p pg .~<!' o %~: ~" tJÙ ;.,;, ',"<'" ',"..: '<'f¡~,: 10~1:J' . " ppm ~ ppm ¡! ft _·'~M.:'t"k'"~ø~~~-· ''';¡;:.''''-~ , ;Jr_~~w~D,..~Uw::"r.~WIf~..n~m.., ;~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. ¡. Description of fillings: ~~:'~¡',~1~':'f!lll~'$~~~;~~~'!i~'!~¡~';'~~"'I<f;1¡t!iii~¡~, . :~ 24 hr Reci Finish rig up on NS 23. P/U bit and start drill out conductor to 122'. POOH to make up heavy weight ~ and BHA. '\ :1 f ~¡ i:~1: ::~ Logging Engineer: Tom Mansfield 1 Doug Wilson * 10000 units = 100% Gas In Air ~~;'."\ .<-:} '~~~?>t.~,~~:~)~~~j~:~\4;~t~l~~{~~~~~{~1_~%~~fijt,~~!~~~~.~~~~~17~Ý2~~):~'~:.' Customer: BP Alaska Report No.: 2 Well: NorthStar NS 23 Date: 4/3/2003 " I sper'r'Y-5Un Area: North Slope Depth 502 :~:? Lease: NorthStar NS 23 Footage Last 24 hrs: 301 or -497 ~..: ï:J AiL... i... i N G SEAv:c::es -') Rig: Nabors 33E Rig Activity: Sidetrack Job No.: AK AM 0002371818 Report For: Polya / Clump Mudlogger's Morning Report Shows: r Current 6 15 80 24 hr Avg 24 hr Max Pump and Flow Data ft/hr 400 ft/hr ( 1128 ftJhr @ 563 Pump 1 72 spm DH flow units 17 unit~ ( 25 units @ 235 Pump 2 90 spm Total flow 685 Deg F ( 80 deg F @ 502 Pump 3 spm AV @ DP Pump Pres 800 psi AV @ DC ,'.- ,',;,~\, I>\-" ; '.;,'" ':' :~~:r:. .-.':.'.~ :,t~):--',:'f~;'~'~~f~;::\\.~':":'";"~.::·,·~¡:>';'~ ":'r: )j~',.~~"~,.,~;~,;{:~f'¡,."'.( 1~1,:,!>..""'.:¡.,,>~';'¡t't~~~,·"'Y.,~:~~:::4~~~;·f/<S ~:~~~"'~{~~'", ~;IA";'>~~~~: ~ ·~0"·,}';';::~JJ;;" ';","~,,':~'~~:.J ·:'¡:;~·~·f·;:~:,{~:~~~~:~·,~;;:;,: ~~~~~~~·:S;~~~'~";''''··:'~'::';~~' ,~', _\i',"!,'I~~ ,';.:,,:. :~: r .' "" ~rf~~':~ ':,,:':'":": .:' >:; ..,:ot:~ .:'.'~'~,,:. ,:; :~~~~A':~\\~:~i:::~µ.~~~.~; ~'?J'~~"I:~~w~~·\'~:~1~~:~~JW4h\~:\.\~:'~)~~Ä~tW4hÞ~~~~~T~~~:?~~S~{:~;¡; ~f·-Ç~.{~~{~£.~tt~~m,?ffi;~~:d~i~~'ì'::~&;;}~~t~\·:~.:~¢J{r~#.t~~$?:,~~':'~~JY~).~}~,;'f:~:fr:: ./~~~M\~)~)j:'.:":':'::~,;'t,:(.i~~\~:li~~~f~~~':·-<~;':';J~:~~~kf ,~' '" I Mud Wt In Mud Wt Out 9,10 ppg 9.10 ppg Visc 92 secs API filt 12.6 ml HTHP Mud Wt at Max Gas PV 20 cP YI 47 Ibs/100ft2 Gels~ / ~/ ~ Ibs/100ft2 pH 9.7 Sd ppg 1.5 % I Bit No.: Wt On Bit: 2 Type: MX-C1 Bit Size: 16 Jets: ~ x ~ ~ x....!3... _ _ TFA: RPM: 0 Hrs. On Bit: 2.5 Total Revs on Bit: 26k Footage for Bit Run ~,:mr~.~u,·~···lt:::Q;::;,:m~:ÄØlVr:~' 1.0310 301 [ Trip Depth: 1000 ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to ~·;:;mt;t::·::ß1~:::C:~=,^"rm=l-tA11',""~~J!l{=,n:=.L ~ none Mud Cut: Mud Cut: to ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: I _._~"L~,=:¿·~;;;~I Current Lithology: % % % % %LCM I Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Sst Sltst Cgl I I r to ~~'¡ :~ , .... :''im~DK.'...L:I'.l'W''\.!lK;':''; -Jlfi-: ·~trfWL '"\lì~lll ~ "'-"'If\l1fi'i¡¡'fr.a~-.J:::::· "' ~~~T.~ ß~'~~~~_~UII,,",~", ~11."")r.u,,:~ ..," ~, , , ,¡~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. ,~1 Description of fillings: 1;11 "~~'·~:;;~\':fil1!.;.,¡til¥~;~~~!(,\i¡..~!o!t\'(~~~~~;~if!~~~Þ~~~.~!i,~'i'¥~W.~1!Ù7f;:t~';:.":';:·':·!·1(~' ::~ 24 hr Recê P/U motor and bit, RIH and tag ice at 50'. Clean out conductor to 122'. POOH and P/U drilling BHA #1. ' .,¡~ RIH. Finish cleaning out conductor and drill 30' of rathole. Run Gyro. POOH and P/U BHA #2. RIH and start ¡ drilling. Drell to 999'. POOH to check Gyro, approaching hard line. Directional attempts unsuccessful. RIH to 465' ~ and open hole sidetrack. ~~. ~: Logging Engineer: Tom Mansfield / Doug Wilson * 10000 units = 100% Gas In Air %:~,;" ·:·:;:~~~\;;:~;~~::·:<r,,;'S:;j.r~~ï~¡#~¡~~~~~~J_~t*S~~~:1.~:~;~~:;~~ç;;:~:~:?::~,t{~;·#~~ I r I I I I I I I Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 3 4/4/2003 1.854 1352 DRILLING Polya / Clump '·K ..,.... :. \,~ spe.....,...,y- sun o A I L...L IN G 5 E A V I c: e 5 R.O.P. Gas* Temp Out ':-",:",';, '. ,. ~~~ :Ii;, ~':~~'.~~~,,: ,~"~.\ ,'¡ ',',~ " '~-i,~~ ""1~~:':~')'~?~~>t l. .': ;p' ~:':7::·,~:,~·~~~~1~"j:',~,;~.'·: :'~~I:,~~:~·:~·.~;~at:b-;:;-,~~~:~~,¡ <~::)~:i<,\\-;~i~:\I1ýl:,p",,~),~~~~~~'.:,~;', }~'..\.: 'h":"~~' '~ '->"I~~\:r:~' .",,;:~ "'i,\'.:~:~. :¡~,:~}'~.~~~,:{"~.'~~',~;;~'-~~~, Current 79 20 52 ;' :' ':'::':'_,,~~"; '~'\f' '..i.~ "~,:::.~: ';-~;;;~'¡':'\~'" 24 hr Avg 24 hr Max Pump and Flow Data ftJhr 274 fUhr ( 1147 ftJhr @ 1768 Pump 1 110 spm DH flow units 11 uniÜ ( 27 units @ 1652 Pump 2 110 spm Total flow 931 Deg F ( 52 deg F @ 1854 Pump 3 spm A V @ DP Pump Pres 2330 psi A V @ DC .. '>,.:.~:,:: .::i,~:g~,:"i:::~¡::l;;·"~·::i::~V(i,~~.~;{,~\:V:j':; :;::-'·:/,~'~~~H:;:~~\~_~;"'lf~fA~":f$';;.~t$.~::~à\J,,~_~$~*~~:if~~~~~~~wt¡~:~,:-1~,·~:X'f.~~~~(~%'t;!~~i},~~~~~~~~~~\~~~t~~$~~~M~~fft.t~~!~:>t:,f~~~t\),~~~~:%.~t*1'!~~~~~~!~t.'hJ';~\',,->::~~:,,1:,_~ " Mud Wt In Mud Wt Out 9,10 ppg 9.10 ppg Visc 92 secs API filt ~ ml HTHP _ Mud Wt at Max Gas _ ppg PV 20 cP YI 47 Ibs/100ft2 Gels 14 / 20 / 25 Ibs/100ft2 pH 9.7 Sd 1.5 % --- .. :,:, S;-1~,.>\'f?I~"\."¡,,~':,r..\i\»~~~~~':.:;,,.'"':..'¡~·~~';~ ,~~rt"~ ~ ~';;'/:-;-';;I': '¡"'~:I.~*,~*~ith~i,J" ·~'~:·;~f &).~~~ï:<:::;~b ::"',jt~t~ '!.~\~,:'......~' ~/,,'<;·.,:'~:~,,;'~'~~'tt~t:",,;.~~·,~,~,~,,~;·~,:,~:::·!)'.~' , "d~. 1.:"¡: '!"" '.,:: ".'. ..:.fl '.'~, '...... ,t"' _' .:f' ,~:~1~\ ·I~,.~r. ::.: r....~~,>~ ...~ ,j''" '~;,'~î',.,,~ -- , ,:. . . Bit No.: Wt On Bit: Type: MX-C1 Bit Size: 16 Jets: ~ x ...3.9... 28 RPM: 0 Hrs. On Bit: 10.0 Total Revs on Bit: . ..:...." :;Y~~'Di.~1(;k:n~:~~·:æ:,._:1UI~:.:~~:.. Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to ,',UJ'Jf:,LI:=~rL.rm:~::::Jt:XJ:JJ=~'JitI1C: 11" 1 ¡. Current Lithology: % ft ft ft units units units ppg ppg ppg 1 x 12 \ TFA: ---- 1654 Footage for Bit Run 1. 031 0 1,854 Mud Cut: ppg Trip CI: ppm Mud Cut: ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft ~-a:::Œ:(I,_Jlhr,~.;;.~~~:rtJJJDm.J::t-:::~r:v'c~-m:::::]I 1m] ~¡. % % % %LCM "I' ft ft ft units ppg units _ ppg units ppg Depth Drill Rate during Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg Drilling Breaks after before Gas during after % Lithology Sst Sltst Cgl Top of Permafrost 1210' MD, 1196' TVD Bottom of Permafrost 1575' MD, 1524' TV Logging Engineer: Doug Wilson / Mark Lindloff before to to to to 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. Description of fillings: t¡I;~~~~'$~~~~"~~~'~~~~~'~ 24 hr Recê RI H to 500' +/- after checking directional tools. Sidetracked from 544' to 818', gyroing every connection repaired top drive, continue drilling/sliding to 1854'. * 10000 units = 100% Gas In Air , , ~ :~'..."~:~:(~~1~~'~Z~~~0tr.~:~:tt.$)~.'~¥~~~~~~~5i;~'iF~~¡,~~~~f~~~~f~fA~K·~r~~'.~~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. Description of fillings: ,~~~:·.i\·;~f~:;:~/;~~~,~~~:V~;\·,~~¡~~~~i~¡\1~_~;~~.tt^1~~':i~;:~ .~i 24 hr Reci Drill From 1854' To 3686.1' MD ;~1'~' Circulate sweep to clean hole. POOH to 400', RIH to make sure side track was good. Lay down BHA #2. I,~: Rig up 13.625 casing tools. !~ ~. SV6 3506' MD, 3066' TVD :~! TO 16" section 3686.1' MO 3206' TVO I· Logging Engineer: Doug Wilson / Mark Lindloff * 10000 units = 100% Gas In Air ',- ,'t:;~ .'. ~. <. ,... .:r-:"'i '~:\:~~?~"J~~~~"f{%:~;~~¥{W¡~~~~~~i~~/~_~~~;';::::;:':~'~~~~~7.kt~:~~~~~,~~:;;:r\t·7':';!:~: ~- ¡e~~""'-"" I\j~~~_: % Lithology Sst 81tst Cgl Gas during before after after Drilling Breaks ft units ppg ft units ppg ft units ppg Connection Gas and Mud Cut ft units _ ppg ft units _ ppg ft un~s ppg % % Mud Cut: Mud Cut: to 001 ] -!f'W-:-- ~~Jt'!!=~ ppg Trip CI: ppg Short Trip CI: Feet of Filion Bottom: to to to to Drill Rate during before Depth ppg ppg ppg units units units ft ft ft % % Trip Depth: Short Trip Depth Tight Spots: :~UC:~I~ Current Lithology: ft Trip Gas: ft Short Trip Gas: to to ~;,~~::W~:J: .-;¡.--_ 1.0310 3,686 Bit Size: 16 Jets: 3 x 20 1 x 12 \ TFA: ------ Hrs. On Bit: 17.6 Total Revs on Bit: 203K Footage for Bit Run II"UVI]I::C~II.MJ"JiU[J::n;¡¡~:~\t":::[,ur:~"" Bit No.: Wt On Bit: MX-C1 o 1 Type: 28 RPM: --- ~. .:~ ..,." -'", "'~:ìI.~':8~\~..;::r:.v.~~M.~--:;~Jf"=.!'3r~.·Ã-t..- ~~';:"t:~\l{iw ~..,,~~. ..)¡·~<'1'l.··:'.'f+~.;.r:·~~3'i;~"'~·~;þ~~~\"ß.,)':~..t>~I'~\~tJ'I..-(~~..6,~~ :'\.~~;~ ~é"'C:'·~~ t~~-~;'l\-F~~1W.~~~$¡¡\:,~:9';:~:' ,::;-~,",~~¡,p:~:'.: .:'~~ 1;.'" ';.~I~ ':.::;C-}.¡.!~ :~·.~1:~:·..~;.,:':·~~~r;::.¡~·r,{::",.~.·~. Visc ~ secs API filt ~ ml HTHP _ Mud Wt at Max Gas _ ppg PV 21 cP YI 42 Ibs/100ft2 Gels 18 / 26 / 31 Ibs/100ft2 pH 8.4 Sd 0.75 % Current 24 hr Avg 24 hr Max Pump and Flow Data R.O,P. 0 ft/h r 303 ft/hr ( 868 ft/hr @ 2265 ) Pump 1 110 spm DH flow Gas" 0 units 16 unit~ ( 37 units @ 2316 ) Pump 2 110 spm Total flow 931 Temp Out 75 Deg F ( 75 deg F @ 3686 ) Pump 3 spm AV @ DP 73 Pump Pres 2710 psi AV @ DC 88 .. 9.40 ppg 9.40 ppg Mud Wt In Mud Wt Out , , ,,\t "...\ ".,' ~ ~j'~,./, ,~;i.~:,',-: ,I :', :~~: ",.' ;, '~i~<',~.. '1," ,.'\;. .. ~' .'\ '~ " :: ~~;>': '.~\~'(~·~':':-:,b~'¡"~)~~", ;¡.~-!~~'-~r~l :\~~;HÞ/~,~~~, ~{;~rC\~.~:i"":~ ': ',1 \~:~~~;~;:t..: ',~'X~'.'" ~~~~'~~":'~~~.~,n~~~~':.i~.~_tt~,;.~·, ',' ~~"\{~t;,·~~,,,:,/"~). ~ _ "~·\í::.".t'i·_~~,~1'~';::r.~.r"~,:' ~~~,:,;~:';~·:'~~',~¡~)l;·:~~-r -;; ~'-~~~;. Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 4 4/5/2003 3,686 1854 RJU Casing Tools Polya / Clump BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: sper'r'Y-5un DR I L.L IN G 5 e A v IE=: e 5 "":':~"""<{~':-',7 '~'~'i ,~,h~~~~~~,':;~~" .' ;\ ~,~ ."~:..';;,'. I I 1 ~ ~ I I I I I I I I '" ;'\;,:~~ ": ~ ~ ~ n Loggi ng Engineer: Doug Wilson I Mark Lindloff · 10000 units = 1 00% Gas I n Air , ,~~:~~~~~~~~~~~~~~;~0~~~~~~~~¡~ pl:',:·~:;,;>\H~+Â':1)Y,';;t~~'¡ij¡¡;tt_¡ .' c,'c ···c . ......:..' . ~,.~11~iM':_.,~~~~,~.I._"â'x1;~~.;.,"t¡~.:J;,~~~~~~~':tlð'ì,,~~fKh\r~,!. f 24 hr Recé Continue to Rig up casing tools, Run 13 3/8" casing, last 5 joints tight, land a 3665' , rig up cement Head, slowly establish circulation, circulate and condition, Pump cement as per well plan, bumped plug, nipple down riser and begin to nipple upo BOP's oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg - ft units ppg ft units ppg ft units ppg - - ft units ppg ft units ppg ft units ppg , Drilling Breaks ~ Depth Drill Rate Gas % Lithology before during after before during after Sst 81tst Cgl to to :r; to to ·..v..··' I I I %LCM % % % % Current Lithology: I Mud Cut: Mud Cut: to Trip Depth: ft Trip Gas: 27 units Short Trip Depth ft Short Trip Gas: Tight Spots: to to .,,!:3t:J::1U¡;~:':Dt::~QlJI:U::::.L-:J.1,L...."~ ~ 11II I ppm ppm ft ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: '~~];;:JM~ ~""""i'Y«J,,",~'a......,o~,"""'''''''''''~ I :~J Bit No.: 0 Type: 0 Bit Size: 0 Jets: 0 x 0 0 x 0 \ TFA: 0.0000 I Wt On Bit: 0 RPM: 0 Hrs. On Bit: 0.0 Total R~n Bit: 0 - Footage for Bit Run 0 ~:~~~J,:1:Jr)I:'JJ~l"1AJ(:?a:nDJ~ l:m:m~~"'U1UJL:U\ìI....Q.t1t~1111;W*.'le:~ Visc £.. secs API filt 13.2 ml HTHP _ Mud Wt at Max Gas _ ppg PV 21 cP YI 31 Ibs/100ft2 Gel~~ / ~/ ~lbs/100ft2 pH 8.4 Sd 0.75 % 9.35 ppg 9.35 ppg Mud Wt In Mud Wt Out I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O,P. 0 ft/hr 0 ft/hr ( 0 ft/hr @ 0 ) Pump 1 0 spm DH flow gpm Gas· 0 units 0 unit~ ( 0 units @ 0 ) Pump 2 0 spm Total flow 0 gpm Temp Out 70 Deg F ( 70 deg F @ 3686 ) Pump 3 spm A V @ DP 0 fpm Pump Pres 0 psi AV @ DC 0 fpm I I ",'I >~',. ',~' .' :*~~_i~~... ~~:1. ~,r~~;~:!~;'"~"~;_~" .;,...l>\f,.~~:~.'-. ~1YI~~:~ ,,~,.~,,;.: ,Irr>~' ,,·'''¡~':;·:'..:',¿'i'';'1~'~~.'','.~'',~1(;\: ',.t.~':~~~,~'~'~;;1i'!'~~,¡:' '~~ ~'~'I'r;} ~~';~~~";\:~::j'\;~~ì;:;+'~ ~~t~?:;'¡~,~.,(·:~· ;:;,,:,":'?;f ~1f'<~'; f'/~ :~"J~' ~':i,,;';' ·,;'..~~v..."'~··~·'.~~~;'~"":~f~· ~~,~ ~;r~~ ;~"f~ '~'~~':\'~\.~1~~~t:¿,::,~' ': ~"" ;;'.';',~~ 5 4/6/2003 3,686 o RJU BOP'S Polya / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 5 hows: BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report I spe...,....,v- sun o A I LL IN G S e R v I c:: e s o ,.\;. <~ii~:;S~;.i1~):'~~~~,~;{~\>. . I - , .1' "';.." '," /"":~"':'~,M~,;.~".:J: ';.'¡~;JIf"t0:',"f-""::'!,:~,>}...',I~ ,,~, -.,~.~:,( ¡,I> "1r~>.r "~f~~~~~'::f~~;~~!~7""~~"~''':·'I; '.' ,~.'. ~~~~.~rl:,~:"~n~".~,~~/,~r,~,.,\,r" l. '}"':,< ,~" '. ~ 10000 units = 100'''.) Gas In ~Ir ,;,;;, Doug 'Nilson ' ~.1ark Llndlotf '11 ',~ ',~, ·.~.ìt ~ :" Logging Engineer ,~==~~lU1JII [J! 1- -i.r}~.J11U1;"'fTW IF f~l::::JI::: ..... ..... ~-,,- % % %LCM - Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg - - ft units ppg ft units -ppg ft units ppg ft units ppg ft units -ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology }~ before during after before during after Sst Sltst Cgl ~ to - -- - to ~ - -- - to - -- - ~j to - -- - --- -. , .. ¡¡¡' . ,~p. ,- .. ...' '" ~ ~. , .. "Vo"':"" I 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. ~,~ Description of fillings: t .. .' ..'". ,""'-""" .~~- ; " ,,~,h, ,..' ", .,.' \~ ~ 2'4 hr'Recé Continue N/U BOP's. Test BOP's, P/U BHA #'3, RIH to Shoe. Currently slippi~g and cutting drillline~' '~, :t~{ d I I I I ppg" :"'.¡ 0.75 % .~.; "':;~~ '\J" Bit No.: 2 Type: RSX238HF~s Bit Size: 121/4 Jets: ~ x ~ ~ x ~ _ \ _ TFA: 0.9410 I ,..: Wt On BIt. i) RPI\," 0 Hrs On BIt. 0.0 T ùlal Re'Js on Bit· I) Footage for Bit Run I) 1;1:, r!. ~~.~~'~.c '," -~; .~. ~ Tight Spots: to to to Feet of Filion Bottom: ft I I , ?;"""'¿:"..r'}~~.~'r.'.~" I''',.'' ·t:".:~~'J.~"~'~·~1;~~,~¥~,.,,:~4'¡1.,,~-.;.'t;~~~~:,:r:.ù~~.~-,(~~i';~:¡;:(C ~)·~~~·~·~1·~~t·.(,:'·d'f~:::\I';"~ ..~.:..~.~~A~~~...ç~:~'''~~~.~::.it~~..'.~\~J';,~.>a''~)~,,~,·~~:.;:....'~:....\.¡~-~.~.~~-"-'/~.;f¡;~.:1I~....,;.~ ~'.'. ..; ~', ¡.'~, F.'·;''',!;".~, > '\\. ~'" '':'''~.' .' 'f;i I:;: \'. Vise 67 sees API filt 13.2 ml HTHP Mud Wt at Max Gas - - PV 21 cP YI 31 Ibs/1 OOft2 Gel~ 15 1 19 1 22 Ibs/100ft2 pH 8.4 Sd --- ppg ppg 9.35 9.35 Mud Wt In Mud Wt Out . '--. .:':'" -', .. ~ ,...' -' ..11., -~ I' ,. "'l-"", . ~ .:..., "" '. -' :.\" .... .~.... "'.,TII!'~ ';".: ."I1..,.~ ,.,,;~. ....... ,. .. I I gpm .);.~ gpm 6 fpm;~; fpm';,:, o o o Current 24 hr Avg 24 hr Max Pump and Flow Data R.O,P. 0 ftlhr 0 ft/hr ( 0 ftlhr @ 0 ) Pump 1 0 spm DH flow Gas* 0 units 0 unit~ ( 0 units @ 0 ) Pump 2 0 spm Total flow Temp Out 70 Deg F ( 70 deg F @ 3686 ) Pump 3 spm AV @ DP Pump Pres 0 psi AV @ DC r . j1':~'; ',,-~~~~~' ,t~':":: f ~.:.'").:' ,"" ~.: ::~. ·~:'ttj:~~~~~~~,~~':~~~~~~~1."r~ti~'~ 'i \,;~.~;",. ~i·~,~~"~;'l'~.~;:"'" ::'~. ;} '~"~,':" 1,' '.")'1~~ ,:~' ':;1;;\' :)' 'i'J" ~~~:.: ,:.;:,\/p;.r::;· ~ ~,~;~,~?:;,.~,' ~':.~".':r!'~~;,\\·~:~ 'j' ;' '"",~ 6 4/7/2003 3,686 o Cut & Slip Drl Line Polya / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report I CJAIL-LING SEAVlc=es 5pe....,.....y- sun 5pe....,....,y- sun OR I LLI N G SEAV I c: e S Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Mudlogger's Morning Report - ,'")' ~"';'-j' '~' ,;t~ ":~·¡<~"'.\\ì'~':,'-"~ ~ ":;,~ "'-.,":",' !:..':"\¡;:;:,ìit'-~~,,<,~~,.: ..Jfi'~~''',r.'·. '.~;;,,,,:~,\r:":~"',::;"\,~, Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 7 4/8/2003 6,4 72 2786 DRILLING Polya / Clump I Current 48 97 70 3857 6256 3686 24 hr Avg 326 ft/hr ( 72 unit~ ( ( 24 hr Max 2165 ft/hr @ 392 units @ 70 deg F @ R.O,P. Gas* Temp Out I ft/hr units Deg F Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data 110 spm DHflow 110 spm Total flow spm AV @ DP 2475 psi AV @ DC 931 177 265 gpm gpm fpm: fpm I Mud Wt In Mud Wt Out Visc 56 sees API filt PV 12 cP YI 23 Ibs/100ft2 8.0 ml Gel~ HTHP Mud Wt at Max Gas 7 1 10 1 12 Ibs/100ft2 pH 9,0 Sd 9.06 9.05 ppg ppg --- ppg 0.75 % .:t";:':':A\t\C0:~;¡%~%~'1%¡¡_$i'Wi;,#\1\,¥¡;~It~~Ø:*",!gMXII$fMMâtì~tWM;,øt~_!*~1t1t:!W;fl~~*'~!it\~1IW:¡;:'_~f.!ìt~*1.tæt~(W~~\'!#¡\'01\}l"·ti¡WJ¿~lt~Ii@¡;:¡~~;1'if1'%\t~~\,;¡¡'¡)4t\\%Nìh\4~¥W;)!?:i,' 1i~¡ Bit No.: 2 Type: RSX238HF-+9s Bit Size: 12 114 Jets: 5 x 12 4 x 13 \ TF A: :P"~. ------ ~;_:~~~ ;;;;~~:O::it Run Tight Spots: to to to Feet of Fill on Bottom: '~;.;;'~t'OC'T.":'.::.:J:X::l¡3!W;£-~œ~.=nr:rr^T":::~:J~=-'=:'k~..,~~,.~ IŒ]mI!J~:][1 ~ :lli IlaF'" I I % % Current Lithology: I, ._Un .1.._... I ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft units units units I ", I Drilling Breaks Depth Drill Rate during after before before to to to to % % r mL Gas during after 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: - ft ft ft units units units 0.9410 2,786 ppm ppm ft %LCM ~.MnæRr~H.L ' ppg ppg ppg .: .. f~I'),· ¡ % Lithology Sst Sltst Cgl oz. ,,·:~;:;:;.;~ti~:>~'%.'1t..~~!.i.)ï1~~1:.}~.~'~~"!1;t(¡~:~~~~.~'Ø·'·. . , ,<>« _JII':~I,~·"':.;,":-,.·f, hr Reci Displace well with new seawater polymer mud while drilling out 20' of new formation to 3708. Perform FIT to 12.5 ppg EMW. Continue drilling F/3708 T/6472 SV5 3838' MD, 3324' TVD, SV4 4247' MD, 3644' TVD. SV3 4534' MD. 3870' TVD, SV2 4743' MD, 4036' TVD SV1 5239' MD, 4430' TVD, UGNU 5682' MD, 4784' TVD i ~ l LO:~~~~~~~::~:~/;:~:~:~\O;~~;=:'~~~~M~~~~~~~~:::;~:;~.~:~~:;¡I~:::J =per"'I'Y- sun DR I LL IN G 5 e: A v I c: e: 5 Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 I Mudlogger's Morning Report ~\~'? ;.,' ,.oJ ,..~. ,~,,.:~: .;,,:,:¡' '~"~~:~J~ì~,.':,'~',";-":fiK.~:,,~' ,:1' ,'~~;" ,'r';':.:i:"~'''::~~~~~¡''\~\,i~~ ,~:\",.,.¡;;,:;,,1It1..,;~,,:¡~j \,¡.,.,t~I:¡ ',' ,".':,:. ",'- '. ~>'~ J ,:';,...~'/'\',~~ì:''',.~,:;~.....t,' <~'.~i~'~(:<\~~~'~;'¡ ',r.~' :'i~ ::"\I:~,'< :<.' '~" ¡;-.. .' .,.~ ..,'. ',"'t' ..: Current ··RO P 0 8 4/9/2003 8,629 2157 POOH Polya 1 Clump I '> Gas* \ ..",. Temp Out ';, >', .'<. .,' 24 hr Avg 24 hr Max Pump and Flow Data ft/hr 192 ft/hr ( 525 ft/hr @ 6870 ) Pump 1 112 spm DH flow gpm - units 150 u n it~ ( 1163 units @ 6673 ) Pump 2 113 spm Total flow 952 gpm Deg F ( 95 deg F @ 8629 ) Pump 3 spm AV @ DP 181 fpm Pump Pres 3040 psi AV @ DC 271 fpm .. - , ",;;" .''> 121 95 Mud Wt In Mud Wt Out Visc 55 secs API filt - PV 16 cP YI 22 Ibs/100ft2 9.15 ppg 9.15 ppg - - 4.5 ml HTHP Mud Wt at Max Gas _ ppg Gels---2- 1 ~I ~lbs/100ft2 pH 8,5 Sd ~ % , Bit No.: Wt On Bit: 4 x 13 556 \ TFA: 0.9410 -- Footage for Bit Run 4,943 . '"!iti",¡," ~"l___. 2 Type: RSX238HF-+9s Bit Size: 12 1/4 Jets: ~ x-23... o RPM: 141 Hrs. On Bit: 28.5 Total Revs on Bit: ,·':àt:'«~~_I(~B~Jr;':-J1m,l1J:ll!n ,m'll~l::~~', ,," I Trip Depth: Short Trip Depth Tight Spots: to O):Dl1rrr:1:l~,~ ."IN".._..4::iIJ",.Lf.]:..f PI t Current Lithology: Trip Gas: Short Trip Gas: Mud Cut: Mud Cut: to nf"""L-:1:r.,__.Jtf.h.!.L.,-= ppg Trip CI: ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft ";~~C-Q;";;¡;:W,-=_,_ ft ft to I ...,JIIJ ~.~ II r % % % % I iIIr ft ft ft ppg ppg ppg Connection Gas and Mud Cut ft units _ ppg ft units _ ppg ft units _ ppg units units units I Drilling Breaks Gas during Depth Drill Rate during before after before after to to to to ¡,¡JUl·' -"U··I'''\1''''." gn - . '. "¡:':::r-:nut , ,w~,..,,~,_ '....... %LCM w,..,m':::rrr::~,," - ft ft ft units units units ppg ppg ppg % Lithology Sst Sltst Cgl - - - - - - - - - - - - - - - - 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. Description of fillings: .,~~.:,." :~·:":"¥~fm··~~S~~_·~M~\f~~·.H~"~1A'iii$~·i'tt'~·~ltt;+:i;:!~::-~.,:.ri,~~~,~';;\"""~.'·r;':'" ,;,,~~. .;,;" :":,, .......,:,.~~, ~'j 24 hr Recé Drill F/6472 T/8629. Begin Pulling to shoe, Top Drive down for repairs. Schrader Bluff 7737' MD, 6383' TVD Colville 8404' MD, 7094' TVD ',!":\f..~\I~~;J·'·" .:,~:~~ : , Logging Engineer: Doug Wilson 1 Mark lindloff " 10000 units = 100% Gas In Air " (;." ,:':};t~i.i~W~§f,~~~~~~~~i~~~~~~~_~'t~*~:?~~~~~r:f.~,f~>~~~~ç~~~f::;~~~~~~F~~f~~~#.~ ' o A ILL N G seAVIc:es Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 9 4/10/2003 8,629 o Repair Top Drv Gavin / Clump " .~~~ ~~. ~ ,~ :1:" ~ .~~. ,~ .& ~'~~) ....j ,~: gpr-.~! v~- gpr-. f: fp r-. :;(: fpm .:~ spe......"y- sun Mudlogger's Morning Report .,," ',' '~-' '! ',;. ~ ~. . '. ,: ',.: ":. ;:, ~ ',' . ." :~.',~ 1~'" '''~'''''I'J'i~>~:~i~~~ " ',~:;:~i7~ ,.-;:t~.:;'t~'~;;.~'~','1-":~~.~ ~;.~;.,. '~:\'ii~~};~~I'~': ~ "i~-~~:'$~\'.\:: /r-;,;' '~~,', '~~~J ,-i;~~:::~Gt~_:'~:.:~i~::\:.~~':'::'~f:~,"~"~:-:':' l~·~'\'~.r,'~:',~<:~ :~. .'\-1' I I Gas" ~, Temp Out 86 ft/hr units Deg F 24 hr Avg fUhr ( unit~ ( ( 24 hr Max ftJhr @ units @ deg F @ Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi A V @ DC R.O,P. Current o :'I'Jx .:"'::"q,,~,,> :,I:··:·,,;¡:"~;:;;A;'j\,·?%t,:,,';';7t:;i1t~'1':<h";·~~.'l\ì;·'1t f::·,;t\1i\11Jb\·t\'?i;if\.1i?Wi');JjC:Y;µtf,{>,i~'<,*,'J¡'\Y1Þi:~¡~__~'PF;~,*P,,\1*S;T¥8kAJ%:,)#;:"*ì!'~~:'¡j¡¡}t;:¡¡~?"%~t._"';l0\1(~:'¡f¡.;t¡hMéiÞ,',w:;;',',+!::if';+t,:::{;(/,,·L'!:;,;;Ú;\,';·,·;'.·· ;:':' ~fJ :ct:' I Mud Wt In 920 ppg Vise 56 sees API fìlt ~ ml HTHP _ Mud Wt at Max Gas _ ppg , Mud Wt Out 9:20 ppg PV 17 cP YI 21 Ibs/1 00ft2 Gels~ 1 ~ 1 ~ Ibs/1 00ft2 pH 8.5 Sd 0.25 % .~. ;~,¡f,' ,.~.,,' f ',,:$~' Qt','í\((I¡j¡:; ¡)~'1\{ji@'~it1\·~r;;'\:Mtw"tì-~B¡,;·i,~,\:I',\~W1li~Pf'J:\¡s¡I~!j¡~m;~~~'Wf_~i_mtihf~fu"1:,1/t'è\\'\tit/îMN::'ß.\%.'h¡!¡.~¡åJ!jI'¡W;;%',~. ~;\~$\~~¡:! 'i;;A'.~,,;\',,~:\t't¿¡}<1I' "¡"';'%WJ~\(!'~ '0:"t~' ':'<:'~'1 Bit No.: 2 Type: RSX238HF-+is Bit Size: 12 114 Jets: 5 x 12 4 x 13 \ TF A: O. 941 O~. Wt On Bit: 0 RPM: 0 Hrs. On Bit: 28.5 Total Revs on Bit: 556 Footage for Bit Run 4,943 ~:;;;:;:"J4\~'L1:;I:]I:'::~~~=tìDJ,..&~,' Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm ~ Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm : Tight Spots: to to to Feet of Filion Bottom: ft ·~~:1·~u:r.r!r~:::::~~C'T.n -I (~~,,' I I I ~ Current Lithology: % % % % %LCM I Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks I I before Drill Rate during after before Gas during after % Lithology Sst Sltst Cgl Depth I to to to to " "'"¡:y I " ~V_. " "~"""'nf''":"", .\!'.\.,~ . 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. , ~'~. .' . :.$~,::\':' ;ê:~::·:,;'~~·~~r.:j,.,.\1!·~¡·¡.~~~t.~ì.,~!i:j!~~!\t!~m:1~!~y;~~'I!;~I#{~~~~~À\::f~.;:~~·¡;;~~r~¡;,~~____~~!'i···~:¡\i;·?.,f~,\'¡"8~~~Ä~~~~(¡'ii::iq¡~œ~ .;í 24 hr Recé Repair Top Drive, Rigged up G & I with pits and monitor. :11 Î '~ J ' ' ~~ i ),~ í \ ! Logging Engineer: Reg Wilson I Mark Lindloff . .' . 10000 units = 100% Gas In Air ~! -~:.:~:~~!~~~\~~~~~~8~~)~~~~~;~i~~~·.:;,~, ~ :~~"~~~~r~,~ Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 10 4/11/2003 8.629 o Repair Top Drv Gavin / Clump ,...~. ,p~~ +1 ù t~; ;~! I¡':I" ,',-;<': }~ ~~~ ( spe....,r'Y- sun CJAIL-LING SEAVlces ;~~.~ f~' ~:J'.i:: ~:'~ ; ,~~~~ 1 ::<' '~" .; '1>~":~' '::',\::~,,1 _-. ~~ .~~,;:i'<":I~· ~...'~·,-t\'~~~~Jt ,~~",~~,,::,!{:¡,, ~~!':,"'~:~f,')"';'': "~,~~ ';\<I,,~~,.;~· ,'!ir~)!':J::" ;; ~t )¿ I.'., gpm ~?, gpmf::' f¡ fpm >"'~ ~~~ fpm )~ ¡~ 'C,'., :..',\,;,··....,,;~A;},~",:c<.:\;,j,!l'í'.:,~~~¡;~i1;:'i:,Ù;¥P.;'{;':~"*¡~ffY,~:i_j;li!:~'*'\ì\¡¡#,¡Wij#$W,(¡,iI\H\~h~¡::-;;;;:r?>'¡\~:\',~\~'t;tt'~t*',~;t~'I"~c'f0i'à*,'¡,'J¡,'~~~itt)!í\:¡:fi<\;;M,Wl'l\"'*,.¡i.,~_,*,~"£\~\\!\~,þH~:k~·M";\;;;jAh(;~;,,>.;·,',"·:{¡if··,.,·' '\'Ì'~~ .~~~1,' 9.20 ppg Visc 56 secs API filt 4.6 ml HTHP Mud Wt at Max Gas ppg I,: 9.20 ppg PV 17 cP YI 21 Ibs/1 00ft2 Gel~ 8 / 11 / 14 Ibs/100ft2 pH 8.5 Sd 0.25 % Gas" Temp Out 86 ft/hr units Deg F 24 hr Avg ft/hr ( unit~ ( ( 24 hr Max ft/hr @ units @ deg F @ Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm A V @ DP psi AV @ DC I R.O.P. Current o I Mud Wt In Mud Wt Out ___ mi, ~"""-----------""";·¿t _' Bit No.: 2 Type: RSX238HF-+gs Bit Size: 121/4 Jets: 2- x..E-. ~ x.-2!.. _ \ _ TFA: 0.9410 'It"\ ~~4 Wt On Bit: 0 RPM: 0 Hrs. On Bit: 28.5 Total Revs on Bit: 556 Footage for Bit Run 4,943 ;. "_""~'t""'4,wi~_·'·"··.."'·"'·,_·,·,·~""~I··'_". '...K..~'I:'j'U·tIIl~~--'.....l1'·_"...·_'"··'"·~"'.."~I¡~I·lm¡II~_iI!in·T·1....'"".~-""~*""~, ' '"' ,. "',.,' '"," ,"''''. ".. :JY,rl-.-,-.....J,-,..-..~.'1I.,~~Mi:~..w..~'I\'I'I'."i..'I"i'\.\_m~~..,."f..r,:I!~a'.·"'~~.!Ø~Jr~.:t.IJ.., rJ'.~~.M~i!t~II..III.,I.1I .. ~~~~"~~. , ¡ ! ft Trip Gas: Mud Cut: ppg Trip CI: ppm ¡ ~ ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm ~ : to to Feet of Fill on Bottom: ft r ~II . ~.IL,J.,~... fm. ~illg II II 'r-::J.t~;- . Trip Depth: Short Trip Depth Tight Spots: to w "" ~I:,,~:lrxr::::tt~;l:[:~:J.":':.l...,~,II,~ Current Lithology: % % % % %LCM [ Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units -ppg I ft units ppg ft units ppg ft units ppg ! ~ ' Drilling Breaks ,.. I ~ Depth Drill Rate Gas % Lithology before during after before during after Sst Sltst Cgl to to to M::' to t- . ·w.' ".œ 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: ',~! "". :'h~;~i,~M:i:ï',"~¥1¡*~\¡\1~~~ . ~~~I"J.\'!!~a~~~lii\i:fl¡·:V:;~~;,;;::)'''i;' ;,1:'¡~;:1 ·;tï· 24 hr Rec; Repair Top Drive. .~~ :.;j ~Tr"., :J ,~ )~ :':~;~' :'1 Logging Engineer: Reg Wilson / Mark Lindloff * 10000 units = 100% Gas In Air ~:.ft~;~~~;"'~~~~~~·~~~J~~~~~~~~~I~~~I~ ",:. ~" ..;_.' '~'¿,:' .' Ifr·_,,~~~:",.', ~,~.......);l!J.~}...f'·.''::,~~,:..:~..~':l~'X,J'\~ !n:~~~";\~~»~~~~~~m~~~~;~~~}~¡QQ9l',~~~,~~~ß"¡"~\~ÿl,,J..~~r~~~4It;w~~~· :..:~. '." :i;,t ~,:(~.',.,.,:;(,:"";:",~;¡..',,,,,~: ~. ;. oz. sper-"'r'\j-sun DRiLLING SEAVIc:eS Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 11 4/12/2003 9,733 1104 Drilling Gavin 1 Clump ... ' ~,I. :~ ',,'~ . ;."'tì;{~Ji~~':"1:":~": ··'''':'.''"f...;'',~',. <:':"" r, >,-' _:~ :~'I:~ ~:'~'.,'/: ~....~' :~:;~~ ';¡;~;:;í~~~:-:~,~ .rt. ,,~,~~~ ~~~~~":;.I;~~::.~i~~ ~""~. -:.._'"::: ...':5 "';Î¡~¥~~':~ ~~'~~.~~i~~ì±;;'~M·l-{l~·,~~t~~'¥f:J~~~¥ :~~,~:'~: ;"',":~"~(i~'~~~~~_,:'~<~!~~~""~ ~~M~~:~~'~~~4'~~~'~":{~':'~~~:":¿~~~\:: ~~~:~~~..~~;':':~_ I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 117 ftIhr 138 ftIhr ( 387 ftIhr @ 8908 Pump 1 110 spm DH flow Gas* 152 units 142 unit~ ( 485 units @ 8771 Pump 2 110 spm Total flow 931 . Temp Out 104 Deg F ( 104 deg F @ 9620 Pump 3 spm AV @ DP 177 - Pump Pres 3120 psi AV @ DC 265 .....-- Mud Wt In Mud Wt Out 9.20 ppg 9.20 ppg Visc 58 secs API filt 3.5 ml HTHP Mud Wt at Max Gas PV 20 cP YI 29 Ibs/100ft2 Gel::~ 1 ~I ~ Ibs/100ft2 pH 8.3 Sd ppg o % ~. I Bit No.: Wt On Bit: Type: RPM: RSX238HF-+95 Bit Size: 121/4 Jets: ~ x.-E.. ~x ~ _ _ TFA: 0.9410 142 Hrs. On Bit: 37.5 Total Revs on Bit: 727 Footage for Bit Run 6,047 ,,:;J::~=:m:n';:.:::C:ml..:~,rJ\~~;:~~' "', ·,,~""~it;;um¡!~&iI&¡m¡~øl[IWn~i\n~l~m!'m.¡l_."lllti5[-1Q;?~_ I 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. ~ Description of fillings: tI }".,':,r:,'9..~~~.~~~~~~L.·.. .,.. ..,.,.., .... -',.: '" '~", "",.,~~Yii,~~.M¡tti~;jIirtW~_~~j\!¡~i'~¡::t~~i:":·":"~/';r~~, 124 hr Recé Complete Top Drive drive repair, RIH to shoeCirculate out 400 bbls of solids contaminated mud .' ,j~ from open hole annulus. Added 900 bbls of new GEM mud while circulating. Torq after dilution 21 K to 22K at 150 : ,'I,f~,t RPM on bottom. Drilling to 9420, troq running between 24-26 K. Add 1 % Torq-trim torq reduced to 23 to 24K. 'Î Currently running at 24.5K. Drill to 9733' MD. :Î .;:1 Still in the Colville. , ~~ ~ 1~.LOgging Engineer: ,Reg Wilson 1 Mark Lindloff * 10000 units = 100% Gas In AirJ ~\ ~ nj~~~_"'r'·~~"$~~;f,~¡~\iff:~~~~$'~:Œ"~.~"*".¡, 1?~,~.t¡\~~~.¡¡t;r:~~~~;;='~'I¡:,;~¿;;,¡~,t'~'~~?';';.í~1/tt.¡!~~1}t'!¥F;,~~~~Ví¡!i-W'~~"''I",,~:':'¡¡~''·, :.: f., '.~', ..... !'t~~-"f';~~~~~]';M·:"~~ 'Lllt" ~. . " ,.'¿. .....~" ~~" ~.~,,~~ß1,·~~m~.,.~ ~~~..t~::·.'~I'· 't.~~:~"~Jt~:~~~.~~/)j'~~~:". "'...ar,~~~ I!C "I.~ ..~t"lIl~~'.\I,;¡¡...-~~:~,O; ~ .~~-f,:~,!. ..', !~.''':'.if JU.{" . ~'1- \.' ~ ::.. . ....,... ~".,i . 2 17 I Trip Depth: Short Trip Depth Tight Spots: to . .."..1 .~: ~Ht"~t:m:l~~";'ItI:J":l\l[,,I, ft ft Trip Gas: Short Trip Gas: I Current Lithology: % , i ft ft ft units units units ppg ppg ppg f I Depth Drill Rate during before to to to to I I I to Mud Cut: ppg Trip CI: Mud Cut: ppg Short Trip CI: to Feet of Fill on Bottom: aIIIlW!f.u~.!,..';~::::~~~' % %LCM II [ ~C:-ctll,: % % .- ~:m.nn:,,~~ i~ Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks after Gas during after % Lithology Sst Sltst Cgl before ppm ppm ft sper'r'Y- sun a A I LL IN G 5 e A-V I c:: e 5 Customer: Well: Area: Leas e: Rig: Job No.: I Mudlogger's Morning Report BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 12 4/13/2003 11,414 1681 Drilling Gavin / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: - :.~~~: ~"':'':>~'.''''':\:~';:;:';' <,~~;,' '~. ";~~'¡,k\....~~\t.;.,~ ~'i.'!:¡, ~'~"'1""~'~'1"~,~-"; :,' 'I >,'-,~~ ":¡;~;.. J!'I,l :}~i"~<\'..,·:",. ~~;"~:~'~~.j.J~ ·t. ~¡'~~.J;)~N;:ri:;:q-~~;.\0.: Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 132 ft/hr 111 ft/hr ( 221 ftJh r @ 111 34 Pump 1 112 spm DH flow 226 units 621 unit~ ( 4545 units @ 11117 Pump 2 113 spm Total flow 952 104 Deg F ( 104 deg F @ 9620 Pump 3 spm AV @ DP 181 Pump Pres 3780 psi A V @ DC 271 .. I 10.05 ppg 10.05 ppg Vise 48 sees API filt PV 19 eP YI 30 Ibs/100ft2 --- I Mud Wt In Mud Wt Out 3,6 ml HTHP 11.6 Mud Wt at Max Gas ~ ppg Gels 12 1 17 1 20 Ibs/100ft2 pH 8.1 Sd 0 % I Bit No.: . Wt On Bit: 2 Type: RSX238HF-H;Js Bit Size: 12114 Jets: 2- x..E.. ~ x ~ _ \ _ TFA: 0.9410 18 RPM: 147 Hrs. On Bit: Total Revs on Bit: Footage for Bit Run 7,728 , tI¡~m~œ;;;tJ:.::rr::œç..~;';:;''J,;~mlT~:.mJU ì~ ,",Im~~' I Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to '.., -:::n:D.....;¡:~:.!1.~a:.11(JC]:;;·t In I I Current Lithology: % I Mud Cut: ppg Trip CI: Mud Cut: ppg Short Trip CI: to Feet of Fill on Bottom: r -. -·:x\t:U:;;i;;:£-DJr,~~r. 1 j ¡~.l';C::x,¡,;¡:r: 19000 ppm ppm ft % % %LCM % Connection Gas and Mud Cut 11100 ft 4545 units 8.8 ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks I I Depth Drill Rate during before I to to to to after Gas during after % Lithology Sst Sltst Cgl before ..·:;JIJ&iIJIH1 1)~mll~.:lwm::!!l,~~~J1j," 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. , .. J '".:: '.~"; J .- I:. 1,;r.4;.'i'~'.,,·l'r,~.i~, f"" '. :,',' ....;:I;".¡¡ r·· \liI';..r(¡:,,\I<\.~·;' ~",~!"",...r..t.:~\.~lt~¡;.~~·,,: t~.~'.i.II;~.Y';~ '!N$;';>·~;,~-\t.,~,~;1,. ;_~;1.:~JíI'l.t~~"i'.w+.i ."C,I.: .', . 24 hr Rec; Continue dnlllng F/9733 to 10200'. lost 50 bbls. increased mud weight to 10 0 PPQ.. hole took 30 bbls more ':,. mud at , 0350, continue drilling to 11414' md Back ground gas running ÕOO-700 units. Currently repairing J top drive. ~ '. HRZ 10767MO, 8786' TVD, KALUBLlK 10849' MD, 8850' TVD, KUPARUK 10899' MO, 8890' TVD KUPARUK C 11072' MD, 9028' TVD Logging Engineer: Reg Wilson 1 Mark lindloff * 10000 units = 100% Gas In Air '-";:-:~.':~'~·'f::\:rçl~~{f?~f·%~~4.r~~~~~~~~~_~~.~~~:-~*~~~~ ...: I I I I I I I I I r I sper--"r'V- sun D Ai LL I N G 5 e A v I c: e 5 Customer: Well: Area: Lease: Rig: Job No.: 13 4/14/2003 11.537 123 Wirelining Gavin / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Mudlogger's Morning Report ..:;~ 'j: ,",',' /';' ?..¢ :~\: ~J, L ': "",i"r~ )\~-.:' ~r~\/~'::;:;""":';: .>;~':, " : ,-',¡:',;'t:' ',/,~ ;.:~, ~: ·.~,~~I.~,1i}t~ /:~8 ./I~:,':;" ,~~~~~,,¡.,~~~,~ ~~:1}~~~::~?·.j::-·~}II·\1~,i~;~'~'~',' '~I~ ,.j(;,;~.¢:~~~i,,~ Current o o 130 24 hr Avg 24 hr Max Pump and Flow Data ftlhr 80 ftlhr ( 187 ftlhr @ 11437 Pump 1 0 spm DH flow units 241 unit~ ( 355 units @ 11425 Pump 2 0 spm Total flow 0 Deg F ( 130 deg F @ 11537 Pump 3 spm A V @ DP 0 Pump Pres 0 psi A V @ DC 0 R.O,P. Gas* Temp Out , ... , .. ,. . ,~.... '.t'-, . ,j..' ..'.';. "'\'·"L'~~'-:¡'..~·I'.:": "':".'t:,,··r::,,···t·;·..¡;,...,;·.·,....:· .... !",.,.,.-;:'.¡.' ··,.1:·_~.~~·~-:'i~.(..._~. '. ..... .",. ,.' ppg ,~ o % .~~! ,.'.~,;,;:',..:,' .~:,.- r .~. .' ~ : ¡)"!I:;~;\ ~n";·~-)~4~.:.:.""~~.~~~~~~ìr.~~~f¡;-~:~.:.:.~),(-ifé·~)~,4;~rLJI'Q:,,,,'~~.~~'(~·J·.,~~'I'\?\~~V~~~~~!,.:!..~~~~~~á·~~~~t!::;:~.::; ·,~~'.f3'~ri~~,~.:.;::;'t?·~'·"'~,~.¡~~I:~..~~~~:'j'~:~ "r·~,~.. >::", '_I ~ ,. '':".''./',' .~::',:~ ".~",:.- ~:--:::,':\.": ~\ .. '-:t.::...:,,~.~ ""..' ~ :~ ~:~~':Bit: 218::;~~~~~~~~~~ ¡ , 10915 to 10850 to to Feet of Fill on Bottom: ft j Mud Wt In Mud Wt Out 10.20 ppg 10.20 ppg Visc 48 secs AP I filt PV 18 cP YI 25 Ibs/100ft2 3.8 ml HTHP 11.6 Mud Wt at Max Gas Gels 12 1 16 1 20 Ibs/100ft2 pH 7.5 Sd --- Trip Depth: Short Trip Depth Tight Spots: " ,:J:3t:::r(C:::I::;:;:~'r m~LIL!IiUt[;.u¡fJ' 4. ."....,......"=::J:n.,,..."~....J,"..L. .w.. [ ~I.(f]]jI!:rI¡Vltt.J,ø:.::I:I~:·ll,!,,, Current Lithology: 25 % SLST %LCM 75 % SH % % Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units -ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks 1\ n ! Depth Drill Rate during after % Lithology Sst Sltst Cgl Gas during before after before to to to to , I , '"'"'1f~æ .....-.-".'j;¡' - .1.JfJ1U1:;;,:¡r.':"1Jß,[8~, "" ,::;:N,o>' l~' . , . 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. ¡ .~;." ,'. .','....'·'i!~,'y".~r:.~,·a~·&~~r3!.~i\:~'<t.~~~~:~~~:~;;~~¡¿¡I'~.P"\::·~.u:~/~t·/¡;':,·~:.·'!;;;,·t',? ¡ .'j.;.,~:' .: ',:-.~,'_ 24 hr Rec¡ Work on Top Drive. TO 12.25" section. Circulate and pump sweep. Top Drive failed. POOH' Spot Steal Seal across Scrader Bluff, Continue to POOH, Lay Down BHA#3, Rig up to run Wire line logs Miluveach 11488' MD, 9362' TVD, TO 11537' MD, 9402' TVD Logging Engineer: Reg Wilson 1 Mark lindloff * 10000 units = 100% Gas In Air ' : . "'., ,~'~~;\:!t,.~:~:ii~ro/%~~~~~~~_,,)¡,~~~i.;r.sr~i~~J~~~~i\~s~~\j·;~.~·:~~.;t:3~?f:~~~;i;J·~:t-~;ç> ;,:c ... ~,~~<r~'.· ,.: I , t' ?;'~'1iM~~'!~#è.'> BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 spe'-'r'v-sun Customer: Well: Area: Lease: Rig: Job No.: 14 4/18/2003 11,537 o Backream au t Gavin / Holt Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. na ft/hr 0 ft/hr ( ft/hr @ Pump 1 96 spm DH flow Gas· 56 units 100 unit~ ( 1269 units @ 3:35 Pump 2 96 spm Total flow 0 Temp Out 110 Deg F ( 110 deg F @ 11537 Pump 3 spm A V @ DP 101 Pump Pres 1800 psi AV @ DC 152 .. I I I I I [ I I I Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 10.70 ppg 10.70 ppg --- HTHP Mud Wt at Max Gas 9 1 16 1 19 Ibs/100ft2 pH 8.6 Sd ppg o % Bit No.: Wt On Bit: RSX238HF-+9S 147 Bit Size: 121/4 Jets: 5 x 12 4 x 13 \ TFA: 0.9410 ------ Hrs. On Bit: 57.9 Total Revs on Bit: 521 k Footage for Bit Run 7,851 ~~J¡¡i)1J_.:nHnUfm:.J.\_ltJt~U~~'·:J'œ¡;:,,~· Trip Depth: Short Trip Depth Tight Spots: 11537 to Mud Cut: Mud Cut: to ppg Trip CI: 19000 ppg Short Trip CI: Feet of Fill on Bottom: ft ft ft units units units OM i L.i.... I N G 5 e R v I c:: e 5 Mudlogger's Morning Report :..t~~\'",~ ~,:~. .1¡.',' !~ t',~ :,;,~~~~~·~v~,·~t ~t; ~f~~",¡~i1';\~l' ,~;..' ".~'~:,;.:', i~'1 :~~.ti~~ '~\":\\: ~~ .'~' ·'~\~~,~,~>;~~~,,~~tt~~··~'~·;':'.";.,i~<;:~'! ~'\'~>";,V(-:';:' -,~~, ,"¿;, ~};.':~~1 ,t~ ~ ~.~I ~J+:-~ ~~~"$:;O ":~~::rL~~:'~'\~'~~~:~~..;:~:~~,.;. '~'-/~.,·,'i'~e..:," .:'.. % Lithology Sst Sltst Cgl ppm ppm ft a}::~.]£CJJI:\t'ffl1.fh.,.~ \11ft TI,-n:~;."~!th~z:n=-::1=\\\:m ~If&~~: ~~l',umœ::=~.:::.:Œ:.Jr1: % %LCM ppg ppg ppg 'iil!I!i~r~Æ~ ïiEr~ .I¡: ~~~ ~:;-:':ul:tiOn of ~te~1 ~ilingS fro~ Possum Belly Magn;ts: ' ; .- ... ... ,. oz. " (,., Description of fillings: 1 ~ ;~c;;;~=~=~.?";""., t"r.t,~ 1 0950' +/-, Spotted 70 bbl pill (BaranexlBarotrol). Backream and pump out of hole. i , ~ ·1 Logging Engineer: Tom Mansfield / Reg Wilson · 10000 units = 100% Gas In Air ~ ~~~I·~:,~~;~~~Jt~~~7~f~7~~~~~~~W!8~~ª"(';~t1,.:1:i1~~!~)~¡~;~~i~"m~~~~1~~~~;~_~5~;I~ Mud Wt In Mud Wt Out Visc 50 sees API filt PV 19 cP YI 27 Ibs/100ft2 4,8 ml Gels 2 18 Type: RPM: ft Trip Gas: ft Short Trip Gas: 9850 to Current Lithology: % % % ft ft ft Connection Gas and Mud Cut ft units ppg ft units ppg ft un~s ppg units units units ppg ppg ppg Drilling Breaks Depth Drill Rate during after Gas during r> (' ! before after before to to to to ·"':S'f'\~.\:,i;;::::£;~l·~¡\'N·;"¡I:"·~'¡;~',~P;SIN~~~:.':',<~M'%"~~'~Nrm"ff,__" '~~' '~~' ,0~', ·'~~Y~;'¡.~~, ' ,,'., '":m4¡~'~,~~',·:· " .", ",II¡(,¡Þ'~"·'·~·.~.,.'Ji'(~i?~~";."",~r." ;~:f:::'.fi".:..\i:,\i' .. f".,.,·~·"~,·''''\i,'...",.):¢·'¡¡·,.. ·",.,~,"f·.~~'.1·,"..1"'.' ""~'¡"... ,"I:¡1X:.I,/i¡,_".~. ,'~',"''''''.... . "", .,'C:.)J...... ...'Ii':.,:".J.I, ,'I(.t."l'~\':."':.. . ," ',' '. F~~'¡-r c"!"'., ,''i1;~ ~~", '¡;',.1'<1~.¡;-, . "~""I.·*"-,.,J"",:'·,'¥ ",-ilr,~¡; ..~."..., " -"'. .-<,o:o.''iifI..... ....,..,.~. .... ,j. ·",.r--·.'f'i,,~'r'~·.,~,r_.~ .:!Ii........ ,:,...,~. '~"'~I" ,.~. '1"'~~\"~1'I .", 1 '.~, '. _",_, ~:,f.r~-:.. .'"..~_.,.ð·"~."'. ::"a.,:~,,, ~..:......,,, ,", oM.. '," * 1 0000 units = 1 00% Gas In Air ppg Trip CI: ppm ppg Short Trip CI: ppm Feet of Filion Bottom: ft -..urJ1"illll II 71:::IU::j_~.~ult~. \ TFA: -- Footage for Bit Run J ~!~ % Lithology Sst Sltst Cgl units units units %LCM Logging Engineer: Tom Mansfield / Reg Wilson POOH. Rig up and run 9 5/8" casing 24 hr Reci oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: to to to to after Gas during Depth after before I Drill Rate during before Drilling Breaks ft ft ft Connection Gas and Mud Cut ft _ units . ppg ft units ppg ft units ppg I ppg ppg ppg units units units ft ft ft I % % Current Lithology: I % % ..._~,.l,...,~_.w.u Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to i ~1.·~1t£:~~r··(I:::I:n:.~JLDJ¡;JN;'·~œ·]IJlI_-··J¡:[jJ-'lJiIl'lr::"'I![~][ I m I Mud Cut: Mud Cut: to Type: Bit Size: Jets: _ _ _ _ RPM: Hrs. On Bit: Total Revs on Bit: "mmx.:tJÐÆ~·]·'·~~!I!RULW~:::¡;;i'::::~LL;~ Bit No.: Wt On Bit: I --- I 10.70 ppg 10.70 ppg ppg o % 4.4 ml HTHP Mud Wt at Max Gas - - Gels 9 / 19 / 22 Ibs/100ft2 pH 8.5 Sd t"""\:.......\. .,.:,.. Visc 50 secs API filt PV 17 cP YI 29 Ibs/100ft2 Mud Wt In Mud Wt Out , '..-!..' 01 - t .. I ,".,ß ........, :':'~ ~..·":I· 'L"I''':~'~'' "po -.~'.1'~ " I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. na ft/hr ft/hr ( ft/hr @ ) Pump 1 spm DH flow gpm - Gas· na units unit~ ( units @ ) Pump 2 spm Total flow gpm - Temp Out Deg F ( deg F @ ) Pump 3 spm AV @ DP - fpm Pump Pres PSI A V @ DC fpm " '~:r,~ '!'i',~:J1,~'tt¡:Ä~';;~~'" ("JoJ"~' :;.', ,.:..~~~~~~,¡.: ,!,';~";~~ '~-:,..'., :,';,,:,. ',:\~"i~;~~'~'r~:~{:': :'r:< '(:"? \'\~~ . ;ì.: :J~;;; ..J:-, ~.~"';;) ",~':::~~:" ,:r:·:'¡:,,<~;l\:·? ,j ~;,~",,'~:~:;'~~;:',-i·~~,,;~,~.'>~,:,,:t~i~j::.,.~~;:,~,- ~~~~W}:;,,\~ ~~;;~':~" ''; '1,:'.'1', 15 4/19/2003 11,537 o Run Casing Gavin / Holt Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Mudlogger's Morning Report BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Customer: Well: Area: Lease: Rig: Job No.: 5pe~""'V-5un DRILLI NG SEAVIc::es I spe....,....,v- sun . , '. ~.~~!:Ì',/- Customer: Well: Area: Lease: Rig: Job No.: down squeeze ann. Gavin / Holt 16 4/20/2003 11.537 o Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: DAILi....ING seRVIc:es BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Mudlogger's Morning Report ¡~,';' ~';~~:, ,,'t,;q\\.; .;;~~.:Ù L '1,:.'~' ..' I"' ~;,. '.:¡. :' ::~j"':' .",".' ." ."~~~<,,~,:;.,~-t~'.,,,,~'~'I.~>~"";~\¡\'k'~\;,. :,;;'~~1;~"):;'·';¡'~~(~~:',~,,x~,',~~i~~.~·':A~;;~j~~ ¡;;:';",(~f:,~" "~":'-:':~~~-~;·f,~,:·~:",\,":af~5.~·.~~":&;:;;ç~it.~~.¡,,J~i~;·~:,J.~: ."; .~.~ ~~~,',~:Ç;:~ì";,',~~~·~:,~;~~~;r.s :':;:;~._:~'~:; <':.:\":~~1:;'~t:~·,.'.~:~~:~~'.:;·;:S."~;'; .:';, .~ I Current 24 hr Avg 24 hr Max Pump and Flow Data na ft/hr ft/hr ( ft/hr @ Pump 1 spm DH flow na units unit~ ( 710 units @ cmt csg Pump 2 spm Total flow Deg F ( deg F @ Pump 3 spm A V @ DP I Pump Pres psi AV @ DC Mud Wt In Mud Wt Out Visc 47 secs API filt PV 16 cP YI 24 Ibs/100ft2 4.4 ml Gels HTHP Mud Wt at Max Gas 9 / 12 / 14 Ibs/100ft2 pH 8.6 Sd 10.60 ppg 10.60 ppg --- ;~ l-" ,",~' ,~",.~,~.'..~~·;~"~"'.':':~''''~?'~-::~.i~:,"1_'¡¡:~f,{;\.,;.q,~~,~r.~~'('~':·~'~'~'~{.,'~~~'''':~'~1*~'~~)-~~':'~~~''t :::"..~~~·~~3:~U¡i~$.~~:.~i;;,'i:,~~_·'r-:d:~,~~:~:.~~~.:....Ì';<,"t;~.~.;.¡,~t"~"';¡,ÍfjJ~'?'~~~~'~;'~~":.·".~-";';'~'~~f~·~~ ~w-;,i J'r~: :,".L' ".,~,_ ..-,~. ',~,: ."', ''"': '^!..,~. ..;J~" :.:..:;.....~~ ... I "'/' ~....., "'"¡'"'IIIiY/(' : 'I > , % %LCM - "-'._.:1,~:~i'.. ft units ppg ft units ppg ft units ppg % Lithology after Sst Sltst Cgl - - - - - - - - - - - - - - - - " . , "'~ ", - " oz. " I Bit No.: Wt On Bit: \ TFA: --- Footage for Bit Run Type: Bit Size: Jets: _ _ _ RPM: Hrs. On Bit: Total Revs on Bit: "~:'òr!;::~;DS~tt'.~·nIUUillllllll l-Wf.r~-'::;JIl[.:c.t::[1(ltlt!U_m.',..J:'::'1!r,[lt,: I Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to -n::.:J.CI...J:~·:frm=;~&I:'M . Mud Cut: Mud Cut: to UI~~-JtU:]r:JI11t1lJr I ~ ~~ ~ ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: Current Lithology: % % % ~ " I Connection Gas and Mud Cut ~ ft units ppg ft units ppg - ft units ppg ft units ppg - I ft units ppg ft units ppg - Drilling Breaks Depth Drill Rate Gas before during after before during to to to to . '~N,lll~;;ø,-" . '->'~l' '~~~ìm'¡¡'- ~.' ~~J.,.~tf~~4ß1I'~tlIl~y,. . .:t~.{' r-¡\,' .. .... - .:rwr[]l~-~ ,..),.;~...,,,,....o\..",~;~~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: ppg o % , ppm ppm ft _ 24 hr Rec; Finished running and landing 9 5/8" casing to 11,516'. Cemented casing with max gas 710 units. Set and tested pack off. Performed down squeeze on 9 5/8" X 13 3/8" annulus. .',~~ ~;\~i'J.'3fili~~Æ¡'t.wt~~..~N.f'~':{~~::;r'"~~~~~~\\~¡.r,~~~~~~~o.i.~"~~.!t.M~~~_~~~,:;"' ," . . ,~".,.~:~,,',,,_,;t'i;:~"¡;'::';';I/:.:.~:¡r~;-r.~" ".-;:"t~:;4 ì\..J. Logging Engineer: Tom Mansfield / Reg Wilson "~:~,;~¡;~}·;f;~~~~~~~9~"~i~i£\~,,;; . ,~.' > ,..,..' ' ~ * 10000 units = 100% Gas In A;J.r :t~ , ":f~," . ',', !:._~~,~, ~, . ....r' I 'St:1' ~ ' . ~ I" " I.. "" , J. ' ';t'lì~I·J6~CI"~ ·f{ , ~ ~'I\~t:'~/f,~{jw_' < . ij ",",,¡ sper'r'Y-5un Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: OR I Lt.-I N G 5 E R V I c= E 5 r Mudlogger's Morning Report :,¡ '.:',:.' ,',<.'~," '-~': ~,,,·,~·,~\;,.;)3',¡·,'·~ ~~:,:".'~.'>'.\ :",~.' ~~, r";:; ",:.~ ':~'1]~~~i~:':f'~':,~,:J ,;;-~:,:t~f~;:.~::i:?:,:~~*Y\''';wk~·~~ri,('~>t'J.'\ 't":~~~. ~,~,~: Current R.O,P. na Gas" na Temp Out 24 hr Avg fUhr ( unit~ ( ( 24 hr Max fUhr @ units @ deg F @ 17 4/21/2003 11,537 o RIH, SLIP & CUT Dinger / Holt Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm A V @ DP psi AV @ DC fUhr units Deg F I ~ .'~. I ·t-r't.~.·:..:.·~"';~"· .", ,_ :/1 :'- ~~~~'.. ~ ._.I."",~]IJ';It. ,'! ':,,..:......'.1,,. ·.r'~.·.,.fl "\r. .. ,. r"."'./ ~ ··~..l~:III-· '''':':.·p,··..''-IJo..~~-..'.:\'''·:w:"..~,.~...!~I'''.·~. ':lot, ,. ,I~' ".." . I Mud VVt In Mud Wt Out Visc 49 secs API filt PV 15 cP YI 22 Ibs/100ft2 10.60 ppg 10,60 ppg --- ~.5 ml HTHP 12.4 Mud Wt at t'v1ax Gas Gels 8 / 14 1 0 Ibs/100ft2 pH 8.5 Sd ~ . ..~~ ,~~.. "" "1,: '".. - "L:·~I,.t.,.~~ 1_·~;r-;:,.·~·~~wt\~.-;..·f'\'t~~.~i~~t·~~~ir.',;~~-:,~~~c4~.......:.;;.~·".)~f.:o',~~.,~.:;;!:~'?i,1',,;~~~·~~.....if~Itþ-:f.·~;g:i~~,~ ~..~it':'>: ~:;~f~f'~~f'I..;.?: ~.~:~~¡;\ :~:~..'..~~.:: '~~f ~~.~.,'f"~"~~¡"«:,;'¡;;-d;':;,~)~~,·:5:·; .,':'~.!,,~~.~-" ::-' ~.",' ~.';'. ,'f ..." ~" gpm gpm fpm fpm ppg o % . '. ' ". ,.-~ ' I Bit No.: Wt On Bit: 3 Type: DS70FNPV Bit Size: 8 112 Jets: ~ x....:!!. -2- x ~ _ \ _ TF A: 0.7390 NA RPM: NA Hrs. On Bit: 0.0 Total Revs on Bit: 0 Footage for Bit Run 0 J.::::::il(;!~ìt1.:X:v:m\~~~:-=rm::~:t:~J;;~:rJ.;,:c:,;;:~;G~ ' Mud Cut: ppg Trip CI: Mud Cut: ppg Short Trip CI: to Feet of Fill on Bottom: ...~.oo,1~:aL~:I=- í ! !IIJJ~LJ::1f~:::JI:: I Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to ,~::;Q'~mI¡1U;ac::·:L"'Z'···..l-~¡¡{~nL~ì[I·~I'-::IW'·C [lOr Current Lithology: % % _·:·::.~^::.:x. : HlU ~ 1 10 1 'u m n-' UIL__.l.IJ~JI.llf1Jln II ~ ß wm Iii] ItIC._Wt] -1 % % -...UI:I"~:':::;:¡:" %LCM I ppg ppg ppg Connection Gas and Mud Cut . ft units ppg ft un"s ppg ft units _ ppg ft ft ft units units units I Drilling Breaks I Drill Rate during Depth Gas during before after before after to to to to "C _. ""'\If,..1 - 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: ft ft ft units units units ppm ppm ft ppg ppg ppg % Lithology Sst 81tst Cgl oz. )};,"". ,; ..... ".'~":':'Ir.:'::~Íj>; ·.~·..;~~!:m'J't.¢.¡.~;;.;.~;A:¿}:I;J;~~'P.~~:\1t¿~."c~~:;:~'''' '.;, ,,,,;¡,;.¡,·l~at\~~..'!i;~~i~',:..·<~·,,,, ;.,; "',' '."'t ,'.-,....,."., ...:tt.1S1 : ,~ 24 hr R~'Cí ",. '" T~sted·BÒP·s'.' pi~k~d ~p BHÅ ~nd tested Mw6. 'R'IH' t~ ;·1329'.' Slip and c~t d'rill ii~~'.' ",. .'. ~1 t ,. ~~ ~ri i ~ I ..~ Logging Engineer: Tom Mansfield / Reg Wilson * 10000 units = 100% Gas In Air :¡~. ·"\~"7:¡,;;:·:.~tJ:~i~~$~4~~~lf~~~~.;"¡~f~·~~2;;~~~~,~~~~~~~~~:~~~~~J~'~\~f}!i1~;:.~:~~~"')·~ . .' 5pe~r'V-5un DRILLING SERVIces Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Mudlogger's Morning Report BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 ". ;.\, ..:: jIo.~"~",,:,~~~ì',,...:~; 18 4/22/2003 11,841 304 Drilling Dinger / Holt Current 24 hr Avg 24 hr Max Pump and Flow Data '. R.O.P. 65 ftfhr 39.4 ftlhr ( 144 ftlhr @ 11699 Pump 1 96 spm DH flow Gas* 250 units 180 unit~ ( 295 units @ 0:00 Pump 2 96 spm Total flow 611 Temp Out 85 Deg F ( deg F @ Pump 3 spm AV @ DP 313 Pump Pres 3350 psi AV @ DC 549 .. I 12.60 ppg 12.60 ppg Vise 50 sees API filt PV 21 cP YI 24 Ibs/100ft2 5.2 ml HTHP 14,2 Mud Wt at Max Gas ~ppg Gel!:~ / ~/ 21 Ibs/100ft2 pH 9.6 Sd 0 % ~"·':c:~::~,:~;:,;:¡'~·,~·~~.:<~~?~~:~t,":,~;~t,~~\\\~;::-j;f."~",:\'.,}~:~;~:,:~/r;;~~~·:Ù:,:,þ'~;:~\\~:·~;:;~:~~~P!·$\.~;1.~:~~Þ1t:f.~~t~JM~tf;~.wY~~~~-;\~~~:.~~~'1'~~~·h~;~~·~~·~~~v~ö~~{j~tÄ~A~*"·:~~:~'Hn:~~;.~¥ifi.;i\~"ia~t.w.f.~~~~""*J~~~~~~~~~~i~1-Qg4~~',:~¡~~\1:f'~~~,·';~·,·~:.~:;~.~~!j:~~f~:·t~\:ì: Mud Wt In Mud Wt Out I .~.,..- ~ "!..~,~", .'1~'" -"..'-1:. . 0",' .~'f,.,~~:.... ." :.·...,'...~,..fort·,· '¿If.";". - '-. ~.~. '.~., .lj.,~ .,.:.....~ l'I" ...,~.... . ,......,... ," .~,. =-.7 . ·r., ..". I . Bit No.: 3 Type: DS70FNPV Bit Size: 8 1/2 Jets: ~ x ~ ~ x ~ Wt On Bit: 20 RPM: 120 Hrs. On Bit: 7.7 Total Revs on Bit: 99K '" ___a~ll~l~m.ms=:';~:~=.ïD.U::r""1 ,.]¡~IB',1[··E::;::,:J:::;:r~~m:""" \ TFA: -- Footage for Bit Run 0.7390 304 .1,... ppg Trip CI: ppm ppg Short Trip CI: ppm < Feet of Fill on Bottom: ft I' illt J1!Q..::'U[]],;~j \ ¡ % %LCM I![{]ßßI r:rH¡¡l;::':i.U~.:J:r.( , I Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: ! Tight Spots: to to . ·),~~¡;'JA::L~.C\Ji;;;;;;:JI:X:A::'::;;l'~r,.,!:^__. Mud Cut: Mud Cut: to ,,"~,œ-'~';;;¡;-(JrJ= I % % % -- II II rmlllll" Ul_ ~ Current Lithology: 11m m rrm.lllr 11 ~"7111 1 _ mu ~, ~II! Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft ( ft ft ft units units units ppg ppg ppg I units units units ppg ppg ppg Drilling Breaks I Drill Rate during Depth Gas during after before before after "J I to to to to % Lithology Sst 51tst Cgl ~ ! Iii' ~ ji~!!~3!1ta;~~~_lmml~llr~lIílllllili~ìI'~~)~I_ f , 24 hour accumulation of Steel Filings from Possum Belly Magnets: Approx 2.5 Ibs. Description of fillings: Slivers, curley cues, small chunks. Beginning to decrease now that BHA is out of casing. ,:'~,1'''';:[::·;','ô*;';i<¡~\Î'?~."iI~1i,~-r_~~~'~~.a1~~~~~~K1!m~$.~~:~,,;i,'~~('f~),::',·' :124 hr Reci Wash to float collar. Test casing to 4600 psi. for 30 minutes. Start drilling on float equipment and bleed . ~~i in spike fluid to raise weight to 12.6 ppg. Drill 20' of new hole and perform FIT to 14.4 ppg. Start drilling new hole. ·.ì:~,~dv.fr Î{ I I Logging Engineer: Tom Mansfield I Reg Wilson .. · 10000 units'" 100% Gas In Air . """,,,r-':'¡":"'."""'~""r,-,v,,v':,,,,,,t '·"'¡'::"/j;o'~!';i'I!IIJ¡'i!"A~. "'::lt~~l:)!'"~~\\'f.¡¡f¡~~~~1:m;¡"~;!i<l!1.."Iö1'iII>.~~,.$1f..-u'W¡¡~r,~¡.~'.''''<''··¿'¡'\:¡.~"';(::'-... ".,....., ..'\ ,...' . . .,,~~~t \~,I,;·,...,'",.,~ ·'I·:';·~':;::~ ,'. !~,:;.., ',~\;~~~.1~,~.t~:7 :I~.}.i,.~'r.~):¡:$:)~.~~~ ~;;-~\I~}~';o-~r¡.~,~!Jli~,~~~~y~~I~~~'":~~!~«~~~~.~r;~~~.t~~~1~~~~~~~~\~~éq'..~~',o-~·~~~/~, ,·~~·.'~~C~~r!¡J"·· I I I I I I I I I I ':,: ·\~.~"Þ4~ :!,,~,;:,~::~,:::':;':~ ;\(~:~~~1.ç~f ,~I' 5pe....,....,y- sun CJAiLLING seFlVIc:es Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 19 4/23/2003 12.696 855 Drilling Polya / Holt Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P, 40 ft/hr 60,1 ft/hr ( 196 ft/hr @ 12499 Pump 1 85 spm DH flow Gas* 145 units 160 unit~ ( 218 units @ 12426 Pump 2 87 spm Total flow 611 Temp Out 120 Deg F ( 120 deg F @ 12626 Pump 3 spm AV @ DP 120 Pump Pres 3600 psi A V @ DC 286 .. I: \ ,~ ~ ;',~, ~~, .~; :1, (:"'~ <..':".,";'~ ~~~~~"~ ~:,~,~,,;,.~. ";,., ,~.... '1"'Ä~1,f:"::'" ,~.~, ,~~~.~~~~~~'.:;~'("t~ ,~~:·D';·{j~~·~\~ift,.~" ':~ .,. '. -t ~; f' : ~,~,,.."f,~~;,~;Z~·:~;i;.. ~..:;"~L\,mis· ··¥.r;~\~·F>~'i~\ ~~t';'ì,t~f~...:~·:i\\:/(\.~...(, '_(~'il'";.~. <>., ~'~~' .:<...'~; _'~\(,: ~ ~,': .~';.~':~ J:- ',~~~:. :.~~,~'t." :"""~: '1~~W~~\~:";;,,~~;:~~ft;~~·,~~;~:,,:~:~~, ~~ ¡~! i~~ KINGAK @ 12135' MD, 9889' TVD (,~ .~ Logging Engineer: Tom Mansfield / Reg Wilson .,r .:~''''~'''''.~,''''~f.:.,'~ ~.;;:'.",.j. ~'."'.'" ~._j':~ ~".... .'";'H~ ',; ......." ..I:.'-~, ).·~'-r.·,~n~·. ,r~..' ''¡'',~'1.';::'?, ,+~DS!'::~T·,;,,~',·· ~'(.. ,.....r~,~, ~:J~>f'....~t:-<~~~~~f'ifi~.~e,~"Ø.:~~:,,.~1'V~ì(t:-.r,..~'"".,.'.~~,~,~: ~~~...«'~.. :... ~,-':'·'\'~"";'.'::·:.."i· "'" .~,~";'"'.f.~.·.'~':,(l,·~~.~r,· gpm 't: gpm ~;;. fpm ~~~ fp m :\:1: , ~~:Ú ~ ,~ Mud Wt In 12.60 ppg Vise 48 sees API filt 4.4 ml HTHP 12.8 Mud Wt at Max Gas ~ ppg ~:; Mud Wt Out 12.60 ppg PV 23 cP YI 23 Ibs/100ft2 Gel~ 8 / 26 / 36 Ibs/100ft2 pH 9.0 Sd 0 % ~t"J . . ,". '. '" ...."",'<, ,.~"U."" ;.' ''''.''''''''''~' . ,~,."".,.."...,>~""_._,..,..",.",._,,,,>w=,';::;::: "":::~"""è'" ;."""""""''''''; "" ..,'..., '.. .' 'C". ",.;, ',',- ..'"" ú .,.......' .. ~ ~: ~~:Bit: 3 20 TY~~M: DS~~~PV Hrs. ~~ ~~~: ~~/~ ~~::I Rev: o~ Bi::3 3~7~ ~ Footag~ for Bi~:~ 0/13:~ I TriPDePth:~~~:-~~:cut: ppg TripCI: ". ...~ 1 Short Trip Depth 11879 ft Short Trip Gas: 375 Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft ~'E~l,"":,,;'-;-·[,,:'!1n:V':IJr::1:rrJ.lœJfUl,l U1lJ~n::::lJI ¡If Ir'r:~¡ I] :~-I"nIlJ"';:'=J..:fCUn::cr'==:::J"·"" 30 % Sltst % .",~:D.rtI:1i._'-::::r:lR::::- %LCM Current Lithology: 70 % Sh ppg ppg ppg Mudlogger's Morning Report BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 units units units % Lithology Sst Sltst Cgl m;.'I;'I"'~ ,-."~ ~,f I, ",' ... J.'" . ,!M;1 , '., ~:Sì1rtB"&_.·" ....., . , . (tI ,.1, ¡ 24 hour accumulation of Steel Filings from Possum Belly Magnets: Approx 3.2 Ibs. Description of fillings: Slivers, curley cues, small chunks. Beginning to decrease now that BHA is out of casing. :'~~'''~~:ì~,; '~~'t_~.~~~~"!~~~~:*l.V~':"';;"·';»';~f.: :?:: 24 hr Recé Drilled to 11879', short trip to shoe to work on top drive. RIH and drill ahead. i % ft units ft units ft units -," - - ~ ¡ Depth to to to to Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg :J.ï1" h ft ft ft ppg ppg ppg Drilling Breaks Drill Rate during Gas during after before before after .. 10000 units = 100% Gas In Air .:: '::·;':~;~;:~},è~~~?{~~::1.~~~}~r.~;~~?:~~tt~~'t~~~M~t~~_d~~~~~;t;~~>\~;~~'~~,:~~:~~:ti:i!~"!r~:~ß:):;~\~,\~.,·~~~,\::.f~':" . '. ~ .: '¡;: ~ ~.. , .. ", I spe..........v- sun Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 DRILLING SERVIC::ES I Mudlogger's Morning Report .~: 7'~":-,; ~~,,"'. ;;,;;'. <., ,;", ,',l~~,,~~' ';:"~:'~'''Y''~~~;~~~~:~'r'~l~~:~~~''~~~~~'''~~~~~'~~::'~~'~~~:~r9~~~:~f~$n~f1Üt~::à~*\,,"~~~,~t~~:t~~~;,~:~,)2~~,'1ì8ì".f~,~~.~~¡:~:i'ff.·:~~~_)t~~~)<,':,.:.~~Æ¥:~:"~',~~~f:\t/:~~~\~,"V~~f~:fi~'~~'..;\.,;(" 20 4/24/2003 13.461 765 RI H from Shoe Polya 1 Holt Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ft/hr 37,8 ft/hr ( 160 ft/hr @ 13460 Pump 1 spm DH flow units 210 unit~ ( 250 units @ 13222 Pump 2 spm Total flow 120 Deg F ( 125 deg F @ 13076 Pump 3 spm AV @ DP Pump Pres psi A V @ DC I 12.60 ppg 12.60 ppg Visc ~ secs API filt ~ ml HTHP 13.0 Mud Wt at Max Gas ~ ppg PV 31 cP YI 27 Ibs/100ft2 Gel~~ 1 ~I ~lbs/100ft2 pH 9.0 Sd 0 ~ ': 0/0 ~,~:~? .,' ~~IiI.: ~ ,'. :,c·",;,;>?~·'1i!'''.'f';-·i;7;"~:1:'·{~~S:i;,%¡::'''¡;;;'''; '..·.'::';'+\I,,;;"t*;,;,\·ë?~6'~f;,j'~m~wmm~,;¡.¡f.:.~·¡~tM/t;i"~~'¡;¡¡:;W'Ì~,¡¡'~~~¿~:WH*lfi;i'*¡¡;Ö~iF~Ii$R¥J..WM!;i'l!.Kf~',¡¡;,'ß~\ì1¡¡.~:;b;i,Ù,~~jJ:Ii'$',»;~þ;;(~i;~,,'<I;;,~'¿.):S~!r.,,;,",(';;;>,.;··,,····' I Mud Wt In Mud Wt Out "" , "..,..., ~.~ ",:.1',e,~ ~l""'· :..;, \':?".' .::r,.,~~·;,~:){I;·'!;¡,'.t;;.t.~ó~f;·.~~~.\'··':' ·;::;'.~~I,:;;¡w¡¡«'';.\i\í.¡~t'::'J#;:.;t<:·~'j:$.>.,W,':'' ·~W..;'~:.J¡:"''-P;:1i \iê;;;"''':'c:~¡.».~:t$::·;~:~¡''W~~7ìIJ'';~,~¡,·'!.~ ,\~,~;·"V};;'.N,,,"';7-; ..ctJ:í· "~~;M:";';,;,.,,:.,!" ," . ~. >'~ I . ..J. 3 Type: DS70FNPV Bit Size: 8 1/2 Jets: 4 x 13 2 x 12 \ TFA: 0.7390 ,h 20 RPM: 120 Hrs. On Bit: 39.4 Total R~n Bit: 580K - Footage for Bit Run 1 ,924 ~ Œ:t11œ1[;u.;tt:,at~Wc;t:[:CUj~JWJ\~tù:,J.~=r.i~~.~Û.':m,\I·.BJW_:m~m~~ , ~ ppm <, ppm ft I ::;: Bit No,: Wt On Bit: I Trip Depth: ft Trip Gas: Short Trip Depth 13461 ft Short Trip Gas: Tight""Spots: 12810 to 12620 12130 to r"¡};;~~::C=~{':(~u;.t.",_"......":;;;::.r: ~ shoe Mud Cut: ppg Trip CI: Mud Cut: ppg Short Trip CI: to Feet of Fill on Bottom: .Juwn, j ~Im mmn1ß'J',,' Kmtll. I i ]I LJCr:mr::::lL % % % % Current Lithology: . ~:n:::~~ [ ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft units units units Drilling Breaks I Drill Rate during Depth Gas during before after before after to to to to ft ft ft units units units %LCM ppg ppg ppg % Lithology Sst Sltst Cgl 24 hour accumulation of Steel Filings from Possum Belly Magnets: 1.5 Ibs. t 'l~' Description of fillings: Slivers, curley cues, small chunks. . ;!~:. /'... .,.... ,,~ ...!,,:, .,', ..' ',' ',,~ '. " . '. ,.. ';'., .'. .,. . fI\""",'''' . ". ..... """~"" '~ f,~~·..·.·,··',¡~1\:~.í~\N'f"",('i.~·¡~iI~,.~~~iI&~¡~~~_~~~~~"\!(..:§ffil'fli$l,~ l~ ...;..."...,,'~..:.:., 24 hr ReCi Drilled to 13461' MD, 10982' TVD. Lost returns. Pulled to shoe and established full circulation up to ,",' ~,. }~~ 7 bbls/min. Start to RIH to bottom. . ; 1¡f~ ':f~~~~ ,. '~f:~ ~ ,I KINGAK @ 12135' MD. 9889' TVD, SAG 13438' MD, 10962' TVD U Î Logging Engineer: Tom Mansfield I Reg Wilson · 10000 units = 100% Gas in Air J ::.~: ·',,·:·.:X~~,<~f'::':;>~'f';~~;?~;::'~/:~:~'f.~~W:~:~~~;'~_~~~.:'%;~:f.~~0r~~~~.~~. sper'r'Y-5un Customer: Well: Area: Lease: Rig: Job No.: DR i LL I N G 5 e A v I c: e 5 r Mudlogger's Morning Report BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Current 24 hr Avg 24 hr Max R.O.P. ft/hr ft/hr ( ftihr @ ; Gas* units unit~ ( units @ Temp Out Deg F ( d~F@ Mud Wt In Mud Wt Out 12.60 ppg 12.60 ppg Visc 53 secs API flit PV 27 cP YI 28 Ibs/100ft2 --- 5.6 ml HTHP 13.0 Mud Wt at Max Gas ~ ppg Gels 10 / 40 / 54 Ibs/100ft2 pH 8.5 Sd 0 21 4/25/2003 13.461 o Run 7" Liner Polya / Holt Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm A V @ DP psi A V @ DC gpm ::~': gpm? fpm:,: fp mZ' '~:-:7< ,~~~: .-~'~',:. '?,-:~ 0/0 ~fj: 1 d l¡ r~ .;!;';:;";,:Y;@!M1SJi®ÄttiÞMMìjì~4\ijÔ/~~~~:¡wtWN~~.\ii&,Wf¡W~.¥'01!*$W$;¡M1Ù%t'\fÄÍMr*¡j¥t..~~~Wi.¡!!\t.\\*~M~m.mhWfi1Wi\t¥Si*~ÄKt¡WiHî\*W44@#_ß:ii'r¡m;¡;¡'\~:1rWM0,;¡¡!W\\i¡t;t¡\%\'@W!i%:èWN*t<i¡Y0@\~%'tuii¡rl;\~w",' I Bit No.: Wt On Bit: 3 20 Type: DS70FNPV Bit Size: 81/2 Jets: 4 x 13 2 x 12 \ TFA: 0.7390 ------ RPM: 120 Hrs. On Bit: 39.4 Total Revs on Bit: 580K Footage for Bit Run 1,924 , ¡r,nœt".:a'.r::~=CC" I ~Lillllll..~X:1r~n:'[". . Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: 13461 ft Short Trip Gas: 12810 to 12620 12130 to T~-.::·_·nt:.::JIU[:r::]J;· Current Lithology: ~~ 1UIIIIHI11111ir 4- % % [I ti 1:1 [ JlIlImlllf I ~. I I ft ft ft units units units ppg ppg ppg 68 shoe Mud Cut: Mud Cut: to 11.1 .,. ,,~~':I:¡::~:,jTI ppg Trip CI: ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft .~::I[crm:::œ:Jm't;,u::!::JC:M]·-· . - % % %LCM ~.IU IIIllflLnl"::Iu__,"..rac~U::=,:m,;:;;¡r, , Drilling Breaks after Gas during after Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft units units units ppg ppg ppg Depth Drill Rate during before to to to to before % Lithology Sst Sltst Cgl , ~ þ1{ _~y¡)][lllll~~~1~ai'::BtIrd...{];~.I¡ðI[~_m_~ ! 24 hour accumulation of Steel Fiiings from Possum Belly Magnets: 1.5 100. ~ Description of fillings: Slivers, curley cues, small chunks. I ,;~'It.t\~,·::;'\t~~~~i(,.\'$:'!'~~~~·' ·;~~~\t~~~-1~~&1':'iiik'Ø'-:.:\' ":r!';íi:~dl,. ~: 24 hr Reci RIH from shoe. Hole tight. Spot 25 bbl LCM pill. POOH. Tight, after 50' pump out to shoe at 2.5-3.5 -r~ ~J' bbl/min rate. Cire. bottoms up at shoe. No losses observed while tripping or circulating. POOH. UD HWDP & _I BHA. Rig up and start running 7" liner. I ~ <~~ Logging Engineer: Tom Mansfield / Reg Wilson * 10000 units = 100% Gas In Air ~ ~ , , ' ~ ':1' -~·~··':'~:·:~~~:~~~:!J\~~r:~~~~~~~~t~_~'r~~~"~~:;ft;t;~~;(~~i;~M~~i.:.:~::~:.~1~k~:·;~'~~~"~j;~~\:::~~'/~~~'i~ I ,. f 1 f ", :......:..~, ~ ·~.~;~~~~~~::~12~t~;'~r.;,:\,'~,:.> " 22 4/26/2003 13,461 o Wash down liner Polya / Holt ~~ :i'i .-:,(, " J~~ ~ :'f~i, 5pe....,~V-5un DR I LLI N G 5 EAV I c: E 5 Customer: Well: Area: lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Current 24 hr Max ftlhr @ units @ deg F @ Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data 24 spm DH flow spm Total flow spm AV @ DP 465 psi AV @ DC 85 44 77 \;~ , . '.i ~... :.~.,~- gpm l{ gpm (~t fpm,~ fpm ~1 ~ % I ~I ~ .......t: ,~', .'.-' , ~·,··,.\~-:/t"~~~~~;. ~".' -". I",I~,-,.. ,,~~ ''{·~h,;:,'.f:~,:~.~, ,(~~t\,\~'~:~') ~:;:\:, ,';_' > . '",. :: '~:: ,~\:"':~ :'I~~~:t~>.¡.¡,~..~¡.~~~,~~,! ;;.;1'('; '~\,o;, ,::,;..: ",." ~ ',: ~ '~: ;'. ;>~: ,¡',~.'",.""~:,,,,"; .':i .'~, ~< "::~:~- 24 hr Avg ftlhr ( 38 unit~ ( ( ftlhr units Deg F BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Mudlogger's Morning Report 50 150 . l' : .<'t. ~I~, ~'.... : ,~.r...~.,'_ ô.. "": "';'""'f. ,q.:", ~:-. ....~' ..... "~:.;; ;,:,,' ...,. '. r" . ~.,:,...:ç \'1*J:!:'''',~ ".~ ~. i'~~~;""~"\"· 01.. ¡·..~,~.1,t~:;::'}~...~,~¡....Þ· ,.'~'';,III!I ~,~~.~ ."';;t".;.. .': ,~'..,a:~:"M·-tA<;"¡.~~·J",~,~'~J..\,·.:~~,~·~':'~f'Nri f~+~,,"..,'.'"r:..'~"'I·'" . ,'" Þ", ": ,',': '1,.' ~.: Current Lithology: % % ~.I ,1][I!IIII.10.1I[::..-.... %LCM % % ~~::rm::J1 ! ' ¡ Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg Mud Wt In Mud Wt Out 12.60 ppg 12.60 ppg Visc 56 secs API filt PV 31 cP YI 32 Ibs/100ft2 -- 5.8 ml HTHP 13.6 Mud Wt at Max Gas ~ ppg Gels 10 / 44 / 57 Ibs/100ft2 pH 8.0 Sd 0 ft ft ft units units units ppg ppg ppg . ~;" ,.",.~ ...~."'l'lw~···..··Þ.·..¡¡.~ :':¡'I""'-_a"¡" ..1·,.,,1o...:~'·..... . :"'I';"·:O~.'-' ,,::, .,:,. I.,·L~"..,::~,...~_..~ '.1.. : ,. ,\". . ... I' '. . \ .: '~ ~~~'A' I_.t, 3 Type: DS70FNPV Bit Size: 8 1/2 Jets: ~ x ~ ~ x ~ _ _ TFA: 0.7390 .~'; 20 RPM: 120 Hrs. On Bit: 39.4 Total Revs on Bit: 580K Footage for Bit Run 1,924 ", ,"'"'' .·l;J;r!~,:·':':~7~~¡;:Ji8:~m~:;:=~D'~~:X:»l.t:;r::t~,tW~~i\' Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft ""::':.t,..1~Uft!m!t;;;L-=:;':!II!'Ii1 UI...QHr.:r:.:nDJ;iI~~~::·;ü!:::S\~~rn'";¿:'n-(-·:··~···~D~lrT¡4u.L~ ..M.~:1 ;~~~n'C;;;¡;¡;;:11t'".:tJrlm:T I I 1 , I' 1 Bit No.: Wt On Bit: Drilling Breaks Depth Drill Rate during after ft ft ft units units units ppg ppg ppg Gas during before after before to to to to ... .' ~ (, ·"'i~_tø;¡¡Ø'.MmLIÌ.t\1 ",,;;\-wæ ..'. """.( ...., .' ,-.J;_ % Lithology Sst Sltst Cgl 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: ~ . ~~~,,~:'f.:&Æ~!f#~~~t~î~~"'~~¿;~~'\i~~~~~.W¡\~:'~··'~"''i.;;;:''''· v.~ 24 hr Recé Run 7" liner. P/U 1 stand DP and circ string and liner vol. Continue RIH to 11452' and circulate string 01 and liner volume. Start in open hole and begin washing liner to bottom at 12090'. :;~~ '~~: 'Jl~~,1 I :~ Logging Engineer: Tom Mansfield / Reg Wilson '" 1 0000 units = 1 00% Gas In Air %:;, ,··¡t·~;.~~~~,:~t:¡t~':~:if.:~~:~~~~·;~:=:;:~~:~~t~~~~t1f¡r~~~f'~I:~~·,¿~;;~~~:;~~l'I¡~}!t:· .,,:.,' . I I r I .'.~ ~J·'::""~:':'~'~'~:'~~~:,~;i!{~;~~~~,,~ß.;;~':.~'~:~',::- '>\,';;,<,~, ,):'·1~~~~:;..;!,(\..~"1t~~~i}t~~:~~··,;h.~'~~ ," . '., Customer: Well: Area: Lease: Rig: Job No.: spef"'"'l'y-sun DRiL.L.ING SERVIc::eS ."'S;>':"::';". . Mudlogger's Morning Report Current R.O,P, Gas * 20 Temp Out ftIhr units Deg F 24 hr Avg ftIhr ( 25 unit~ ( ( 149 BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 23 4/27/2003 13,461 o POOH wi liner Polya / Holt 24 hr Max ftJhr @ units @ deg F @ Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm A V @ DP psi A V @ DC ?,t,.·".,.,·. '"'.":~';~:~"·\'·t<ei·è\··'i'.";:'i"":¡({~*"1'\~':::::c,~:;'jt*1;k}\1.t!';ì4\'W:,:\¡Þ'i%J;"1~RM~'r)í'ii~v.;i?'Þ\i>}&<':è;'¡\i:i~'~:'i.(\<',*,t~)<æ¿?i'*;¡..;\\r~N,,>~~;~t~~'4.\tà\é:,i'/1\Í~;~..;¡i!%~'t~'Wj:~~\$'iiU~~i¡¡~~\¡;~t!i¡?i:','(if'f.'>,¡,':,." Bit No.: Wt On Bit: Type: RPM: Mud Wt In Mud Wt Out 12.60 ppg 12.60 ppg Vise 53 secs API filt PV 33 cp YI 24 Ibs/100ft2 5.8 ml Gels HTHP 12.8 Mud Wt at Max Gas ~ ppg 9 / 42 / 54 Ibs/100ft2 pH 8,2 Sd 0 --- . . ,,,"::.>' '.<."'," ,"#;;.~,~'z,·~;· .,. .~".. j, "V ..':1.',;·,·:', i!l:'\.;¡,.If.~<4\<:"",,'.lt;~~~~J1'ßI:."~r.~,: ,~""~~r,¿~,;\\)"..~";··,0,·~'·~'~;¡;'hf,&;$~..~\' ;:~,~».ir\'¥;¡~';·.j;¡1!~;¡:·.f.~;" r;:'tn;:~..:;:....;¥,..¡'..:¡~~'tI~w'>'4~'!i':"'¡&"':;:~';:¡;';')'~:"':~~·'Y··' <"I,. Bit Size: Jets: x x \ TF A: ------ Hrs. On Bit: Total Revs on Bit: Footage for Bit Run :.::::m;;¡:$t:ll:;:::r,:~]~~~L:l.'C)'UI·~;~~I' I 1 Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to . '}"~:;;m:1T.'1."1Tr:t_..t_~L"':lJ::~-:RI.\::. "]¡~ Current Lithology: % Mud Cut: ppg Trip CI: Mud Cut: ppg Short Trip CI: to Feet of Filion Bottom: 11~.~,I·,~",,",,".,""HII "'L.~:ì~J7r;çr:1:JI:n:J.:m:~t:1Àt:·-mUI::;a(:U:l:::\:::. , I % % % %LCM L.IIl1R. Ll.n ~ ill I~ r r";;;~'v:x! 1 U~,JI~Æ1i.i¡. ft units ft units ft units 1 U" rT U . Connection Gas and Mud Cut ppg ft units ppg ft units ppg ppg ft units ppg ft units ppg ppg ft units ppg ft units ppg ... T~~1I1l Drilling Breaks Drill Rate Gas % Lithology before during after before during after Sst Sltst Cgl Depth to to to to ~~~JIk~-¡ .¡, 24 hour accumulation of Steel Filings from Possum Belly Magnets: ., Description of fillings: '1*~i~r:J~"::::~,j;\"'\%~Ì'~'f¡i~'i;r~~~.~ J. '~" " ··,~~~t.~~'~~~i:;'A~ 'j 24 hr Reci Washed liner to 13446' @ 4:30 hrs. Circulated 1 string and liner volume (270 bbls). Unable to get off :¡~ of liner to cement. Cut and slip drill line. Rig service. Start POOH with liner. t J~: .~~ ; .\tti Logging Engineer: Tom Mansfield / Reg Wilson * 10000 units = 100% Gas In Air : ,: .~~. /··..;:..~'>;t,;..;>'-::i::'~.r\·~:i~~~~~~·;:~'j\~ì...~1:~~~~'#~_~~~!~$~:9\?;f~~;":~:~:~;~~;~.:<~:-:;.·.' 5pe...,....,y- sun Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: DRiLLii\lG SERVices Mudlogger's Morning Report r-,· '~,' . ,'" ';'::\";'.~" "~"~);f\,~~ -~';~::;)~,,:~:..:~:"~1;':~j~,~'·t;}~'::,\{,~,,::( ;:-:;~.~:;~:;i:':~,<.~W;:.:J:~_, 4. ;:~><~.'~.\~I~:)~~'~ ,:,'/,. _~ ::-';,,~;::.. ~.,µ.; ~;~':;i'i~?>~""~t "':: .",. '.":t, . .,; , ",.\1 i'.· 24 4/28/2003 13.461 o Test BOPE Polya / Holt Current 24 hr Avg 24 hr Max Pump and Flow Data I : RO.P. ftJhr ftJhr ( ftJhr @ Pump 1 spm DH flow units 18 unit~ ( 44 units @ Pump 2 spm Total flow Deg F ( deg F @ Pump 3 spm AV @ DP Pump Pres psi AV @ DC I 5.6 ml Gel~ ,~ \1,;\ ;~ *' -,Jt ~~ ~. ~~ '-,': \'í t..:h 12.55 ppg 12.55 ppg --- HTHP 12.6 Mud Wt at Max Gas 12.6 ppg 9 / 43 / 54 Ibs/100ft2 pH 9.1 Sd 0 % Mud Wt In Mud Wt Out Visc 53 secs API filt PV 31 cP YI 28 Ibs/100ft2 1 Bit No.: Wt On Bit: Type: Bit Size: Jets: _ x _ x RPM: Hrs. On Bit: Total Revs on Bit: '" '1:m:C:Iz,:KI'J:n.:LI:;:¡::U;::C:~:!f~~~ra:.:tm~~ ,'" \ TFA: -- Footage for Bit Run I Trip Depth: Short Trip Depth T~~Spo~: ~ ~~F~~ijL~rn,;'::.,r.m1íL}m,.J:n..m:3~J__bh, Mud Cut: Mud Cut: to to ::-f_,::::r:~:C"U:t\r..5., 11 1. ] I J ppg Trip CI: ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft ~ Il.:::::.IL:::~.r:J~ .', ft ft Trip Gas: Short Trip Gas: I Current Lithology: '1." IIml III fill -11\1 r '~ml_' d JRI 11II1~lIlmm I IIIJIII % %LCM ,.--~~"W11I=J1I,~;:~'Œlt;; % % % 1 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft ft ft ft units units units ppg ppg ppg I Drilling Breaks I Gas during after Depth Drill Rate during before after before to to to to units units units % Lithology Sst Sltst Cgl ppg ppg ppg r;.~k~~"-D&fi~i~t:·-'," 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: :"~¥-:':'~.?¡,:1nrW.!ii.~$ft~~i~t~~,~~Jt~~~~t!iê'i{·1,~~,~Iiþ!ìl(~;¡~:,i<::-,w~'W*,~~··...-W·~"'; ~:~~ 24 hr Reci Finish POOH. Liner left in hole. BOP test. ' I ,:~~ Logging Engineer: Tom Mansfield / Reg Wilson * 10000 units = 100% Gas In Air ~\:...:>,..~.~:"b.';,""~_'~'~~"'..~~":'.¡'¡!;;'*~~_"" --.. .. "',',' ." -' '"-:$,~ - ;'~.,.'.""~.',.~"'.j~.'>~,_.Øí:,,P~".f",.J~.\,:.'E~?~~""._· ".' ·,.'~".tfI~.,:~..:¡-''=fi.~..,,·,·. ... ,', ""\~,~,,·~,,~,,"~;r.f;.~$E~~-~"~I',.,,,.., .", ". .'J, '., ' -" _·"'H~·;:~~~:''''~~'''' , ,,_".. "".:"!,, ~r~~W"1: I" spe""''''Y-5un Customer: Well: Area: Lease: Rig: Job No.: DR I LLI N G SE AV I c: E 5 r Mudlogger's Morning Report Current ~.. " ~,\$1\;.~~,~'\:"1 ,;'\~'~:,~." " .....~,J I.,:':~, ~';-j~~ ',~' :''''.,~'~.:. .~:~~ '~"'~~~1:~I~,.J~~(:-~~¡'.J:·,.\.....:~~y,;,~,~¡¡¡'~,;.1;~~~k:~~'r~':;,,/,~~;..::.(. ~'\:.,i;,;"..'_~:<,· '~,::' 'L.~' A"·'·y·:, .:: ,,':,.~:~'t.;\~,~~·,1~"~',£'~~'·~:~~i~.:..tl~ ')~:'~~'~~'~;,": ~,.",' .;\\.' :~>l.:.< 1.1~,>,.>~:,~\i;,':1~~~r~¥Ü$~¡~1'".-s~··' 24 hr Avg ftIhr ( 5 unit~ ( ( I R.O.P. Gas* Temp Out ftJhr units Deg F 12 [ 12.60 ppg 12.60 ppg Visc 54 secs API filt 5.6 ml HTHP 12.6 Mud Wt at Max Gas ~ ppg PV 32 cP YI 26 Ibs/100ft2 Gel~~ / ~/ ~lbs/100ft2 pH 9.0 Sd 0 % Mud Wt In Mud Wt Out BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 25 4/29/2003 13,461 o RIH for clean out Polya / Holt Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 24 hr Max ftIhr @ units @ deg F @ Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi A V @ DC ( Bit No.: Wt On Bit: Type: Bit Size: Jets: _x _ _ x _ _ _ TFA: RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run ~::~;~~~J:J.::)oo:~rIC,m'~'m:;~~~~_',' Connection Gas and Mud Cut ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units '::~'.i'=" .. - "!["',1::~===I:: -. Drilling Breaks Drill Rate Gas % Lithology before during after before during after Sst Sltst Cgl 1 Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to :;W;~~U:lu""T 1 Current Lithology: % % --·-·Ir¥Œ"TJ.'C;;;:.' 1 ft ft ft units units units I Depth to 1 ': "'- to to to Mud Cut: Mud Cut: to ._....,..mfm?J!M"Ð-..,;,;,;J;:;;^~··g:"r:·.u;;¡;;· ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: '" ppm ppm ft ppg ppg ppg .,~_~!~~_1~ !t1; 24 hour accumulation of Steel Filings from Possum Belly Magnets: Î{ Description of fillings: .. i~~,,:,;:(.:~~:~;~~t~'~ìY'~~~~M_~~~~¡;~~~¡~~i!ff~~~if~;m:~_~-fì4t~*~~~~~~'V;;~~J ,j 24 hr Reci Run wireline to determine top of liner (11282'). Top of fill inside liner at 13168'. Finish wireline. RIH ';,1' with cleanout assembly to clean out fill inside 7" liner. ;1' ~ ~i· ~. \~' Logging Engineer: Tom Mansfield / Reg Wilson ." 1 0000 units = 1 00% Gas In Air ~ ;.::~!. -:,:,:·~~:·~~~~?~~~·;!';ÞrA.~~~~·:·:~~:~;'s~·~t¡i,+~t:·t~~~!~~~~~~~:t~~~1}!.;~~f~:~~~~~t~~~~~~t~~}·~·::;,11:;:i~~~,·;%:~t.~~t;~~i~:.. , % % %LCM I rum~r ~1I:';;;T~'I·;;;;;;;;;rœ"".· -" .. m I I m~ liD If 5pe~r'V-5un ReportD~~~; 4/30~~003 j ,,\~ Footage Last 2~:~~ 13,~61 I Rig Activity: RIH wi packer I: Report For: Polya I Clump I' . 5 hows: ·..::~\:',r:'Y.·<'~"'·' .~d·;'~q~~~·:~~,:I:(.~,,~~,"'''':~l~<;.:·,,{~~~,,~~''~~:'Y~~"'~:~,;j¡>!>;\V~-~\1~"r.,1'~;·:~i:~~'!"~:~~;:'ì~~~',,'-rJ~~~~~,\'t~1.~f-.~<.~¡jf'~~~!f-~~~:~<_.:':;· '''J:(\,'¡,-,~·t~~a; ~.....,,~ ~~.,~-<~#,'~."I.,t¡lif'~'r'''''''~~ ,- "" ~ .--, ". .'.....,.;"'1.' ); " " " .-1 ...., C' ''''J '~~~;'~~:~:: ~:t:'" ,~,h ,'" ~ Pump 1 spm DH flow _ gpmi Pump 2 spm Total flow _ gpm Ii Pump 3 spm AV @ DP fpm ~ Pump Pres.. psi AV @ DC = fpm ,k$ '" Wi;)"';·'¡4~êÇfÄ)\~,,!~i'):¡"";;:;::!;;:)~;~:""'~';1.~#,'i$\,,~,:;'0-r;t1f>~~ir~wM1t%",,**::NìW.1¡~~K~t:i,\:t~~~', ~ """;o/l'4·"';''¡. ',¡;: ...~. ".';': ':;"'; ;'·';\(;t·,..¡¡,;",·,¡;,.:;'·~i1!k!~Iô.'Øt~~,),-.:-. ·.;,~.,;,.:~.,i1:' ".:'. i :" ~':, . .' '... ..,. . ';~",',~ '. ;.",<¡~ 'jJ>.)~ Mud Wt In 12.60 ppg Visc ~secs API fìlt ~ml HTHP ~ Mud Wt at Max Gas ~ppg 'I MudWtOut 12.60 ppg PV ~cP YI~lbs/100ft2 Gels~/~/ ~lbs/100ft2 pH ~Sd ~% I '::."~,.r_','.,~:,,, I ," ~:',.- '''- :'~I" '·'~":\I'~.If:.:"·"rI:,,,~''¡''.·~:'.~:::·''~~.C~.~.·rt.lf.:·.~:~-·.......'::....~~.\-'.": ·~:~·.."'·.I.,.';..·~..I:.oI'·......C'1""O': :~'":r~\.,,'.....~·,· '-~...'~ . I..." ..~.-,..~:~ Type: Bit Size: Jets: _ x _ _ x _ _ \ _ TFA: ~. RPM: Hrs. On Bit: Total Revs on Bit: Footage for Bit Run ItC~~~~:::.I!"J~Ullln[~,I~.T~m[~.L\t~~Y~~~~.t1'~- SERVIc::es Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 LJAiL.L.ING 1 Mudlogger's Morning Report I Current R.O.P. ft/hr units Deg F 24 hr Avg ft/hr ( unit~ ( ( 5 12 24 hr Max ft/hr @ units @ deg F @ r 1 1 Bit No.: Wt On Bit: ( Trip Depth: Short Trip Depth Tight Spots: to ~f·'·IDD~NII'~r.J.._ ft ft Trip Gas: Short Trip Gas: to Mud Cut: Mud Cut: to ppg Trip CI: ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft Current Lithology: 1 ft units ft units I ft units ITI ~Im~ . l [U -1 Depth to to to to % % J _nl-·;·~i;r';;;;;:~::D:";_~., % '";.. ·1("\.Or:lt.t::l":::::':':;;¡:'r.: % %LCM :':':ðiY~: '," _H r "mEn]! J m .' II, III.! II~J[::;Ç;';;!;¡:~~ ppg ppg ppg - Connection Gas and Mud Cut ft units ppg ft units _ ppg ft units ppg ~ ft ft ft ppg ppg ppg Drilling Breaks before Drill Rate during after before Gas during after % Lithology Sst Sltst Cgl I 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: ,,~;j:·:"'t"".:';t¿'¡~':¡iVi~'>!!¡~~~.\..~~~~~·''''"'"'''I''''''¡~~~~~\iil:1~~~l\¿Q;u_~~~O¡¡'l".'~\J.:.JIPia.''',~~,...".['wd ! ":"~ ¡.... ,.'f·..,._·,."·.·rr-,.'~Ii>'·"'",,,, . . ,:¡P.'I'''~~~~~J.~.,.,..__J;ri_.,.~~I~~~~-'~~~~~~'I_.l.Jf,..!~W~'ii~'J¡.,. ~~~~;'lIl"~fF'~~~~;¡,y......:~~....~~. :s: 24 hr Reci RIH wi clean out ssembly. Tag fill @ 13228'. Wash to 13349'. Pumped high viscosity LCM sweeps ~ ~l while washing fill. Pumped high viscosity sweep at 13349'. Circulated @ 15 bbl/min. and rotated @ 130 RPM while .~~ circulating sweeps until hole cleaned up. Attemp to push liner down unsuccessful. POOH and pick up Fas Drill .~. packer. Running in hole with packer @ report time. t ¡~. Logging Engineer: Tom Mansfield I Reg Wilson \~~t>..',~;::"·"~~~ ~':~i!:";' :?*>~I.~}~tf~1!~~,· ;...¥~ .., .' '" .:;,;~, ~11'~JJI~ )I 'A~. : _ (Nt . * 10000 units = 100% Gas In Air : ':'j¡~~:~~~~~~1\~~~~~~\~~"';~¡0~t~î~@1 I I I 1 I I 1 , '.. '. ,,;,'. ,..;:, :~:. '~")~:'f;''',~W{1i:~:~.'~'~¡':.'':~:';:' Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 27 5/1/2003 13,461 o Perforating Liner Polya / Clump spe""r'v-sun CAlL LING SERVIces BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Mudlogger's Morning Report '~" .,"~(' ~,}1): :'::'.; >~ ':, :::~~~.~'t,~y.~%\~}":·:i~~3' }:~rt::r~ :":1~'~~<:,1 ~!;;;:èt: ,~~,~;~~ :~,t:~~' ";'.1:'_,,'., ::;{,t:t..ifi~~~~ ~~:~~;µ:.r:~i·~~,,{~~-'\*,_~'!'\~).'-l:,,:.~~·>~~ ',~~Ò'~'~,~<;:'~' ; ,I.':'\tii.:'f.,"; ;'~~::-',~' .?': -,-, "i~, :;,~~:', .i~t:':_i~~7··,,~.ti~,~~~·.~:,~~:~"t\·,~: :,:"~).: :",,";~$,\J~','f>' Current RO.P. Gas * 0 Temp Out 75 ft/hr units Deg F Mud Wt In Mud Wt Out 12.60 ppg 12.60 ppg Bit No,: Wt On Bit: Type: RPM: 24 hr Avg ft/hr ( 5 unit~ ( ( 24 hr Max ft/hr @ units @ deg F @ 11173 Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm A V @ DP psi A V @ DC 24 Visc 55 secs API fìlt PV 33 cP YI 27 Ibs/100ft2 5.9 ml HTHP 12.5 Mud Wt at Max Gas Gel~ 10 / 45 / 68 Ibs/100ft2 pH 9.1 ~ppg Sd 0.1 % --- Bit Size: Jets: x x \ TFA: ------ Hrs. On Bit: Total Revs on Bit: Footage for Bit Run , ··~}ill~:,l:,:'j)ìU::::~::~~~_J.Ii.·r~;:;,XJ:,:3:'·"'~~(~.I~ Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to '.; " -....:::::I.;;:u::.:œ;:::::øœrX:c:I·~,n~·li'ï":=Hm:-n_....:] Mud Cut: ppg Trip CI: 55000 ppm Mud Cut: ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft ¡ Œ--}\lm:~_~»---.nJU:J!m'I . I IT 11m. 11 II ¡rì!if-"¡n}lLir'·:Jt.t:~, .. Current Lithology: ft units ft units ft units ~¡ 1 r~ Depth to 1 to to to I % % %LCM :I::::!:J: % % ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg .. .. .-:J:1JØJf ft units ft units ft units 1!~[IIIIU...l"r..I"..,~ ". Drilling Breaks before Drill Rate during after % Lithology Sst Sltst Cgl Gas during after before ~J ..,..·~::!jr..," ,- 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: ppg ppg ppg ..:~~~'~;~~~~_,'it_,~~~~~~~~~~~~~_!?>i~if~~(.:,,\~·;l'?',-::;~tÞ~~!~'~;',!_, hr Reci RI H to 13348' - fill pipe and break circulation- set fast drill plug at 13343'- space out with pups - rig up Àø.i cement head - establish circulation, no returns - rig down cement head - sting into plug, still unable to circulate iji POOH to 11187' , Slip and Cut drill line, Service top drive and draw works - POOH _ rig up and run wire line to !. perforate liner at 13529', currently rigging down wire line. , iii r ,Q ~~f Logging Engineer: Doug Wilson / Mark Lindloff * 10000 units = 100% Gas In Air ,~ ,..-:':'~.' r;.~1t?':\.,¡:..~,~~::j~~:~~~:~~I~iMt~~:\~.J~%~~t_":~f~f~t~:::;i'J?W:·~~~~;.~~~~~4Wt~~~~~~r~t~;J:,;t\~'~~l}\:·-~~f3J· ( .~, I'<',~.. ': ~; . . .,... f~,-:; ,,:,;:~'t?l,)¡',Jì;.:": '. . Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 28 5/2/2003 13.461 o Circulating Polya / Clump \~. ~~ '1'." :r:! ;~'~ ,~; .. r;:'~'A>q;r~¡:"'~",, ~~~:~:':".' :·r.":, ." .' ',;:\,¡.'..o~,.~ ~'. .~. ~ ," .' ~~. '~.:, :\:î:'~' '.t1~J., .,-.\!(~ ~~ :,\' ~.\,~~..~ ',' :;-. ,-,., .: -,~ d-. ;.~,,~, 1:.'1\~,~~ ,:,~.;. ~~~-~~~II;'¡~1 ~~t\Zt: ~,~,:k~ -"'~':'~~ ~·.:,\-;:"ì,''''''''''~: ~t:..;:~,,:~-:t:<;~~:, ~i~,-.H~;' :,w ~ \",,, '~~,~ '; ";':"';·,~,:,\";·)ì_.}:~~~~~::1I5~·:~:,~~'<':~':; :~~>'.: ~1':; ,(,"'-~ Current Lithology: % r'r'---"'''~ ~IIII In mmr III % ...-:In.. % sper'f""'v-sun !:JAIL-LING SEAVIc::es Mudlogger's Morning Report Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ftlhr ftlhr ( ftlhr @ Pump 1 spm DH flow Gas* 52 units 34 unit~ ( 325 units @ 13199 Pump 2 35 spm Total flow 124 Temp Out 92 Deg F ( deg F @ Pump 3 spm AV @ DP 54 Pump Pres 920 psi AV @ DC 482 1 1 ~ " gpm .~~ gpm::{ fpm ~ fpm .:Y A~ Mud Wt In 12.35 ppg Visc 55 secs API filt 6.0 ml HTHP 12.6 Mud Wt at Max Gas ~ppgu,. Mud Wt Out 12,35 ppg PV 33 cP YI 24 Ibs/100ft2 Gels 11 / 44 / 66 Ibs/100ft2 pH 8.5 Sd 0.1 % .. .'. ,. ,.'·,~"~'r, .,;,;:".j. :-.f ."J$'.x1";'~,~..;r:' J.¡:'/:',! .ì;..~.,..c"",:~·,,;.~..,;·...!':'M:ti~t.:"~r'!"":',,'5~·1;(t\i:4~;::¢I~"'''''~¡<'\'\'';:''' '··~·.~:!t'i,4.'¡;' "~"~'!G~,:\r,',..n"'¡\¡'''''I'}!':Wi~f'1"'~.:·.,r.,,,,;,. ::,,~,t.·>_. .~,~: .'IfI.:r;rl."': :~-,.;:.:~(!¡\ ,,~:;.i;,..;,,:¡,.~, r ,;.",~~. Bit No.: 'Type: Bit Size: ' Jets: x 'x \ TFA: ·I~ Wt On Bit: RPM: Hrs. On Bit: Total Re~n Bit: - Footage for Bit Run : : ,_.1 ....~~m::r:~..;¥!\~C:JI·:" ~ ! Trip Depth: 13213 ft Trip Gas: 325 Mud Cut: ppg Trip CI: 55000 ppm " t Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft -~.:X:~:f1n:~\'C,~oc:r:::.1::rD:::'~;;;::::Œ~:::::':.ìlL,.._A~~ . ~ :~"!'"WI [ ~ T r J IL U ~·~;o~;:~:;n. 1 1 1 1 1 I I 1 % I ßID œ Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg %LCM ft ft ft units units units ppg ppg ppg ft ft ft units units units ppg ppg ppg % Lithology Sst Sltst Cgl ~1i1iil~1iiIi~ItŒiJ¡~;¡~iia¡~" ¡!~æ_iJIE.i_ 24 hour accumulation of Steel Filings from Possum Belly Magnets: ·T;~:~~Ë:~~:~1~~!n:~:~S~~:=E~~E:~~:::r:~:~::;~:-"1 Pumping up and bleeding back pressure. Esablished returns pumping at 3 spm., slowly staging up to 25 spm- ; Packed off. no returns - MW fell to 12.3 PPG, while staging up. Decided to circulate and condition mud to 12.6 PPG before re-establishing circulation through the perforations. Drilling Breaks Gas during Depth Drill Rate during after before before after to to to to Logging Engineer: Doug Wilson / Mark Lindloff * 10000 units = 100% Gas In Air ~,i,~f~¿/;¡~~~W:·~~;~f,):~f:"}tiit~!~~~;*!~j1;_~¡~._l._~~~~~~~.;.'. ~l, ..). I r , (~..~. ":.:" :;.'I~< ~ .,':'~;;"~·::;:~¿..;~th~¿\~~'>'~l;;' , ~,' 28 5/3/2003 13,461 o Fixing Blocks Polya / Clump Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ft/hr ft/hr ( ft/h r @ Pump 1 spm DH flow Gas* 0 units 26 unit~ ( 187 units @ 13198 Pump 2 spm Total flow Temp Out 78 Deg F ( 78 deg F @ 13461 Pump 3 spm A V @ DP Pump Pres psi A V @ DC I 1 r 1 1 ¡ i ~ t . ! 1 sper'''''V- sun DA I LLI N G se AV I c: e 5 Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Bit No.: Wt On Bit: \ TFA: --- Footage for Bit Run ;; .',:' ~~,:: .: :.. ':¡,!:1µ;'\~;II~r~".:~~, "~~~'~:~"'JI\~'~, ,i."',~·~-!: ~ ~:~,< ~ ...~~~'~.{~i'.:;: ;~":" ....~~;.,;;:~':f~~~'~~~~~j:~~,\~'¡1·~~~'":~~·~:~~~~)/.~:.:~··~,~~~~ti.'~~~\~·:,t~;t..· !_,~(¿~ "~~-à-\~~'t~~~ir~~/:t~\~';;'~~~~"'J:".z;~;~ ~¡~:~4o..:~\~' ,~,';,~'~1;:;;' .',~ .:.~,~~~:.:;."'~' '-'."~,::--<'" "':~~ ',:,,":;:~ '". ',,~r"'~:; ..t-r;~\{:~$~f.:~ ~,~",:, ~(;;, I %LCM ft ft ft units units units Mudlogger's Morning Report BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 % Lithology Sst Sltst Cgl .II ".'. --- Visc ~ secs API filt ~ ml HTHP 12.6 Mud Wt at Max Gas ~ ppg PV 29 cP YI 32 Ibs/100ft2 Gels 12 / 36 / 44 Ibs/100ft2 pH 10.0 Sd 0.1 % Type: Bit Size: Jets: _ x _ _ x RPM: Hrs. On Bit: Total Revs on Bit: , ,;~1.:::~.,,1¡t::¡::::;;J~r.r::-.m~ ",' Trip Depth: 13198 ft Trip Gas: 187 Mud Cut: ppg Trip CI: 50000 ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft lY:P.X~II;:;~~~,~'LB:~~ti::!~~~~-·g;-rlt(1)J:n: it III[ ¡II _ ,,",~J:nI.:~-- ppg ppg ppg '., .", :.,~I~iI': ~-~.....'~'\~~~~¥-t..?t.;~~?~i(~,r'ttt'~"'~'''~':'~ ",~.,,~~'rt~~-·:'~,.¡~~~1t~:.~~~~~~~!#-~..\'t·,);)."';:~~~·'l~~~..~~:w{~;..~:~~~';\'#:it:::;. J·";".:?'ð...~*~~,~~µt-,,",~'l~~~\iJ':~~di~'I:.~J::'·~:~lt·, "t ~..f:" '-~~'~-{~::'I;'~1 '.. ....:.\.;, ''''_'": ~~,~' ~;.;c- ;.~-:, :,.'~ ~,:~.~."" Mud Wt In Mud Wt Out 12,60 ppg 12.60 ppg I I !~ ¡ ¡, '. .-' )\¡¡" 24 hour accumulation of Steel Filings from Possum Belly Magnets: \1 Description of fillings: _ !~}.ti~-i:~:JI~~~~~~'" .'Ö/f:~..:;~¡<~:'.-, '~ 24 hr Reci Cir & Condtion mud to 12.6 ppg in/out, Make up' cement head, sting into packer, attempt to circulate ;{~: leak off at 1350 psi, estimate injection rate up to 4 3/4 BPM, Plan for squeeze cement job, unsting from packer :~: pump cement job, max gas from squeeze 44 units, continue to circulate 100 units of gas at bottoms up., No i ~~~:v~. returns were seen at surface. Begin POOH, inspect traveling block, currently repairing traveling block ,'~ . '*':ï, :1 Logging Engineer: Doug Wilson / Mark Lindloff * 10000 units = 100% Gas In Air ::~': ·':-;.",::~:1_:'.... ::" ".:;' - ,,~.~,~~,;,o,~~~." '~,~~'"!;,'",'. \~ ',' ~~:tt"il~-·~~~~~~~rI.;¡¡~>!:q;y , .... ,", ,.~.-,~...¡ P-,.,.,.. .~. ~11~.JV~~f.,.~~~.if~~A·~ ~.~,_ ~~~~_ji~~i,f,,~:'~~.T.'.¡'" .' Current Lithology: % :]111.11 I ß fiT If 1111 _ ".'LIlLL % % % ft ft ft Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg units units units ppg ppg ppg Drilling Breaks Depth Drill Rate during after Gas during after before before to to to to "'\-¡1I(~1~r~'''', "... .. ~~.~ 'N:I1'UtA L,J.~I&."f'I't~~' . I :.f .'I..~~":~~"'lþ~"" Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: spef"""'r'y-sun DRILLING SERVIc:es Mudlogger's Morning Report 1 . . 4., " .... . :. :.-:.,., "~..r":7"':-t.~:..'~'" "", ~.."'~~"v·~ rra ~... Current 24 hr Avg 24 hr Max R.O,P, ftIhr ftIhr ( ftIhr @ Gas" 0 units 0 unit~ ( 0 units @ 0 Temp Out 75 Deg F ( 78 deg F @ 13461 , of:.' -, ~'..a'. . ,",,;..,\ ", .', 29 5/4/2003 13,461 o RIH W/BHA 10 Polya 1 Clump Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm A V @ DP psi AV @ DC 9 P r:¡::, gpm :> fpmiJ:; fpm;f:: N~~ . ~~do; 1~>'·-~·:'~:<"::'·~":::"4;~'¡:::"'''':';~_~~7::'é:\''~~'.''~:":; a:~~~ ~:s ~ ppg 1 Mud Wt Out 12.60 ppg PV 28 cP YI 30 Ibs/100ft2 Gels~ / ~/ ~lbs/100ft2 pH 9.6 Sd 0 % ~i " .,-'... _,"; :' '::,;~."..:' ~'~~~""':X!-;:,·\~\r;¡';:¡¡·""'$-4'N.'t1Ic'."\~j..'~:~:,Þ#'''.*'f.\,;~.;£:J.:1;';;·"¡h.:~.:>t¡~,¡!t~:.g;~.~r::'¡¡¡¡;'~~~~""'~;~ìf:,:·:;·~~·:~'"'.,~¡:'j~~,::::'~',~\(,,":;,.o~i~~:,:>"" ",".'.'" ',,' ",..,,;'~.: ,...,: >.>/ ;.';^" .', ,': . ./" .. ",.~ ~:~~':Bit: 5~~~:~S¡O;Bit: 0 X-Fooœg~forBi;:~n.~' ,.. , . -; ~ I o I Trip Depth: 0 ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to :::;m:~(\.ltS~~;:::::::~~~ I IT I j .m:Iœ:::ll:~ Mud Cut: ppg Trip CI: Mud Cut: ppg Short Trip CI: to Feet of Fill on Bottom: J JkOC::::::r,JJ;Œ:!::::1\m. Mfll 11 l&:: --. .... "\ o I ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft un~s ppg ft units _ ppg % % % - J(r II ::I:;;;lr-~.II~:;;¡:~C~ "~~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: I Description of fillings: fi':=~' . Re~tring drilling line 'through tra~eling blocks and crown sheaves- p~'i j: Currently RIH ~ :1 I.~,! Logging Engineer: Doug Wilson I Mark Lindloff ,¡~ M~~(·i:?~1~~I.~:~~'~~\~',.~'~., . ..:.¡ .'. .,,' ", Current Lithology: % BM¡SIUI ~ F ur ~IR 11m I - l~m~ftll I ,F IIl"JmiJJlli,m 1!¡llm~ ~ ~II I ft ft ft ~ units units units Drilling Breaks 1 Depth Drill Rate during Gas during after after before before 1 to to to to I ~~~":"p"vrl " ~:';l~l~L." .' s><.\\'., %LCM ft ft ft units units units 'j: ~ ~" ;~i ~ t ~2'. ^' ppm ppm ft ppg ppg ppg * 10000 units = 100% Gas In Air % Lithology Sst Sltst Cgl , r. ~~~~~¡%1;';;fF:';A~~'~~~~ I DR I LL I N G SERVICES Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 30 5/5/2003 13,461 o RJU Wireline Polya / Clump ~iÌ.' ;~ Jìf, ~~ &; ~ 3~ It i spert....,v- sun I Mudlogger's Morning Report i:. '~-:~¡'~J;::':~'; ';¡" ,\":.t;,:'~~:~:::" ~~t~·~;. I~;\~~:;r·,I~!?~.."1 'I(>~~k'I'~\:Y:;\~;wì ".~~~;S.¡~1,~,~:i'~;~,~~~l.~~~!~~Jì~{t'1q~~;'1~~~~~~t:'~~I:',: ,': ':t' ¡'::"':,i,';·~.;'~:$?t~~~~j~;:'~:f~ij;t ~~Ä~~·~~'~;<~?~~;:~:~?: ~',~; .;ú.~]~~(~,·, o 90 ft/hr units Deg F 24 hr Avg ft/hr ( 24 unit~ ( ( 24 hr Max ft/hr @ units @ deg F @ 11275 13461 Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data 75 spm DH flow spm Total flow spm A V @ DP 1290 psi AV @ DC Current 1 :~I 9 P m.2 267 gpm,).~ 115 fpm ,~~ 388 fpm .~ '.....(' :-~ fì~ ;'.~. Mud Wt In 12.60 ppg Vise 53 sees API filt 7.7 ml HTHP 0.0 Mud Wt at Max Gas ppgl <;' Mud Wt Out 12.60 ppg PV 28 eP YI 24 Ibs/100ft2 Gel~~ / ~/ ~ Ibs/100ft2 pH 9.9 Sd 0 % ~ :~;. < ','. ,.',' ,,:,'. ',w. '. '., ' ,^ -, . \~.,'"~'..:: ','.' '~-:"C_" ''::~",.1!í:4)¡',*:;''1\,<'"t¡:¡,¡WR*~'Iõ,.',(,?>t\:"..r.,"';,~~_·,.x ~~,r~,d;!I!'r~~~,,;r~,..,< ::'S':iI~:' .;:,:"', "'? >'..\'..'" ,,\~\ ,~"o:' . ."\:'~': ,^" ' " .., . ..:;."~,~ ~ ¡ '.~J, Bit No.: 0 Type: Bit Size: Jets: x x \ TFA: 'I' I: Wt On Bit: RPM: 0 Hrs. On Bit: 0.0 Total Re~n Bit: - - Footage for Bit Run 0 ~';'w"·..,,,,il'\!"t>i.I,t''''''~'''';~·''<~',II¡~~~¡&Jr:It¡l~(f1~~~~~:I~.ïf~~~ØJ'.,f.,i't¡.~!;.":.~~· ~;¡¡."'~\::~¡,¡m~I, j~~f ~ 1 ~:. Trip Depth: 11275 ft Trip Gas: 213 Mud Cut: ppg Trip CI: 0 ppm~. Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Filion Bottom: ft ,·'t::u;:n;;;;¡;m;t ;,~'T'-··-;-~;1!11:··tl';-~':'T:::¡;':::::::1!1.[.." I JlI ~ : ~ "'ß.. ,,~~ .. ¡ ! [[o..';¡ .v"'J;[ .. " ..~ "1:1!II!.Ir.:"" " RO,P, Gas" Temp Out 213 90 I I.- .". ... '..1 .' . ' " ¡.., ~ ..,:,.., ~. "-....,_ .1'>....,......,~...;......... .ya¡.~.,~I",,'"':.......~.':.. :'~~""r~t-',:,~1..~~....;..~·~p...-:f'J;:'·~~r....:~"::,..è.Q¡.~·~ .~.~........:"Wt'II'.+~ ..,tw.\~~'~"~-t.~-i'i"'i " 1 I 1 Current Lithology: % % % % %LCM f~~'[f"-Jl!::T1JI!II:,~IiII' l~mH L ~';.1J!:~2'^~, d Connection Gas and Mud Cut 1- ft units ppg ft units ppg ft units ppg t ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg j ~ Drilling Breaks ~ Depth Drill Rate Gas % Lithology before during after before during after Sst Sltst Cgl 1 I 1 1 to to to to ~ ':,\.~~_""""".' 0·.,.···1: .,' ..,' . ,.'I, .,,,,,'I\~,,>"~~'"'!I.':!. ',"" '... . ~r. ~ ~ I.. .~~;~:~~t:::fi~~~:~ OfS:I~ :~:;~:~~m Possum Belly Magnets: O.35Ibs, . '.' ... è.,~"i ~"",:,.:¡.,..~,~~,,~..:i~'~ '. ,~ ",; ~~,/,f"~ì$~ ¡~ 24 hr Recé Continue to RIH with BHA #10, Circulate mud till Mud Weight in and out was 12.6 ppg. 213 units :,1' of gas was observed at B/U. Continue to RIH to 13085' - washed down to 13207', Continue milling on fast drill · · ,~~; I FC, and LC, Tagged shoe at 13434' , circulated hi vis sweep @ 14 BMP. 121 units of gas at B/U. Monitor well, 1-: i pumped dry job - POOH - Lay down BHA #10, currently rigging up eLog equipment. b :i~_ ~ 1 ~~~ r't ¡ Logging Engineer: Doug Wilson I Mark Lindloff . ". . '. . · 10000 units = 100% Gas In Air ~ .'·'i3.,:···;:.,:":;·I;~,;,·:~~,\t::~:Y~:;Ò·¡~~ir~~~~~~'t4i~ft~i~~1~.~~~~~M~~~~l~h?~j~·~1.Øi : ~:.': . ','r'; <::"',::':.~':':;:t~~~:~~~w~;~,~~¥~t~~{~~_~~s:~;~ :~~'~;~\',:} \.~:~;;I,~:~';'f:i\~~lttn~ì~~~¥.~~~'¡':.;~.~~:fj:?,,:~'l~>t~'):~.V~~ ~':'::·;:~~1·l~,~.":."·.,Ô~~~\ sper'r'y-sun o A I LL I N G 5 e A V I c: e 5 Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 31 5/6/2003 13.461 o Test BOPS Polya 1 Clump Mudlogger's Morning Report BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 :·'·.·,j,.·,:·.;"':.~:j).~};,tV,,\).\'1\J·~ftJ·_·f('..-:,;"'K.Ji:i(.\.:t;·4i¡t.~'\)""ff;¡,~~~~i~1\if~jl!..~~~\'~M'~i;{~'it;t;;{~~~)'~~;f,¡\~;.t_~~~~"~:¿¡'i!>.~~~~;,.tt.1i~)(j'~~·;!X:"f!; ""i"! 1 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P, ftJhr ftJhr ( ftJhr @ Pump 1 spm DH flow Gas* 0 units 0 unit~ ( 0 units @ 0 Pump 2 spm Total flow Temp Out 78 Deg F ( 78 deg F @ 13461 Pump 3 spm AV @ DP Pump Pres psi A V @ DC I , . .,. -' ". " ··:Jri'.~.:¥ì~~,,,,,"·..1O!"!'l ~,.", ."'......~,1"4'\"1Þit'\1i.tr.J.'.~1IÞ~~.~.,r.::j.~~:"3!.u..;~~,..~~t'.:.,~"';'llU.li':!,~:~',:r'. ,~,.,~.,,; . . ,. ...,'. " ...-; .'. I :...'.j,<..~.¡æ,,;1;¡f.iAA~~,.;;1~M'1l~\¢¡:.'¡$;~t<l;~~~...~'a~~.I"~·M1ti~,!*~:~~,.¡g¡t~~~7t.'¡.:";,1,$.'.'..':.',;¡.~~.,""·:;.~,;,~:·~,:/~;,,·· '.;' Mud Wt In Mud Wt Out Visc 57 secs API filt PV 29 cP YI 33 Ibs/100ft2 8.0 ml HTHP 0.0 Mud Wt at Max Gas Gel~~ / 23-. / ~ Ibs/1 00ft2 pH 9.8 Sd 12.60 ppg 12,60 ppg 1 Bit No.: Wt On Bit: x \ TFA: --- Footage for Bit Run o Type: Bit Size: Jets: _ x _ RPM: 0 Hrs. On Bit: 0.0 Total Revs on Bit: , "::r=:::::\t:::';J:tU:,.'7M,"i11U'U,:r:;:.¡C:~:I:::m:::rm1f;:Jt:;~:~j:.t" Mud Cut: Mud Cut: to ;mrH'~I:==II!: II I gpm gpm.:' fp m )~' fpm;:j, .;;t .~ ppg o % o I Trip Depth: Short Trip Depth Tight Spots: to "---:~-A.......,iI,l'IIr~_..,_".""."_ to ppg Trip CI: 45000 ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft , J.L~m~~~:::"':J!=... ft ft Trip Gas: Short Trip Gas: I % I!~.w_~w~mm~~ % % % %LCM r' M:1:,. . ft units ppg ft units ppg ft units ppg Current Lithology: '" ,. ::m::::'_..I.iI1111 1 ~ ~L 1m I mlm ~iI"'~ m Connection Gas and Mud Cut ft units ppg ft units ppg ft units _ ppg I ppg ppg ppg ft ft ft units units units Drilling Breaks Depth Drill Rate during after % Lithology Sst Sltst Cgl Gas during before after before I to to to to ,- '1'¡ih"ilf),"'" 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Scale and slivers ·~~~¡~f..::;~':k~~~.~~~.ø,U\t..,.~. .. R~;1i'k;¡Jr;.~l~'W;<~~!ii.1f.~ti~~:·':. ~'iI:'J~:. ' ,y 24 hr Rec¡ Continue to rig up wire-line, run USIT/CBL over 7" liner - run fas-drill bridge plug - test choke while ,.' wire-lining.- rig down wireline, flush stack with Johnny Whacker. Currently testing Bops I .'1 ¡~ I Logging Engineer: Doug Wilson I Mark Lindloff ~~~:::":'i:1:?:~!_~)1~Vf.~ "1'" I JI I * 10000 units = 100% Gas In Air ; . .... ;..~~ ~":.'«. I \."" t 1.1.....1,.. t.m <II "'~,,,~r?'{:: ~ r .~:ïI\:i;'~~i\1~j~·~~'~~~~~It.·~~ ,'~'Ji:., 1 1 I 1 1 1 5pe....,....,y- sun DRILLING SERVices Customer: Well: Area: Lease: Rig: Job No.: .' ." f. " ,..,,';:e;¡,~~..,. BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 32 5/7/2003 13,461 o RIH W/BHA#12 Vaughn / Clump :, ,'.' . . ~\ (':'.. II, ~'-t" I" t.'... a . I." ~ . .;..,.' -, . ... 24 hr Avg ftIhr ( o unit~ ( ( o 13461 Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi A V @ DC .~ ~~ 1~1,':;"l.'!.1 ..- -,.~.,..!.~..~ "~'''.' .... '.',,:',,\,,~~r~II...,¡';.¡,.·I.....¢..,.t:.':'\'\.···~I~\o¡f~~];'U::l"':~~'pa..."P-~,,"'t'J"tt"'~'''Iro~I'';'':'~~·~~~~~.~t.t.'~,'';.~''''JIþlS''ort"'t- ".. .~ ...., ''''-:1'... . ,',,¡.: ..._. --- 8.2 ml HTHP 0.0 Mud Wt at Max Gas Gel~ 11 / 35 / 40 Ibs/100ft2 pH 9.7 Sd ppg o . '.'; . .:;....., ;'i':>-" ·'..,~..fWf,.,..,·'.'"·:;:\'.".,:;':~",~,;f..;;.~\.i0....'1,,.'~;,~ð:~i:-i':,f~:~J,\tJt'!l4'·~:''''¡'<,:'¢I.i'ìJI:,i;J';~;.t\¡¡i;~~~,m~·~~~bï;'~';r!>i ,,,,,,)!!"¡~,~~:.i\~'~'":I:"i¡<,~''¡~!!:::'·'"'t:';·'',:·r:. ·¡·"r'~~;"'·' ',", '::J" "'.~ Bit No.: Wt On Bit: 6 Type: HTC/EP4970 Bit Size: 6 Jets: -2... x ~ _ x _ _ \ _ TFA: 0.5180 o RPM: 0 Hrs. On Bit: 0.0 Total Revs on Bit: 0 Footage for Bit Run 0 r.ImT.1C~f1r,::t:~~::!mr:":tf¡:J::Á:::r\tf(]r~:r~::::::»::::II$;::Jtmr.:::t(,,"':1l::I': Trip Depth: ft Trip Gas: Mud Cut: Short Trip Depth ft Short Trip Gas: Mud Cut: ïight Spots: to to to ~. .-r"C:i:ŒI1[:n:==:JI.:~:::t:JlM.W,1I111 . ~L;I~jJ.:I:a:I::::mJta: " ppg Trip CI: 45000 ppm ppg Short Trip CI: ppm Feet of Filion Bottom: ft % % %LCM ft ft ft units units units ppg ppg ppg Mudlogger's Morning Report Current 24 hr Max ft/hr @ units @ deg F @ % Lithology Sst Sltst Cgl '~i~i~il~ri!l\¡;¡~;''''d~_;~!~~>J'Iia~~LI;~, 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Scale and slivers :':iìf':.:··"'~'::':~~~:~~7i;;i., tì" ...."". '" ' ~_t~~ :;: 24 hr ReCê Continue to test BOPS, pick up BHA #11, RIH Set Packer and polish top of 7" liner, test packer. OK . ¡ :........~ POOH, cut drill line, pick up BHA #12 (Drilling Assembly),- RIH I~ ;~i I: J Logging Engineer: Doug Wilson / Marl< Lindloff · 10000 units = 100% Gas In AirJ ·'~~'¡~"r~~~;~~~~.@.(~~~~.iIJg~_~~i .. R.O.P, Gas* 0 Temp Out 74 ft/hr units Deg F o 74 Mud Wt In Mud Wt Out 12.60 ppg 12.60 ppg Visc 57 secs API filt PV 28 cP YI 35 Ibs/100ft2 Current Lithology: % % . DJ:'''11~ II';. m W!_.¡L.1Jil. I 001 ',r J'~ _ JïfJC!!':::'"-:- ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft units units units , ¡ Drilling Breaks Depth Drill Rate during after Gas during before after before to to to to . ... il\·i ~'';'." ; ',r,\.."'. . .¡ J. . \.'Ü~~':-: " :..:~ ,I:.> ..~:- ~: :.. "... ' '.' . '.~ .~'-.'~~,'.." ..,. "'~~.: ....._~ I spe.....,.....,y- sun Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: C)f~ I LL I !\I G 5 e F! v I c:: E 5 BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 r Mudlogger's Morning Report -~. .....!'.: r'" ~~~.. ~:-..-. ~ ;11' "I. or-. ~. ..-. .' . o,,,,'-",-'p~-·'.:a..:·.:..::·.~,' ¡'.M~~'- -r~~I' ....: -I~"'.~~-.¡.,J:?~· ·'o.,·~~"-·. - ;/" ....4Iir:"¿;"..:.-~L.~.P~t:;;.:.:';('~".i·.~.\.....~~,..,·..~~~·,,~·.'-:-."i_ . ~ :-.,' ':., :'~'~'. .:.-..,.~ ...-r ,_.:~ ... 33 5/8/2003 13,654 193 RIH W/BHA#12 Vaughn 1 Clump Current 24 hr Avg 24 hr Max Pump and Flow Data R.O,P. 44 ft/hr 29 ft/hr ( 420 ft/hr @ 13462 Pump 1 spm DH flow Gas* 101 units 150 unit~ ( 596 units @ 13481 Pump 2 90 spm Total flow 320 Temp Out 74 Deg F ( 74 deg F @ 13461 Pump 3 spm AV @ DP Pump Pres 3420 psi A V @ DC " . .WI·"·.:" ..t".~~ .....:- '\""",' .~!\:;.... ..'I'J ...../"...""a·.":...~~ 7,..~~-;ã¿.~.·.~....,...~...."I"I~.:::~,,~lt·..l'o-:....'·~.f \~....!;--.d' '¿'l'fll:.t.·'!.J':~~,...~~,~t#'{~·~'.:~ril~"~~...,(çy~:.·· r ..'... ~ .~".~' \........ '. I --- 4.5 ml HTHP 0.0 Mud Wt at Max Gas Gels 13 / 17 / 18 Ibs/100ft2 pH 8.2 Sd Vise 45 sees API filt PV 10 eP YI 29 Ibs/100ft2 Mud Wt In Mud Wt Out 9.25 ppg 9.25 ppg .' I. "'0 .t·,II,:;.,..·.....~~~.~.'...,,;: ..h....:._ '. I.. .Or· ·.\·.·.t..::~..I·:"'.\",.....··r.,:~':.,.,;:j·.ø..~v.).7f:.~.:I-ttIJl.......!¡,.·~·'.I "':·..,..··-.Lr.·':"·'fJ..M~,I'_~.. :..~·;.~I'":".\:':'..:..I·' o/f....;:Jr::.~ .':..~.:"', '\~i ~f I ~, ~ ;1, ~ '1_'1 ppg o '~ gpm ~~. ".1' gpm ~f~ ,~t fpm:;~ ;t~ fpm l~ ~ 1 %:\¡~ ~. '~r ;* x \ TFA: 0.5180 -- Footage for Bit Run 193 1 Bit No.: 6 Type: HTC¡EP497Q Bit Size: 6 Jets: ~ x ~ Wt On Bit: 20 RPM: 84 Hrs. On Bit: 11.0 Total Revs on Bit: " . ,'~:n.""D:L~nt:~~l~:~::::n:lJC~:::JIU1:;a~~lIIE:rx.:=~·, 98 I ft Trip Gas: Mud Cut: ft Short Trip Gas: Mud Cut: to to to . ...... ~·U;¡Ji(Dœ:\~;]L;;;"'K!-~t~).L . 'tlll~ H . 1ffir?ì:x:::ø=nr:·~-m_1I ppg Trip CI: 18000 ppg Short Trip CI: Feet of Fill on Bottom: 111111I J mllllii ¡:lil.",X Trip Depth: Short Trip Depth Tight Spots: [ 10 % SH 65 % CONG % %LCM 25 % SST Current Lithology: 1 W r' ~ ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft units units units i , . Drilling Breaks Depth Drill Rate during Gas during after before after before to to to to ~~An"'fJ;la~m!~~M~~I~: ~~r:'3f::,,;;",- ft ft ft units units units ppm ppm ft ppg ppg ppg 24 hour accumulation of Steel Filings from Possum Belly Magnets: ( ~.: Description of fillings: Scale and slivers i ··tJ~~·~~~~~··"., T.: ."'" ..... . ,.....,..,. . ,....' ..' .'..'.'..,. ......:.JI¡"tM*'i~~~~~,.~; t 24 hr Reci Continue to RIH to 13195', lost hi line power, switched to rig engines, wash down to fas-drill plug i i, at 13225', drill out, displace well with 9.2 ppg mud, washed down and tagged shoe, F?13434 T/13436 - drill/clean .' lout rat hole T/13481'. Perform FIT, leaked off at 11.3 ppg. continue drilling to 13654' MD, I Shublik 13505' MD 11020' TVD , Ivishak 13657 MD, 11150 TVD .1: Logging Engineer: Doug Wilson / Mark Lindloff l~'··~~::~ì~V~.tI: % Lithology Sst Sltst Cgl * 10000 units = 100% Gas In Air ,*,,,' -''ni~~~'"\!t~'III:'£':\tii'V.:i_··';'... '.'...,. .... . .",~~,j~ÎI'I ,_"f?~:~W~~~,i:-l~~'\'I"'\"~I':¡'~ ~I'-..J'.i'.".." ~, ......-..~./'",!J · 1000~ "':'T:. ,!JlII"1'jI. ijV1~t\~ Ìr~;~~1"\",~. ;t~"~,¡;> "'.í:'"..:~.s.~.oII!i'~.... ..·...~I, :~.~ ·~~~~1.~~~~~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: Descnption of fillings: Scale and slivers ,I' ':.:·.\,'''~~:')1':'~'::~"~!f~~~i~.~~\'s.I¡''·~··'''~~~~~~i1t¡~~~'té.i~'';(',~'f:'~'¢*_ hl.·rr.~~.,~~~fIj\5~ì·i'~~~t~\~~1J1Jj 24 hr Recí Continue to drill, TO' ing at 13981.4 MO, 11434' TVO, Circulate and 'condition hole. Mad Pass to shoe, ~ Max Gas 178 units at Bottoms Up, Pulled 20 stands 11550' md, open PBl to circulate (12500 stks) . hole clean with 130 units of gas at Bottoms up. POOH, Currently laying down BHA#12 logging Engineer: Doug Wilson / Mark Lindloff ~ ,.¡ 1 ¡ ~ % Lithology Sst Sltst Cgl ppg ppg ppg units units units after Gas during before after !m;~rI'..~-"nW" 1L~JU,,~. to to to to Drill Rate during before Depth Drilling Breaks ft ft ft ,LaT.... Connection Gas and Mud Cut ft units _ ppg ft _ units _ ppg ft units ppg 1 ppg ppg ppg units units units ft ft ft Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: 18000 ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm ïight Spots: to to to Feet of Fill on Bottom: ft 1 ' ,.,.:=[\111]1] ~ . 111I' ·11"Q·--I[lJX.~~(::·=;f~··~:r1 'Ir'J~]U]]:t:C:L1: Current Lithology: 10 % SST 40 % SH 50 % CONG % %LCM ]11I 101111 ß1J:l~:::CjTji( 4.2_ml HTHP 0.0 Mud Wt at Max Gas _ppg Gel~ 13 / 18 / 19 Ibs/100ft2 pH 8.5 Sd 0.1 "0 __ --- --\" :. .:~~..":I~ -'.,",~ ~ü",,"1:~""~,I~~~·:.":!*~~~~";~f· .~_,:-,".:"~ ...~:J...~~' r'~~~~..)J".~r,'-~~~:c.~."'~\i.p"J'''''\hl;-=·~?'~'-=:''w..r- r;,~,.J'?r:.:t'"t :...·~·,þ'.~~.\:,:ï.,.>~;{~;":J'~·..~ :'t.-1'"!"":. - ~..r r ."1'" ~ .'. .:,,:'if.. Bit No.: 6 Type: HTC/EP4970 Bit Size: 6 Jets: 3 x 15 x \ TFA: 0.5180 I' , WI On Bit: 0 RPM: 0 Hrs. On Bit: 0.0 Total Rëvšõn Bit: 0 - Footage for Bit Run 520 . I: "I~~.:nMU~:~:m:.~.,J.l..IölIIJIliij..l nmt:m:~.~CT'~::DJ::r:::~U:l:J['::!X;~J;,'[J:~..:=~::y:r;:~~ . ""'1'· I I ~ I J 'I "'-,, ~ .~ gpm ~ It:f gpm ~~~~ fpmi, f¡:.m ~ , rl"'" :\~ II M' I" ..,.--4.........., 44 secs API tilt 10 cP YI 27 Ibs/100ft2 1 Vise PV ppg ppg 1 13917 13762 13461 24 hr Max ftJhr @ units @ deg F @ 930 Mud Wt In Mud Wt Out 9.30 ""'r', ~~.~.~...-:'J.~'":.'I.II.~ \. ~~~ ~~.')~ -\..... -. ...~l~ ..':'t._~¥:~...ù'.I.,....l1-·~....I:~.~!."I~I.\I._"1If1I~~(,I).~~~~,· . ..- Pump and Flow Data spm DH flow spm Total flow spm AV @ DP pSI AV @ DC Pump 1 Pump 2 Pump 3 Pump Pres 308 288 74 24 hr Avg 55 ftJhr ( 128 unit~ ( ( ftJhr units Deg F ,;~ R.O.P. :,{\. ~~ Gas* ~!; Temp Out .·¡,ü,· 1 Current o o 74 ';<;*,·j:.,;'),';;~*.!Ik';·&i~''\;;;·:·'';¡.i;'''r.'~~'.;''ii,\\:\,~;f~~~'k""~~"~~~"?iIi\~~~I~"~~\~'!I~""è~;~~'~"ii",¡~I}~,*1::il;",""~>(':"~'" 34 5/9/2003 13,981 327 UO BHA #12 Vaughn / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: 'i:¥ spef"""f"""V- sun DRILLING SERVIc::es I .'~..' :>.:!.-~:;;·tJ.~:¥.if;;:~!;~~~.¡;~~*~~~¿:::~.~:),~:~~\~~.$i~:~~~~rW:~~L~,;~~~i~>·?i\~'·;~~:'~?;::~:';;;;~~\~~~~\~~;'·~t:I.~~~~¥tr-~~~;ft&~it·:~~L}'ì.~.'~(~·¡~\:~~:;..i:;.J:i - "i\)~. ~"i,¡'f ':1b~ ~.~~.,,~,:. ~ . I ~. ~..~ .~ ".!~ .,;:~ .~ Pump and Flow Data ~~ Pump 1 spm DH flow gpm .)~ Pump 2 spm Total flow gpm .~ Pump 3 spm A V @ DP fpm ~~. Pump Pres psi A V @ DC fpm I. ~~~:'e~.~'~~~:.~W~"..p~c '~~ Mud Wt Out 9.30 ppg PV 8 cp YI 26 Ibs/100ft2 Gel~ 13 / 17 / 18 Ibsi100ft2 pH 8.5 Sd 0 % g --- ,~~ ..' ...."':".: ....>" """:M~_-:;·;",,::·~·:,\""-""'-~~,,¡:1.·ot·¿;:~t:';''''~:''';'¡''¡:·i,I!I:'!'~I,o;~),. ilte~LHMt~I'M!.'!'diØ\ill'I:~~::f4r.{·.!:!'.'t:\ :...,... ': ¡. .f'¡.'''::-~:.'': '~-"'''''''~''.~(. :,..§.p>, ''''~J. " ~ ~~~~ml~=~~o .~~=~::XI-=_~~:!.J Trip Depth: 13975 ft Trip Gas: 653 Mud Cut: ppg Trip CI: 18000 ppm ~I Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm' ïight Spots: to to to Feet of Fill on Bottom: ft . '~~::X[:'M:::I,U'::::r._ ![.-r':::;;£~:.I::J __ ¡IJlYJ·~1ml1lfr spe.....r-y-sun Customer: Well: Area: Lease: Rig: Job No.: DRILLING SERVIces Mudlogger's Morning Report "\'}:'; ,:'·d~·~'·'.:.:~-'·~)'··.· ...'~...... BP Alaska NorthStar NS 23 North Slope NorthStar NS 23 Nabors 33E AK AM 0002371818 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 35 5/10/2003 13,981 o circulating Vaughn / Clump : ~:~~":".!);.~~ ~.,'" ·.~,.-",';I'i~;::,·,,~,,·.:·"\~lI~:~:'¡'''\Io:>!,;.¡,,_.\tI'I.;'::j?Õ:,,_. ·i:;"è:..:<o::,~.\..,J. ~·,~,"!;.i¿~'-"~.~M":.: '.....:'.:-:;...,,"..~...:::.. ;' ';, ". 24 hour accumulation of Steel Filings from Possum Belly Magnets: :1 Description of fillings: Scale and slivers " ' .' (i;..:, .·..¡;~!1.~·*)xif.·~~<i;:,\·)r~ti"~_~fAt~~:t;,~.v~Jj'lUm>1l·lif~w~..(¡$~à'n~\':'#'Æ.I~~~Y~'t.'1f ,r: 24 hr Reci Continue to lay down BHA #12. rig up 4.5 liner, run liner and inner string.Circulate one liner volume. .1 RIH with liner on 4" drill pipe. Switch to 5" drill pipe.filling every10 stands. Circulate one drill string vloume at 7' .~ shoe, Continue to RIH going to bottom, No Problems, Currently staging up circulation. Gas is 525 Units 'I :J Logging Engineer: Doug Wilson / Mark Lindloff :1' ". :~'ì:;;i~iN.J.~:&1~;'ir ~"'I.~": . 1...,'~,.1f~~( '.~. . ~.~ ~ 1 Current o o 86 o o 86 24 hr Avg o ft/hr ( o unit~ ( ( R.O,P, ft/hr units Deg F Gas· Temp Out I I I ppg ppg ppg 1 I Current Lithology: 10 % L -1\CC,w_IIm/Ot!t.Ln- ~ r SST 40 I i H 1]l1D I um 1 ft ft ft units units units Depth Drill Rate during ~ j I before I to to to to -1J~:5i!'~ li jlLJ~. ,0, ~;., . ~.~_.._ - ,,_, " 24 hr Max ft/hr @ units @ deg F @ o o o % - 'm Jl:mJ::1::: " % %LCM IIIIII~IIII~',="" ft units ppg ft units ppg ft units ppg SH 50 % CONG , .l.:::J.:.~:!:]I.J ~I Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg Drilling Breaks after Gas during after % Lithology Sst Sltst Cgl before I ~.¡ :g-;l-..rt'i."¡"~·]I·'tr~::":::¡·· . .. ~t:ß!J.."", ~,.. .. J.. ,. " \u.,; . * 10000 units = 100% Gas In Air ~ . I; r".., ;;¡. ~... ' I .,'r h'~ Schlumberger 1 Job # 40008877 Customer BP AOW Well NS231 Field Northstar Rig Nabors 33E AFE # NSO-831306 DD's Levad / Tunnell Co. Rep. Polya / Holt I PDM Run # 1 PDM Ser# 962-3573 PDM Size 9 5/8 Mud Type Spud BHT F Description I Item R/S 3/4 Stages 4.5 Rev/Gal 0.221 Mud Wt 9 Mud Vis 150 Vendor Date In 01-Apr-03 Time In 23:00 Depth In 201 TVD In 201 Drlg Hrs 0.3 Slide Hrs 0.0 Rot Hrs 0.3 Pump Hrs 0.8 PDM Jet Blk Bearing Mud Rubber RM 1000 Sand % tr Solids % 3.6 00' ID I ' Bit#1 MX-C1 Hughes 6005654 TFA=1.031 2 9 5/8 Std POM 1.83° Ana 962-3573 1 *Float 3 Orienting Sub Ana STORS-HA-105 4 NM STAB Ana N MSZSS-HA-009 5 MONEL LC Ana I 6 MONEL LC Ana 7 NM STAB Ana 1 8 X-OVER Ana I 1 1 I 16 BHA# Date Out 02-Apr-03 Time Out 4:30 Depth Out 330 TVD Out 330 Drlg Ft 129 Slide Ft 0 Rot Ft 129 Rotate % 100 Inclln 0,00 Az In 305.00 InclOut 0.78 Az Out 325.51 Avg Dls 0.5 Max Ds 0.7 RPM 40 GPM 600 DIg TQ 2.5 WOB 12 ~ta~.()9'·"} . F.". BottomCe>rm In/out Top CO.fm 9 5/8 3x20 1x12 Jets Tool 15 7/8 7 15/16 2 1/2 2 13/16 2 7/8 2 7/8 2 7/8 NMLC-10-HA-001 8 1/16 8 NMLC-10-HA-013 8 1/4 NMSZSS-HA-012 8 STXOS-HC-614 7 1/16 x 8 1/E 2 7/8 _.~_._."---~,,-_._-,- BHA and Run Objective Clean out 20" conductor. Drill hole w/ -'~._-----_._----'."'-----'.---_._-----'----- gyro to make room for Bha02. BHA and Run Results I Excellent. 16 16 BHAVieight Dry Wt 11,446 Buoyed Wt 9,877 Incl Angle 38 Buoy+lncl wt 7.783 Bit To IGyro 0&1=43' Why POOH I Comments I ~~'?~_~~.£~~_~~_~~_~____________._____..___________ 1.35 1.35 7 5/8 Reg P 7 5/8 Reg B 26.74 28.09 6 5/8 H90 B 6 5/8 H-90 P 1.47 29.56 6 5/8 H-90 B 6 5/8 H-90 P 4.49 34.05 6 5/8 H-90 B 6 5/8 H-90 P 9.20 43.25 6 5/8 H-90 B 6 5/8 H-90 P 9.96 53.21 6 5/8 H-90 B 6 5/8 H-90 P 5.50 58.71 6 5/8 H-90 B 6 5/8 H-90 P 3.08 61.79 41/21F B 2.18 2.43 2.40 1.28 Bit Data IADC # 117 Footage 129 Hrs 0.3 k Revs 3 k Grade O-O-NO-A-E-I-NO-BHA ':;omment 1 Hole Size 16 Hole Sect Surface Bha Type Steerable Hrs BRT 5,50 Avg ROP 477.78 Slide ROP 0.00 Rot ROP 477.78 Slide % 0 Bit>Srvy 43.00 T/F Corr 0.0 Plan Dls 0.0 SPP On 560 SPP Off 400 Length Cum Length Tool Motor Jars Bit #1 Hrs~ In 0.0 0.0 0.0 Hrs. Out 0.8 0.3 0.3 0.8 · ':r }..1)2 Schlumberger BHA# 2 Job # 40008877 Date In 02-Apr-03 Date Out 04-Apr-03 Hole Size 16 Customer BP ADW Time In 4:30 Time Out 22:00 Hole Sect Surface Well NS231 Depth In 330 Depth Out 3,686 Bha Type Steerable Field Northstar TVD In 330 TVD Out 3,205 Hrs BRT 65.50 Rig Nabors 33E Drlg Hrs 16.8 Drlg Ft 3,356 Avg ROP 199.76 AFE # NSD-831306 Slide Hrs 11.6 Slide Ft 1,709 Slide ROP 147 33 DD's Tunnell / Levad Rot Hrs 5.2 Rot Ft 1,647 RotROP 316,73 1 Co. Rep. POlya / Holt Pump Hrs 28,5 Rotate % 49 Slide % 51 PDM Run # 2 R/S 3/4 PDM Jet Blk Inelln 0.78 Az In 325.51 BiÞSrvy 67,68 PDM Ser# 962-3573 Stages 4.5 Bearing Mud Inel Out 38.96 Az Out 329,23 T/F Corr 87,9 PDM Size 9 5/8 Rev/Gal 0.221 Rubber RM1000 Avg DIs 3.0 Max Ds 6.0 Plan DIs 2.5 1 Mud Type Spud MudWt 9.15 Sand % 1 RPM 40 GPM 930 SPP On 1150 BHT F Mud Vis 97 Solids % 4.8 DIg TQ 4.0 WOB 15 SPP Off 1250 Item Deseript/(Jn Vendor SIN OD ID.., ~tabOD J=~N. Bottom Conn Length .Cum Length I In/Out· Top Conn Bit#1 MX-C1 Hughes 6005654 16 3x20 1x12 1.35 1.35 TFA=1.031 Jets 7 5/8 Reg P 2 9 5/8 Std POM 1.83° Ana 962-3573 9 5/8 Tool 15 7/8 2.18 7 5/8 Reg B 26,74 28.09 I *Float 6 5/8 H90 B 3 MONELLC Ana NMLC-10-HA-001 8 1/16 2 7/8 6 5/8 H-90 P 9.20 37.29 6 5/8 H-90 B I 4 MONELLC Ana NMLC-10-HA-013 8 1/4 2 7/8 6 5/8 H-90 P 9.96 47.25 6 5/8 H-90 B NM STAB Ana NMSZSS-HA-012 8 2 7/8 16 2.40 6 5/8 H-90 P 5.50 52.75 5 1515/16 6 5/8 H-90 B 1 6 MWO Ana 079 7.15/16 Tool 2.28 6 5/8 H-90 P 29.72 82.47 *Filter in Top 6 5/8 H-90 B 7 Orienting Sub Ana STORS-HA-105 7 15/16 2 1/2 6 5/8 H-90 P 1.47 83.94 I *Mule Shoe 6 5/8 H-90 B 8 NM STAB Ana NMSZSS·HA-D09 8 2 13/16 16 2.43 6 5/8 H-90 P 4.49 88.43 15 7/8 6 5/8 H-90 B 9 NMOC Ana NMDC-HA-D17 7 15/16 2 13/16 6 5/8 H-90 P 30.75 119.18 6 5/8 H-90 B 10 NMOC Ana NMDC·HA-018 7 7/8 2 13/16 6 5/8 H-90 P 30.34 149.52 6 5/8 H-90 B I 11 NM STAB Ana NMSZSS-HA-016 8 2 7/8 16 2.40 6 5/8 H-90 P 5.23 154.75 15 7/8 6 5/8 H-90 B NMOC Ana NMDC-HA-021 7 7/8 2 13/16 6 5/8 H-90 P 30.81 185.56 12 6 5/8 H-90 B 13 HYOJARS DAILEY 1417-1121 7 1/2 3 1.55 6 5/8 H90 P 31.26 216.82 6 5/8 H90 B 14 X-OVER Ana STXOS-HC-614 7 1/16 x 8 1/E 2 7/8 1.28 6 5/8 H-90 P 3.08 219.90 4 1/2 IF B 15 26 Jnts HWDP 5" NAD 26HWDP 5 3 4 1/2 IF P 782.37 1002.27 4 1/2 IF B 16 OP 5" to Surface NAD DP 5 4 1/4 4 1/2 IF P 1002.27 4 1/2 IF B BHA and Run Objective Drill to csg pnt. Kick off 2,5/100 to 38 d. _____.__. .,___·_~"_._n_·__·_ BHAWelght Dr¡ Wt 73,839 Buoyed Wt 63,54 7 Incl Angle 38 Buoy+lncl Wt 50,076 ,Sit Data IADC # 117 Footage 3,356 Hrs 16.8 k Revs 220 k Grade 1-1-Wf -A-E-I-PN- TO ~omment 2 Nozzles plugged Tool Motor Jars Bit #1 Hrs.ln 0.8 0.0 0.3 Hrs.Out 29.3 16.8 17.1 28.5 BHA and Run Results I POOH due t~_~~~~~~1 response reorient, sidetrack well, fine from there. Why POOH I Comments I~~~-=~.x0 _o.,~..~~~_~~~r:9_~=-~~_____..._..___ Tool face off by 50° Pull to 457' sidetrack well, red rill 500' to TO Bit To IGR=6~.69, 0&1=67,68, Gyro=98 J I~{ }..¡)~ r 1 1 1 1 I 1 I I 1 I Schlumberger Item 2 RSX238HF+GS Bit #2 TFA=0.941 PO Bias Unit Job # 40008877 Customer BP AOW Well NS231 Field Northstar Rig Nabors 33E AFE # NSO-831306 DD's Tunnell / Levad Co. Rep. Polya / Holt PDM Run # RSS #1 PDM Ser# PDM Size Mud Type Sea-Poly BHT F 151 Description 3 PO Extention Sub 4 Control Collar Control Unit-383 XO FLOAT SUB 5 6 NM STAB 7 COR 8 MWD 9 NM STAB 10 NMDC 11 NMDC 12 NM STAB 13 NMDC 14 HYDJARS 15 X-OVER 16 26 Jnts HWDP 5" 17 Reamer 18 Dart Valve Sub 19 DP 5" to Surface BHA and Run Objective R/S Stages Rev/Gal Mud Wt 10 Mud Vis 50 Vendor Date In 06-Apr-03 Time In 18:30 Depth In 3,686 TVD In 3,205 Drlg Hrs 57,9 Slide Hrs 0.0 Rot Hrs 57,9 Pump Hrs 92.4 PDM Jet Bearing Rubber Sand % 0 Solids % 8.5 OD ID 12 1/4 5x12,4x13 Jets 9 1/4 Tool 9 1/4 Tool 9 3/16 Tool 8 2 13/16 8 2 7/8 8 1/8 Tool 8 Tool 8 2 7/8 7 15/16 2 13/16 7 7/8 2 13/16 8 2 7/8 7 7/8 2 13/16 7 1/2 3 7 1/16 x 8 1/é 2 7/8 5 3 7 3 7/8 6 3/4 3 1/8x4 1/2 5 4 1/4 BHA# Date Out 14-Apr-03 Time Out 23: 30 Depth Out 11,537 TVD Out 9,402 Drlg Ft 7,851 Slide Ft 0 Rot Ft 7,851 Rotate % 100 Inclln 38.96 Az In 329.23 Incl Out 36.86 Az Out 329.79 Avg Dls 0.7 Max Ds 2.2 RPM 150 GPM 950 DIg TQ 28.0 WOS 15 stàbOf) "'F.N. Bottom Conn 11'1. I ôÎ1t Top Conn 12 1/4 1.34 12 1/4 6 5/8 Reg P 6 5/8 Reg B 7 5/8 Reg B 7 5/8 Reg P 7 5/8 Reg P 7 5/8 Reg B 65/8 Reg B 6 5/8 Reg P 6 5/8 H90 B 6 5/8 H-90 P 6 5/8 H-90 B 6 5/8 H-90 P 6 5/8 FH B 6 5/8 FH P 6 5/8 H-90 B 6 5/8 H-90 P 6 5/8 H-90 B 6 5/8 H-90 P 6 5/8 H-90 B 6 5/8 H-90 P 6 5/8 H-90 B 6 5/8 H-90 P 6 5/8 H-90 B 6 5/8 H-90 P 6 5/8 H-90 B 6 5/8 H90 P 6 5/8 H90 B 6 5/8 H-90 P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B Hycalog 203465 Ana 90208 Ana 90178 An a 90055 Ana STFLS-HH-118 Ana NMSZSS-HA-017 Ana 8039 Ana 11664 Ana NMSZSS-HA-002 Ana NMDC-HA-017 Ana NMDC-HA·018 Ana NMSZSS-HA-004 Ana NMDC-HA-021 DAILEY 1417-1121 Ana STXOS-HC-614 NAD 26HWDP WTH 248668 BPX CM7996 NAD DP 2.40 12 2.01 12 15.13 2.11 12 1/4 2.15 12 12 1/4 2.45 11 7/8 1.55 1.28 12 1/4 3 Hole Size 12 1,4 Hole Sect Interm Bha Type RSS Hrs BRT 197.00 Avg ROP 135.60 Slide Rap 0.00 Rot Rap 135,:30 Slide % 0 Bit>Srvy 58,18 T/F Carr n/a Plan Dls 0.0 SPP On 3700 SPP Off 3700 Length Cum Length 1.00 1.00 3.16 4.16 1.28 5.44 9.95 15.39 1.57 16.96 4.85 21.81 22.72 44.53 28.28 72.81 5.19 78.00 30.75 108.75 30.34 139.09 5.58 144.67 30.81 175.48 31.26 206.74 3.08 209.82 782.37 992.19 6.01 998.20 2.37 1000.57 1000.57 BHA and Run Results performed excellent Why POOH I Comments ~.~i~I.~~~~?!~_~~~_~______ BHA Weight' Or¡ Wt 71,050 Dr~~~_~~_-=,_g pnt. RSS.~nd~?_~ging t0o..~___ Buoyed Wt 60,227 Incl Angle 38 ~<?_?,~__f~~_~~.£~!~..~_~od ~_r:.:__.________,_. Buoy+lncl wt 47,460 , Bit Data Tool Hrs~ In lADe # Motor Footage 7,851 Jars 16.8 Hrs 57.9 Bit #2 0.0 k Revs 521 k RSS 0.0 Grade 1-1-WT-T-X-I-NO-TD Hrs. Out 92.4 74.7 57,9 92.4 Bit To Res=27.86', PWD=29.61'"GR=38,86', D&I=58.18' ':::omment /_-:' )-IY': Schlumberger r Job # 40008877 Customer BP ADW Well NS231 Field Northstar Rig Nabors 33E AFE # NSD-831306 DD's Tunnell J Levad Co. Rep. Kidd / Holt PDM Run # n/a PDM Ser# PDM Size Mud Type Sea-Poly BHT F DescriptiolJ 1 Item R/S Stages Rev/Gal Mud Wt 10.2 Mud Vis Vendor Date In 15-Apr-03 Time In 14:00 Depth In 11,537 TVD In 9,402 Drlg Hrs 0.0 Slide Hrs 0.0 Rot Hrs 0.0 Pump Hrs PDM Jet Bearing Rubber Sand % Solids % ID BHA# Date Out 17 -Apr -04 Time Out 15:30 Depth Out 11,537 TVD Out 9,402 Drlg Ft 0 Slide Ft 0 Rot Ft 0 Rotate % 0 Inelln 36.86 Inel Out A vg Dls RPM Dig TQ ,~~~ê¡,eq"., F.N. lilt.Óût r RSX238HF+GS Hycalog 203465 12 1/4 5x12,4x13 Bit #2 TFA=0.941 Jets 2 BIT SUB Ana DFS-AS-802 8 4 7/8 1 *Float 3 24 Jnts HWDP 5" NAD 24HWDP 5 3 4 DP 5" to Surface NAD DP 5 4 1/4 1 1 I BHA and Run Objective Fix top drive. BHA and Run Results Why POOH lComments Bit To I BHAW,ei'ght Dry Wt 36.226 Buoyed Wt 30.598 Incl Angle 38 Buoy+lncl Wt 24.111 Move pipe out of derrek. run to shoe. -.-,,---.--.. ---~---_._-_._._--_..__._...._-------_._.,-'"--- I ~_~~_9_~~~_~~_~~_____,_"_____,,____ . --.-.------.-..-.-.-.-----.-...--. ..- .-..._--_._----_.-.._~---_._--~..- --~-.....-.--,--..- .._.~- Az In 329.79 Az Out Max Ds GPM WOB Bottom Conn r;~p Conn 6 5/8 Reg P 1.20 6 5/8 Reg B 41/21FB 4 112 IF P 4 1/2 IF B 41/21FP 4 1/2 IF B Bit Data. IADC # Footage 0 Hrs 0.0 k Revs Grade 80mment 4 Hole Size 12 1.4 Hole Seet Interm Bha Type Kill String Hrs BRT 8,833.50 Avg ROP 0,00 Slide ROP 0,00 Rot ROP 0,00 Slide % 100 Bit>Srvy T/F Corr Plan Dls SPP On SPP Off . Length Cum Length 1.00 1.00 2.28 3.28 721.90 725.18 725.18 Tool Motor Jars Bit #2 Hrs. In Hrs. Out 74.7 57,9 74.7 57.9 ,·'r "\~~ Schlumberger BHA# 6 Job # 40008877 Date In 21-Apr-03 Date Out 25-Apr-03 Hole Size 9 Customer BP ADW Time In 12:30 Time Out 19:30 Hole Sect Intermediate Well NS231 Depth In 11.537 Depth Out 13.461 Bha Type RSS Field Northstar TVD In 9.402 TVD Out 10,982 Hrs BRT 103.00 Rig Nabors 33E Drlg Hrs 38.0 Drlg Ft 1.924 Avg ROP 50.63 AFE # NSD-831306 Slide Hrs 0.0 Slide Ft 0 Slide ROP 0.00 OD's Levad / j. bossel Rinke Rot Hrs 38.0 Rot Ft 1,924 Rot ROP 50.63 Co. Rep. Dinger / Holt I Polya Pump Hrs 71.0 Rotate % 1 00 Slide % 0 PDM Run # RSS #2 R/S PDM Jet Inclln 36.86 Az In 329.79 Bit>Srvy 75.71 PDM Ser# Stages Bearing InclOut 27.92 Az Out 332.00 T/F Corr n/a PDM Size Rev/Gal Rubber Avg Dls 1.0 Max Ds 2.2 Plan Dls 1.0 1 Mud Type Sea-Poly Mud Wt 12.6 Sand % 0 RPM 120 GPM 610 SPP On 3750 BHT F 180 Mud Vis 50 Solids % 16.9 DIg TQ 26.0 WOB 18 SPP Off 3750 Item Description Vendor OD ID ~t~Þ9P F.N. Bottom Conn Length Cum Length I JnLOut Top Conn Bit#3 DS70FNPV Hycalog 200976 8 1/2 4X13,2x12 0.85 0.85 TFA=0.739 Jets 4 1/2 Reg P 2 PO Bias Unit Ana PU-AA-00357 6 3/4 Tool 8 1/2 2.10 4 1/2 Reg B 3.41 4.26 1 *Float 4 1/2 IF B 3 Control Collar Ana 631-CC-60100V 6 13/16 Tool 4 1/2 IF B 9.77 14.03 CU-123 4 1/2 IF B 4 XO Float Sub Ana STFLS-FA-504 6 7/8 3 1/2 41/21FP 1.63 15.66 1 *Float 4 1/2 XH B 5 NM STABILIZER Ana NMSlSS-F A-004 6 3/4 2 13/16 8 3/8 2.42 4 1/2 XH P 5.70 21.36 8 3/8 4 1/2 XH B I 6 NM LEAD Ana NMLC-FA-10-004 6 3/4 2 3/4 4 1/2 XH P 9.80 31.16 41/2XH B 7 XO Ana STXOS-FE-1042 6 5/8 2 3/4 4 1/2 XH P 1.98 33.14 4 1/2 IF B I 8 NBR Reamer Security 912501 6 3/4 2 3/4 9 1.24 4 1/2 IF P 3.89 37.03 4 112 IF B 9 XO Ana GLDD361 6 1/4 3 4 1/2 IF P 1.58 38.61 1 4 1/2 XH B 10 CDR Ana 7077 6 3/4 Tool 15.12 4 1/2 XH P 22.83 61.44 5 1/2 FH B 11 MWD Ana 799 6 7/8 Tool 2.17 5 1/2 FH P 28.33 89.77 *Filter 4 1/2 XH B 12 NM STABILIZER Ana NMSZSS-FA-017 6 3/4 2 3/4 8 3/8 2.39 4 1/2 XH P 5.64 95.41 8 1/4 4 1/2 XH B I 13 NM Flex DC Ana NMFC-FA-027 6 3/4 2 13/16 4 1/2 XH P 31.02 126.43 4 1/2 XH B 14 NM Flex DC Ana NMFC-FA-016 6 3/4 2 13/16 4 1/2 XH P 30.89 157.32 4 1/2 XH B 15 NM Flex DC Ana NMFC·FA-025 6 5/8 2 13/16 4 1/2 XH P 30.99 188.31 4 1/2 XH B 16 XO Ana STXOS-FE-066 6 1/2 2 7/8 41/2XH P 2.18 190.49 4 1/2 IF B 17 HYDJARS DAILEY 1416-1573 6 1/2 2 3/4 1.69 4 1/2 IF P 32.63 223.12 4 1/2 IF B 18 14 Jnts HWOP 5" NAD 14HWDP 5 3 4 1/2 IF P 420.15 643.27 4 1/2 IF B 19 Dart Valve Sub BPX CM7996 6 3/4 3 1/8x4 1/2 4 1/2 IF P 2.37 645.64 4 1/2 IF B 20 DP 5" to Surface NAD OP 5 4 1/4 4 1/2 IF P 645.64 4 1/2 IF B BHA and Run Objective Directional drill to 7" liner point. BHA Weight Bit Data ,Tool Hrs. In Hrs. Out .~-~.._---"-,_.._----- 71.0 RSS to steer well path as per plan. Re-run bit. Dry Wt 40,236 IADC # Motor BHA and Run Results 14 ~~mands sent ~~_~~~cepted by Buoyed Wt 32,513 Footage 1,924 Jars 24,5 62.5 tool downhole. Maximum build DLS capability approx. 1.5°/100ft. /ncl Angle 38 Hrs 38.0 Bit #3 35,8 73,8 Why POOH / Commepts 1 T otal d:E.~~f?.r_~9~~_ section. P~~ial __,_____ Buoy+/ncl Wt 25,621 k Revs 274 k RSS 0.0 71.0 lost circulation at TO. Grade 2-1-BT-C-X-I-ER-TD ·Blt To I GR=55.87'. Res=44.87', PWD=46.62', D&I=75.71' f::omment Re-run, in grade: 1-0-BT-C-X-I-ER-TD .r~r }..I)~ Schlumberger BHA# 12 Job # 4.0008877 Date In 07 -May-03 Date Out 10-May-03 Hole Size 6 Customer BP AOW Time In 20:00 Time Out 2:00 Hole Sect Production Well NS231 Depth In 13,461 Depth Out 13,981 Bha Type Rotar¡ Field Northstar TVDln 10.982 TVD Out 11,332 Hrs BRT 54.00 Rig Nabors 33E Drlg Hrs 19.1 Drlg Ft 520 Avg ROP 27.23 AFE # NSO-831306 Slide Hrs 2.5 Slide Ft 50 Slide ROP 20.00 DD's Rinke Rot Hrs 16,6 Rot Ft 470 Rot ROP 28.3" f Co. Rep. Vaughn / Clump Pump Hrs 31.4 Rotate % 90 Slide % 10 PDM Run # 2 R/S 7/8 PDM Jet 8 Incl In 27.92 Az In 327.01 Bit>Srvy 85,85 PDM Ser# 475-14022 Stages 2.0 Bearing aSB Incl Out 28.17 Az Out 326.96 T/F Corr 308,8 PDM Size 4 3/4 Rev/Gal 0,330 Rubber RM1000 Avg Dls 1.7 Max Ds 3.5 Plan Dls 0.0 Mud Type Oril-N Mud Wt 9,3 Sand % 0 RPM 80 GPM 320 SPP On 1900 BHT F 155 Mud Vis 45 Solids % 5.5 Dig TQ 15.0 WOB 25 SPP Off 1800 Item Description Vendor OD,·' ID Sta~'C)p" . 'li·N· BottomCoìm Length Cum Length 1 In/Out Top COnfl Bit#6 EP4970 HTC 5010808 6 3x15 0.75 0,75 TFA=O,S16 Jets 3 1/2 Reg P 2 :. 3/4 POM SSS 1,15' Ana 475-14022 4 3/4 Tool 5 7/8 3 1/2 Reg B 22.88 23.63 I 5 7/8 3 1/2 IF B 3 FLOAT SUB Ana GLDD 276 4 5/8 2 1/4 3 112 IF P 1,60 25.23 "'Float 3 1/2 IF B 4 NM IB Stab Ana NMSZISB-EA-810 4 3/4 2 1/4 6 2.15 3 1/2 IF P 4.87 30.10 I 5 15/16 3 1/2 IF B AON4 Ana 74 4 3/4 Tool S 3/4 2.13 3 1/2 IF P 27.13 57.23 5 5 3/4 3 1/2 IF B 1 6 ARCS Ana 61 4 3/4 Tool 1.24 3 1/2 IF P 22.30 79.53 3 1/2 IF B 7 MWO-Slimpulse Ana 4845 4 13/16 Tool 1.18 3 1/2 IF P 33.40 112.93 3 1/2 IF B 1 8 NM IB Stab Ana NMSZIBS-EA 806 4 3/4 2 1/4 6 2.10 3 1/2 IF P 4.89 117.82 515/16 3 1/2 IF B 9 NMDC Ana NMDC-EA-001 4 3/4 2 1/4 3 1/2 IF P 31.02 148.84 I 3 1/2 IF B 10 NMDC Ana NMDC-EA-004 4 3/4 2 1/4 3 1/2 IF P 31.04 179.88 3 1/2 IF B 11 PBL Sub (2-Port) Jeatherfo NOR475PBL 18 4 3/4 2 1/4 3 1/2 IF B 8.11 187.99 3 1/2 IF P 12 HYOJAR DAILEY 1400-1380 5 1/4 2 1/4 1.85 3 1/2 IF P 29.86 217.85 HT40 1 13 6 Jts HWDP NAD 4" HWDP 4 2 11/16 HT 40 P 184.21 402.06 HT 40 B 14 81 Jts. DP 4" NAD 81 DP 4 4 3 5/16 HT 40 P 2541.50 2943.56 HT 40 B 15 xa NAD 400008C 6 1/4 2 5/8 HT 40 P 1.88 2945.44 4 1/2 IF B 16 Dart Valve Sub BPX CM7996 6 3/4 3 1/8x4 1/2 4 1/2 IF P 2.37 2947,81 4 1/2 IF B 17 OP 5" to Surface NAD DP 5 4 1/4 4 1/2 IF P 2947.81 4 1/2 IF B BHA and Run Objective Drill to TO while mantaining an angle above 20 degrees BHA and Run Results IVery good:g_~~!_lide of 50 ft, was_____ enough to keep angle above 28 degrees Why POOH / Comments I ~_~a~~=9.u~"n~~~~_!!='________.__.__,_____ as per geology Bit To I Oens=36.79', Nuet=39.54', Res=62.41', GR=67.33', 0&1=85.85', GR=88.85' BHA Weight Dry Wt 45,717 Buoyed Wt 39,241 Incl Angle 28 Buoy+lncl wt 34,648 Bit Data Tool Hrs.ln' IADC # Motor 0.0 Footage 520 Jars 0.0 Hrs 19.1 Bit #6 0.0 k Revs 201 k PBL 0.0 Grade 8-4-BT-G-E-1/16-WT-TO 80mment Hrs. out 31.4 19.1 19.1 31.4 - - Customer: BP EXPLORATION ALASKA inch at sperry-sun Well: NS23 inch at Area: BEAUFORT SEA,ALASKA inch at Lease: NORTHST AR 7" inch at DRILLING SERVICES Rig: NABORS DRLG RIG 33E 4 1/2" inch at Mud Company: BAROID inch at Bit Record Job No.: AK-AM 0002371818 ---------""'....-- - ----------'IfIiíI - --.- --- BHA# Bit Bit Serial Size TFA Depth Depth Feet Hours ROP RPM KREV Slide No. Type Number In Out ftlhr % GRADE 1 1 MX-C1 6005654 16 1.031 201 330 129 0.3 478 40 3K 0 O-O-NO-A-E-I-NO-BHA 2 RR1 MX-C1 6005654 16 1.031 330 3686 3356 16.8 200 40 220K 51 1-1-WT -A-E-I-PN- TO 3 2 RSX238HF+GS 203465 12.25 0.941 3686 11537 7851 57.9 136 150 521K RSS 1-1-WT - T -X-I-NO- TO 6 3 OS70FNPV 200976 8.5 0.739 11537 13461 1924 38.0 50.6 120 274K RSS 1-0-BT -C-X-I-ER- TO 12 6 EP4970 5010808 6.0 .516 13461 13981 520 19.1 27 80 201K 10 8-4-BT -G-E-1/16-WF- TO - ,....-- -- - - - - - Customer: BP ALASKA Casing Program 20" inch at 201 ft sperry-sun Well: NORTHSTAR NS23 13.375" inch at 3665 ft AÆa: BEAUFORTSEA,ALASKA 9.625" inch at 11516 ft Lease: NORTHST AR 7" inch at 13434 ft DRILLING SERVICES Rig: NABORS DRILLING RIG 33E 4.5" inch at 13980 ft Mud Company: BAROID DRILLING FLUIDS inch at ft Waterbase Mud Record Job No.: AK-AM 0002371818 Depth MW Vis PV YP Gels Fltr HTHP Cake Sol Oil Water Sd CEC pH Pm I Pf / Mf Chlorides Calcium Comments Date ft Ibfgal see LB/100 10S/10M ml/30 ml@deg F 32's % % % % mgeJhg ppm ppm U4IU<l:/UJ <l:U1 9.1 15U <1:<1: 5ts 1 6/<l:6/J 1 11.5 :III: 5.U U.5 94.:1 U 1.5 9.<1: U.15 U.U5/1.<l:U <I::lUUU 1<1:UU ~pua U4/U3/UJ 999 9.1 9<1: <l:U 41 141<1:U/<l:5 1<1:.6 <I: 5.4 U.U 94.6 1.5 6.U 9.( U.JU U.15/U.9U <I:<I:UUU 9tsU ....UUH . 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Generated 7/18/2003 3:18 PM Page 1 of 4 \\\NS23 working file Version DO 3.1RT (do31rt_399) 3.1RT Service Pack 2.03 I bp .. Schlumberger 0 ' ' 1 NS23 working file Survey ReJ.lu Report Date: May 10, 2003 Survey f DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 332.320° I Field: Northstar Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure / Slot: Northstar PF I NS23 TVD Reference Datum: KB 1 Well: NS23 TVD Reference Elevation: 56.5 ft relative to MSL Borehole: NS23 Sea Bed / Ground Level Elevation: 15.670 ft relative to MSL I UWlfAPI#: 50-029-23146-00 Magnetic Declination: 26.007° Survey Name f Date: NS23 working file I April 1 , 2003 Total Field Strength: 57553.241 nT I Tort I AHO I 0011 ERO ..do' 172.941' /7727.13 ft /6.213/ 0.676 Magnetic Dip: 80.953° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: April 01, 2003 Location LatfLong: N 70 29 28.863, W 148 41 35.938 Magnetic Declination Model: BGGM 2002 I Location Grid N/E Y/X: N 6031041.560 ftUS, E 659826.260 ftUS North Reference: True North I Grid Co,..",,,,, An91" +1.23169248' Total Corr Mag North .> True North: +26.00r Grid Scale Factor: 0.99992902 Local Coordinates Referenced To: Well Head I Measured Inclination Azimuth TVD Vertical NS EW Course DLS Tool Face Walk Rate Build Rate Comments I Depth Section Length (ft ) (deg) (deg) (ft ) ( ft ) (ft ) ( ft ) (ft ) ( deg/100 ft ) (deg) ( deg/100 ft ) ( deg/100 ft ) 0.00 0.00 305.00 0.00 0.00 0.00 0.00 0.00 0.00 -15.59M 0.00 0.00 Tie-In 50.00 0.34 344.41 50.00 0.15 0.14 -0.04 50.00 0.68 -72.99M 0.00 0.68 Gyro 100.00 0.38 287.01 100.00 0.41 0.33 -0.24 50.00 0.70 -53.54M -114.80 0.08 Gyro 163.00 0.50 306.46 163.00 0.80 0.56 -0.66 63.00 0.30 -54.95M 30.87 0.19 Gyro 200.00 0,71 305.05 199.99 1.15 0.79 -0.98 37.00 0.57 -34.49M -3,81 0.57 Gyro 284.00 0.78 325.51 283.99 2.18 1.56 -1.73 84.00 0.33 -88.03M 24.36 0.08 Gyro I 356.00 1.11 271.97 355.98 3.01 1.98 -2.70 72.00 1.25 -76.26M -74.36 0.46 Gyro 447.00 1.99 283.74 446.95 4.49 2.39 -5.12 91.00 1.02 -46.75M 12.93 0.97 Gyro 539.80 1,76 313.25 539.70 6.91 3.75 -7.72 92.80 1.06 -42.55M 31.80 -0.25 Gyro 630.80 3.88 317.45 630.58 11.20 6.98 -10.82 91.00 2.34 -42.66M 4.62 2.33 Gyro I 720.00 5.48 317.34 719.48 18.24 12.33 -15.75 89.20 1.79 1.27G -0.12 1.79 Gyro 811.00 6.82 317.59 809.96 27.66 19.52 -22.34 91.00 1.47 O.OOG 0.27 1.47 Gyro 901.00 11.13 317.65 898.83 41.24 29.89 -31.80 90.00 4.79 -2.71G 0.07 4.79 Gyro I 991.00 13.09 317.24 986.83 59.48 43.79 -44.57 90.00 2.18 11.52G -0.46 2.18 Gyro 1081.00 16.23 319.52 1073.89 81.59 60.84 -59.66 90.00 3.55 15.21G 2.53 3.49 Gyro 1183.80 21.16 323.20 1171.24 113.94 86.64 -80.11 102.80 4.93 15.34G 3.58 4.80 Gyro 1278.80 24,21 325.23 1258.88 150.21 116.38 -101.50 95.00 3.31 177.09G 2.14 3.21 Gyro I 1307.06 23.97 325.26 1284.68 161.66 125.86 -108.07 28.26 0.85 -48.69G 0.11 -0.85 MWD+IFR+GMAG 1403.57 25.31 321.80 1372.40 201.40 158.18 -132.00 96.51 2.04 69.40G -3.59 1.39 MWD+IFR+GMAG 1495.22 26.83 329.53 1454.75 241.33 191.42 -154.61 91.65 4.06 29.15G 8.43 1.66 MWD+IFR+GMAG 1592.97 32.13 334.96 1539.83 289.38 234.02 -176,82 97.75 6.07 78.88G 5.55 5.42 MWD+IFR+GMAG 1658.90 32.32 336.66 1595.60 324.47 266.09 -191.23 65.93 1.40 12.13G 2.58 0.29 MWD+IFR+GMAG 1754.80 36.67 338.22 1674.62 378.54 316.24 -212.02 95.90 4.63 147.64G 1.63 4.54 Gyro 1851.80 36.15 338.78 1752.69 435.78 369.81 -233.12 97.00 0.64 170.28G 0.58 -0.54 Gyro I 1946.80 33.21 339.70 1830.80 489.44 420.34 -252.29 95.00 3.14 -48.09G 0.97 -3.09 Gyro 2069.02 38.01 331.54 1930.20 560.34 484.89 -281.87 122.22 5.52 94.03G -6.68 3.93 Gyro 2164.34 37.94 333.55 2005.34 618.98 536.93 -308.91 95.32 1.30 166.36G 2.11 -0.07 MWD+IFR+GMAG 2257.32 35.08 334.76 2080.06 674.27 586.70 -333.04 92.98 3.17 -143.08G 1.30 -3.08 MWD+IFR+GMAG r 2352.81 33.56 332.67 2158.93 728.08 634.98 -356.86 95.49 2.01 -19.88G -2.19 -1.59 MWD+IFR+GMAG 2448.22 35.19 331.65 2237.67 781.95 682.60 -382,03 95.41 1.81 15,77G -1.07 1,71 MWD+IFR+GMAG 2541.77 38.39 333.10 2312.58 837.96 732.24 -407.98 93.55 3.54 148.68G 1.55 3.42 MWD+IFR+GMAG 2636.42 36.61 334.93 2387.67 895.55 784.02 -433.23 94.65 2.22 -22.68G 1.93 -1.88 MWD+IFR+GMAG 2730.85 37.16 334.55 2463.20 952.17 835.28 -457.42 94.43 0.63 -7.83G -0.40 0.58 MWD+IFR+GMAG 2824.48 39.04 334.14 2536.88 1009.91 887.35 -482.44 93.63 2.03 -111.12G -0.44 2.01 MWD+IFR+GMAG 2918.72 38.41 331.38 2610.41 1068.85 939.76 -509.41 94.24 1.95 -44.30G -2.93 -0.67 MWD+IFR+GMAG r 3012.90 39.80 329.29 2683.49 1128.21 991.37 -538.82 94.18 2.03 112.23G -2.22 1.48 MWD+IFR+GMAG 3106.17 39.64 329.91 2755.23 1187.74 1042.77 -568.98 93.27 0.46 164.28G 0.66 -0.17 MWD+IFR+GMAG 3200.46 37.75 330.78 2828.82 1246.65 1093.99 -598.15 94.29 2.09 -26.59G 0.92 -2.00 MWD+IFR+GMAG 3293.01 39.74 329.23 2901.00 1304.52 1144.14 -627.12 92.55 2.39 144.98G -1.67 2.15 MWD+IFR+GMAG 3387.80 38.36 330.80 2974.62 1364.18 1195.86 -656.97 94.79 1.79 -36.33G 1.66 -1.46 MWD+IFR+GMAG Generated 7/18/2003 3:18 PM Page 2 of 4 \\\NS23 working file Version DO 3.1RT (do31rt_399) 3.1RT Service Pack 2.03 I Measured Inclination Azimuth TVD Vertical NS EW Course DLS Tool Face Walk Rate Build Rate Comments Depth Section Length I (ft ) (deg) (deg) (ft ) (ft ) (ft ) (ft ) (ft) ( deg/1 00 ft ) (deg) ( deg/100 ft ) ( deg/100 ft ) 1 3482.44 40.01 328.93 3047.97 1423.92 1247.56 -687.00 94.64 2,14 135.19G -1.98 1.74 MWD+IFR+GMAG 3573.58 39.62 329.54 3117.98 1482.19 1297.70 -716.85 91,14 0.61 -163.56G 0.67 -0.43 MWD+IFR+GMAG 3615.61 38.96 329.23 3150.51 1508.77 1320.60 -730.41 42.03 1,64 -171.69G -0,74 -1.57 MWD+IFR+GMAG 3772,62 37,95 328.99 3273.46 1606.26 1404.40 -780.54 157.01 0.65 -48.87G -0.15 -0.64 MWD+IFR+GMAG 1 3866,38 38.02 328.86 3347.36 1663,86 1453.82 -810.32 93.76 0.11 -36.75G -0,14 0.07 MWD+IFR+GMAG 3961.11 38.59 328.18 3421.70 1722.45 1503.90 -840.98 94.73 0.75 -45.72G -0.72 0.60 MWD+IFR+GMAG 4055.86 38.86 327.74 3495.62 1781.55 1554,14 -872.43 94.75 0.41 16.37G -0.46 0.28 MWD+IFR+GMAG 4150.97 39.01 327,81 3569.60 1841.13 1604.71 -904.30 95.11 0.16 140.64G 0.07 0.16 MWD+IFR+GMAG 1 4245.25 38,88 327.98 3642.93 1900.22 1654.90 -935.80 94.28 0,18 -174.94G 0.18 -0.14 MWD+IFR+GMAG 4339.10 38.32 327.90 3716.27 1958.60 1704.53 -966.88 93.85 0.60 141.63G -0.09 -0.60 MWD+IFR+GMAG 4434.82 37.75 328.64 3791.66 2017.43 1754.69 -997,90 95,72 0.76 158.29G 0,77 -0.60 MWD+IFR+GMAG I 4527.81 37.46 328.83 3865.33 2074.06 1803.19 -1027.35 92.99 0.34 79.50G 0.20 -0,31 MWD+IFR+GMAG 4622.19 37.50 329.18 3940.23 2131.39 1852.42 -1056.92 94.38 0.23 116.57G 0.37 0.04 MWD+IFR+GMAG 4716.51 37.29 329.88 4015.17 2188.61 1901.79 -1085.97 94.32 0.50 135.75G 0.74 -0.22 MWD+IFR+GMAG 4810,74 37.16 330.09 4090.20 2245.56 1951.15 -1114.48 94.23 0.19 43.79G 0.22 -0.14 MWD+IFR+GMAG I 4905.84 37.53 330.67 4165.80 2303.22 2001.30 -1142.99 95.10 0.54 -8.67G 0.61 0.39 MWD+IFR+GMAG 5000.34 37.57 330.66 4240.72 2360.79 2051.50 -1171.21 94.50 0.04 80.77G -0.01 0.04 MWD+IFR+GMAG 5095.59 37.59 330.86 4316.21 2418.86 2102.19 -1199.58 95.25 0.13 119.43G 0.21 0.02 MWD+IFR+GMAG 5188.81 37.20 332.02 4390.27 2475.46 2151.91 -1226.65 93.22 0.86 121.03G 1.24 -0.42 MWD+IFR+GMAG 5283.04 37.07 332.38 4465.39 2532.35 2202.23 -1253.18 94.23 0.27 120.99G 0.38 -0.14 MWD+IFR+GMAG 5376.77 36.75 333.28 4540.34 2588.63 2252.31 -1278.89 93.73 0.67 -167.98G 0.96 -0.34 MWD+IFR+GMAG 5471.98 36.61 333.23 4616.69 2645.50 2303.10 -1304.48 95.21 0.15 75.75G -0.05 -0.15 MWD+IFR+GMAG I 5565.75 36.81 334.50 4691.87 2701.53 2353.42 -1329.17 93.77 0.84 54.88G 1.35 0.21 MWD+IFR+GMAG 5659,64 36.95 334.83 4766.97 2757.83 2404,35 -1353.28 93.89 0.26 66.89G 0.35 0.15 MWD+IFR+GMAG 5752.36 37.25 335.97 4840.92 2813.67 2455.20 -1376.56 92.72 0.81 51.34G 1.23 0.32 MWD+IFR+GMAG 5846.72 37.84 337.16 4915.74 2871.01 2507.96 -1399.42 94.36 0.99 50.67G 1.26 0.63 MWD+IFR+GMAG I 5941.12 38.14 337.75 4990.14 2928.89 2561.62 -1421.70 94.40 0.50 35.4 7G 0.63 0.32 MWD+IFR+GMAG 6035.48 38.49 338.15 5064.17 2987.10 2615.84 -1443.66 94.36 0.45 46,75G 0.42 0.37 MWD+IFR+GMAG 6129.60 38.96 338.94 5137.60 3045.64 2670.64 -1465.20 94.12 0.72 57.94G 0.84 0.50 MWD+IFR+GMAG 6223.38 39.28 339.74 5210.36 3104.36 2726.01 -1486.07 93.78 0.64 -32.54G 0.85 0.34 MWD+IFR+GMAG I 6315.90 39.58 339.44 5281.82 3162.65 2781.08 -1506.56 92.52 0.38 -65.03G -0.32 0,32 MWD+IFR+GMAG 6410.34 39.97 338.16 5354.41 3222.68 2837.41 -1528.42 94.44 0.96 -68.74G -1.36 0.41 MWD+IFR+GMAG 6504.07 40.14 337.49 5426.15 3282.72 2893.26 -1551.18 93.73 0.49 -89.49G -0.71 0.18 MWD+IFR+GMAG 1 6597.68 40.15 336.49 5497.71 3342.87 2948.81 -1574.77 93.61 0.69 -87.84G -1.07 0.01 MWD+IFR+GMAG 6692.18 40.20 334.89 5569.92 3403.73 3004.37 -1599.87 94.50 1.09 -92.71G -1.69 0.05 MWD+IFR+GMAG 6786,59 40.17 333.71 5642.04 3464.61 3059.26 -1626.29 94.41 0.81 -85.63G -1.25 -0.03 MWD+IFR+GMAG 6879.92 40.26 332.11 5713.31 3524.86 3112.90 -1653.73 93.33 1.11 -83.03G -1.71 0.10 MWD+IFR+GMAG 1 6973.89 40.41 330.38 5784.95 3585.67 3166.22 -1682.98 93.97 1.20 -98.80G -1.84 0.16 MWD+IFR+GMAG 7066.85 40.26 328.77 5855.81 3645.76 3218.10 -1713.45 92.96 1.13 -113.43G -1.73 -0.16 MWD+IFR+GMAG 7160.17 39.78 326.99 5927.28 3705.59 3268.92 -1745.35 93.32 1.33 -133.81G -1.91 -0.51 MWD+IFR+GMAG 7255.06 39.09 325.84 6000.57 3765.54 3319.13 -1778.69 94.89 1.06 -128.28G -1.21 -0.73 MWD+IFR+GMAG 7349.43 38.22 324.03 6074.26 3823.99 3367.38 -1812.54 94.37 1.51 -154.81G -1.92 -0.92 MWD+IFR+GMAG 7443.21 37.56 323.52 6148.27 3880.95 3413.84 -1846.58 93.78 0.78 159.27G -0.54 -0.70 MWD+IFR+GMAG 7536.61 36.91 323.93 6222.64 3936.83 3459.41 -1880.02 93.40 0,74 176.37G 0.44 -0.70 MWD+IFR+GMAG 7631.80 36,35 323.99 6299.03 3993.02 3505.33 -1913.43 95.19 0.59 153.60G 0.06 -0.59 MWD+IFR+GMAG 7724.64 35.96 324.32 6373.99 4047.23 3549.73 -1945.51 92.84 0.47 57.94G 0.36 -0.42 MWD+IFR+GMAG 7818.66 36.56 325.90 6449.80 4102.40 3595.34 -1977.31 94.02 1.18 63.00G 1.68 0.64 MWD+IFR+GMAG 7912.45 37.02 327.37 6524.91 4158.29 3642.25 -2008.19 93.79 1.06 78.39G 1.57 0.49 MWD+IFR+GMAG 8006.83 37.30 329.47 6600.13 4215.16 3690.81 -2038.04 94.38 1.38 81.03G 2.23 0.30 MWD+IFR+GMAG 8100.94 37.49 331.30 6674.90 4272.27 3740.50 -2066.28 94.11 1.20 87.56G 1.94 0.20 MWD+IFR+GMAG 8193.53 37.54 332.84 6748.34 4328.65 3790.31 -2092.69 92.59 1.01 110.12G 1.66 0.05 MWD+IFR+GMAG 8288.15 37.32 333.85 6823.48 4386.15 3841,71 -2118.49 94,62 0,69 15.14G 1.07 -0.23 MWD+IFR+GMAG 8383.43 37.50 333.93 6899.16 4444.01 3893.68 -2143.96 95.28 0.20 148.75G 0.08 0.19 MWD+IFR+GMAG 8476.99 37.38 334.05 6973.45 4500.87 3944.80 -2168.91 93.56 0.15 -164.12G 0.13 -0.13 MWD+IFR+GMAG 8567.58 37.21 333.97 7045.52 4555.74 3994.14 -2192.96 90.59 0.20 104.71G -0.09 -0.19 MWD+IFR+GMAG Generated 7/18/2003 3:18 PM Page 3 of 4 \\\NS23 working file Version DO 3.1 RT ( do31 rt_399 ) 3.1 RT Service Pack 2.03 I Measured Inclination Azimuth TVD Vertical NS EW Course DLS Tool Face Walk Rate Build Rate Comments Depth Section Length I ( ft) (deg) (deg) ( ft ) (ft ) (ft ) (ft ) (ft ) ( deg/100 ft ) (deg) ( deg/100 ft ) ( deg/1 00 ft ) 8614.41 37.18 334.16 7082,82 4584.03 4019.60 -2205.34 46.83 0.25 -147.21G 0.41 -0.06 MWD+IFR+GMAG I 8708.73 36.91 333.87 7158.10 4640.83 4070.68 -2230.24 94.32 0.34 163.01G -0.31 -0.29 MWD+IFR+GMAG 8804.85 36.54 334.06 7235.14 4698,28 4122.32 -2255.46 96.12 0.40 -150.42G 0.20 -0.38 MWD+IFR+GMAG 8900.67 36.29 333.82 7312,25 4755.14 4173.42 -2280.45 95,82 0.30 66.12G -0,25 -0.26 MWD+IFR+GMAG 8994.55 36.34 334.01 7387.90 4810,72 4223.35 -2304.90 93.88 0.13 144.63G 0,20 0.05 MWD+IFR+GMAG I 9091.45 36.29 334.07 7465.98 4868.08 4274.95 -2330.02 96.90 0.06 -41.75G 0.06 -0.05 MWD+IFR+GMAG 9184.51 36.45 333.83 7540.91 4923.24 4324.53 -2354.25 93.06 0.23 110,79G -0,26 0,17 MWD+IFR+GMAG 9278,81 36.02 335,83 7616.98 4978,92 4374,97 -2377.96 94.30 1.33 120.90G 2.12 -0.46 MWD+IFR+GMAG 9373.86 34.63 340.14 7694.54 5033.58 4425.88 -2398.59 95.05 3.00 122.89G 4.53 -1.46 MWD+IFR+GMAG 9467.04 33.84 342,39 7771,58 5085.36 4475.51 -2415.43 93.18 1.60 7.60G 2.41 -0.85 MWD+IFR+GMAG 9563,28 34.39 342.52 7851.25 5138.50 4526.98 -2431.70 96.24 0.58 -17.45G 0,14 0.57 MWD+IFR+GMAG 9658.44 34,90 342.24 7929,54 5191.76 4578,54 -2448.08 95.16 0.56 -29.35G -0.29 0,54 MWD+IFR+GMAG I 9751.48 35.97 341.22 8005,35 5244.98 4629.76 -2464.99 93.04 1.31 -42.00G -1.10 1.15 MWD+IFR+GMAG 9847.52 37.15 339.48 8082.49 5301.62 4683.62 -2484.24 96.04 1.64 -10.27G -1.81 1.23 MWD+IFR+GMAG 9943.01 38.49 339.09 8157.92 5359.74 4738.39 -2504.95 95.49 1.43 -21.97G -0.41 1.40 MWD+IFR+GMAG r 10038.87 39,81 338,26 8232.26 5419,89 4794.76 -2526.97 95.86 1.48 -65.82G -0.87 1.38 MWD+IFR+GMAG 10136.81 40.77 335.13 8306.97 5483.02 4852.90 -2552.03 97.94 2.29 -70.11G -3.20 0.98 MWD+IFR+GMAG 10229.56 41.34 332.84 8376.92 5543.90 4907.64 -2578.75 92.75 1.73 -87.77G -2.47 0.61 MWD+IFR+GMAG 10324.06 41.40 331.05 8447.84 5606.35 4962.75 -2608.13 94.50 1.25 -159.27G -1.89 0.06 MWD+IFR+GMAG 10417.80 40.95 330.79 8518.39 5668.05 5016.68 -2638.12 93,74 0.51 -178.05G -0.28 -0.48 MWD+IFR+GMAG 10517.24 40.19 330.75 8593.93 5732.70 5073.12 -2669.70 99.44 0.76 -135.74G -0.04 -0.76 MWD+IFR+GMAG 10612.44 39.72 330.03 8666.91 5793.80 5126.27 -2699.91 95.20 0.69 -161.77G -0.76 -0.49 MWD+IFR+GMAG 10708.27 39.45 329.89 8740.76 5854.81 5179.14 -2730.48 95.83 0.30 -176.69G -0.15 -0.28 MWD+IFR+GMAG I 10803.92 38.48 329.80 8815.13 5914.90 5231 .15 -2760.69 95.65 1.02 179.16G -0.09 -1.01 MWD+IFR+GMAG 10897.91 37.65 329.82 8889,13 5972.80 5281.24 -2789.83 93.99 0.88 180.00G 0.02 -0.88 MWD+IFR+GMAG 10993.54 36.75 329.82 8965.30 6030.56 5331.22 -2818.90 95.63 0.94 -160.82G 0.00 -0.94 MWD+IFR+GMAG 11089.04 36.09 329.43 9042.15 6087.19 5380.13 -2847.57 95.50 0.73 -21.57G -0.41 -0.69 MWD+IFR+GMAG ( 11184.68 36.36 329.25 9119.30 6143.64 5428.75 -2876,39 95.64 0.30 -77.56G -0.19 0.28 MWD+IFR+GMAG 11279.19 36.48 328.36 9195.35 6199.64 5476.75 -2905.45 94.51 0.57 -117.57G -0.94 0.13 MWD+IFR+GMAG 11371.99 36.29 327.74 9270.06 6254.54 5523.46 -2934.58 92.80 0.45 30.57G -0.67 -0.20 MWD+IFR+GMAG 1 11475.34 36.86 328.30 9353.06 6315.95 5575.69 -2967.19 103.35 0.64 -63.33G 0.54 0.55 MWD+IFR+GMAG 11571.05 37.04 327.71 9429.55 6373.32 5624.49 -2997.68 95.71 0.42 174.24G -0.62 0.19 MWD+IFR+GMAG 11666.79 34.94 328.08 9507.01 6429.41 5672.14 -3027.58 95.74 2.21 -146.00G 0.39 -2.19 MWD+IFR+GMAG 11762.12 34.00 326.94 9585.60 6483.17 5717.65 -3056.56 95.33 1.20 34.20G -1.20 -0.99 MWD+IFR+GMAG ( 11855.78 34.51 327.55 9663.01 6535.68 5761.99 -3085.08 93.66 0.66 60.92G 0.65 0.54 MWD+IFR+GMAG 11948.71 35.26 329.82 9739.25 6588.71 5807,39 -3112.69 92.93 1.61 68.11 G 2.44 0.81 MWD+IFR+GMAG 12043.47 36.03 332.91 9816.26 6643.91 5855.85 -3139.13 94.76 2.07 45.00G 3.26 0.81 MWD+IFR+GMAG 12138.96 36.81 334.20 9893.10 6700.59 5906.61 -3164.37 95.49 1.14 42.76G 1.35 0.82 MWD+IFR+GMAG 1 12230.27 37.54 335.30 9965.85 6755.71 5956.51 -3187.90 91.31 1.08 47.08G 1.20 0.80 MWD+IFR+GMAG 12325.75 37.89 335.91 10041.38 6814.02 6009.71 -3212.03 95.48 0.54 139.70G 0.64 0.37 MWD+IFR+GMAG 12418.29 37.61 336.30 10114.55 6870.55 6061.50 -3234.98 92.54 0.40 143.90G 0.42 -0.30 MWD+IFR+GMAG 12511.11 37.46 336.48 10188.16 6926.96 6113.32 -3257.62 92.82 0.20 171.39G 0.19 -0.16 MWD+IFR+GMAG 12607.09 37.42 336.49 10264.37 6985.16 6166.82 -3280.90 95.98 0.04 -156.76G 0.01 -0.04 MWD+IFR+GMAG 12698.95 37.00 336.19 10337.53 7040.57 6217.71 -3303.20 91.86 0.50 -154.67G -0.33 -0.46 MWD+IFR+GMAG 12793.14 36.35 335.67 10413.07 7096.71 6269.07 -3326.14 94.19 0.76 -159,17G -0.55 -0,69 MWD+IFR+GMAG 12887.72 34.58 334.48 10490.10 7151.52 6318.84 -3349.25 94.58 2.01 -153.82G -1.26 -1.87 MWD+IFR+GMAG 12981.30 33.29 333.32 10567.74 7203.74 6365.75 -3372.23 93.58 1.54 -141.09G -1.24 -1.38 MWD+IFR+GMAG 13075.47 32.42 332.00 10646.85 7254.82 6411.14 -3395.68 94.17 1.20 -157.89G -1.40 -0.92 MWD+IFR+GMAG 13170.35 30,86 330.76 10727.62 7304.59 6454.83 -3419.51 94.88 1.78 -151.16G -1.31 -1.64 MWD+IFR+GMAG 13264.11 29.24 328.92 10808.78 7351.49 6495.43 -3443.08 93.76 1.99 -146.14G -1.96 -1.73 MWD+IFR+GMAG 13357.79 27.92 327.01 10891.04 7396.17 6533.42 -3466.84 93.68 1.71 10.25G -2.04 -1.41 MWD+IFR+GMAG 13484.58 28.80 327.34 11002.62 7456.15 6584.03 -3499.48 126.79 0.70 -15.43G 0.26 0.69 MWD+IFR+GMAG 13577.95 32.02 325.67 11083.13 7503.16 6623.42 -3525.58 93.37 3,57 173.72G -1.79 3.45 MWD+IFR+GMAG 13675.87 30.28 326.05 11166.93 7553.49 6665.34 -3554.01 97.92 1.79 -141.01G 0.39 -1.78 MWD+IFR+GMAG 13771.45 29.27 324.36 11249.89 7600.58 6704.32 -3581.09 95.58 1.37 129.25G -1.77 -1.06 MWD+I FR+GMAG 13865.11 28.56 326.21 11331.88 7645.52 6741.53 -3606.88 93.66 1.22 -169.71G 1.98 -0,76 MWD+IFR+GMAG Generated 7/18/2003 3:18 PM Page 4 of 4 (deg/100 ft) (deg/100 ft) -0,57 -1.48 MWD+IFR+GMAG 0.00 0,00 Projected survey to TO Comments (deg) 180.00G O.OOG Tool Face Walk Rate Build Rate \\\NS23 working file Version DO 3.1 RT ( d031 rt_399 ) 3.1 RT Service Pack 2.03 I [ 1 1 [ I EOU Freq Survey Tool Type Act-Stns SLB_UNKNOWN (default tool used) Act-Stns SLB_FREE GYRO Act-Stns SLB_MWD+GMAG Act-Stns SLB_FREE GYRO Act-Stns SLB_MWD+GMAG MD To ( ft ) 0.00 1278.80 1658.90 2069.02 13981.00 Survey Error Model: SLB ISCWSA 3-D 95.00% Confidence 2.7955 sigma Surveyinq Proq: MD From ( ft ) 0.00 0.00 1278,80 1658.90 2069.02 I Survey Type: Definitive Survey I I Measured Inclination Azimuth TVD Vertical NS EW Course DLS Depth Section Length I (ft ) (deg) (deg) (ft ) (ft ) (ft) (ft) (ft ) (deg/100 ft) 13891.46 28,17 326.06 11355.06 7657,97 6751.93 -3613.86 26.35 1.50 13981,00 28,17 326,06 11434,00 7699,98 6787.00 -3637.46 89.54 0,00 - - - -- - - - NS23 - Spud 04/02/03 Prognosed Tops Actual Depths Formation TVDss I TVDrkb I MDrkb TVDss I TVDrkb I MDrkb Top Permafrost 1140 1196 1210 Base Permafrost 1468 1524 1575 SV6 - top confming zone 3010 3066 3506 Surface casing point 3,144 3200 3667 3150 3206 3686 SV5 - base confining zone 3268 3324 3838 SV4 3588 3644 4247 SV2 - top upper injection zone 3980 4036 4743 SV1 - top major shale barrier 4374 4430 5239 TMBK - top lower injection zone - Top Ugnu 4728 4784 5682 WSl - top Schrader Bluff - Base Ugnu 6327 6383 7737 CM3 - Base lower injection zone (top Colville) 6929 6985 8492 THRZ - Top HRZ 8730 8786 10767 BHRZ - Base HRZ 8794 8850 10849 Top Kuparuk 8834 8890 10899 Kuparuk C 8972 9028 11072 Top Miluveach 9306 9362 11488 Intermediate casing point 9,480 9536 11695 9346 9402 11537 Intermediate logging point 9,480 9536 11695 Two failed attempts Top Kingak 9833 9889 12135 Top Sag River 10906 10962 13438 Geol target #1 10906 10962 13438 Intermediate casing point 10,874 10930 13418 10926 10982 13461 Top Shublik - 90 11004 11060 13552 Top Ivishak 11093 11149 13657 Oil - Water contact Total Depth 11378 11434 13981 - - Formation Logs