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200-115
7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By: Date: APPROVED BY THE AOGCCCOMMISSIONER PBU S-101 Acid Stimulation Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 200-115 50-029-22968-00-00 ADL 0028257, 0028258 11721 Conductor Surface Intermediate Production Scab Liner / Liner 6753 81 3987 8831 3726 9090 20" 10-3/4" 7" 4-1/2" 6819 28 - 109 27 - 4014 24 - 8880 7995 - 11721 2000 28 - 109 27 - 3393 24 - 6773 6313 - 6753 None 470 2480 5410 7500 9090 1490 5210 7240 8430 8850 - 11699 4-1/2" 12.6# L80 22 - 79746760 - 6750 Structural 4-1/2" HES TNT Packer No SSSV Installed 7840, 6194 Date: Torin Roschinger Operations Manager Hunter Gates hunter.gates@hilcorp.com (907) 777-8326 PRUDHOE BAY 11/4/2025 Current Pools: AURORA OIL Proposed Pools: AURORA OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 1:54 pm, Oct 20, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.10.20 13:05:23 - 08'00' Torin Roschinger (4662) 325-652 SFD 10/23/2025 10-404 J.Lau 10/23/25 DSR-10/30/25 CDW 10/20/2025 10/31/25 Acid Stimulation Well: S-101 PTD: 200-115 API: 50-029-22968-00 Well Name:S-101 Permit to Drill:200-115 Current Status:Operable, WAG API Number:50-029-22968-00 Estimated Start Date:11/14/2025 Estimated Duration:1 day Regulatory Contact:Abbie Barker Service Lines:FB First Call Engineer:Hunter Gates (215) 498-7274 (M)(907) 777-8326 (O) Second Call Engineer:Tyson Shriver (406) 690-6385 (M) Current Bottom Hole Pressure:3,776 psi at 6,700 TVDss Maximum Potential Surface Pressure:2,000 psi Last SI WHP:1040 psi August 10 th, 2025 Min ID:3.725 @ 7,941 MD R-Nipple Max Angle:78 deg @ 9,000 MD Last Tag:9,090 ELM (set CIBP) Brief Well Summary: S-101 is an operable Kuparuk injector that supports S-44 and S-125. In February of 2025, we elected to set a CIBP to isolate the lower perfs within the slotted liner because we believed the MI utility to S-44 had matured and wanted to support the C2 sand for S-125s production as best as we could. When the toe perfs were open, we were injecting about 6 MMCFD of MI, and now we are only injecting 500-600 MCFD. The idea here is to perform a fullbore acid job to improve injectivity in the Kuparuk C2. Current Status: Active Operable WAG Injector Objective: Fullbore acid stimulation to improve injectivity in the current Kuparuk perforations. Acid treatment targets: Type Top Bottom Net perf Footage Perforated Liner 8,8508,960110 Total 110 Procedure: DHD 1. TIFL. Fullbore 1. MIRU LRS pump truck and SLB acid transport. a. Ensure a shower trailer is on location and properly functioning prior to opening the well and pumping any fluids. b. Please have SLB test the load water to confirm iron content is <100 ppm and all water is filtered to 5 microns. c. Order out brine between 100 120 deg F. d. No sludge emulsion testing is required. e. Verify acid strength via titration testing prior to leaving SLB yard. f. Document all test results on load out sheets and have present at the wellsite. Acid Stimulation Well: S-101 PTD: 200-115 API: 50-029-22968-00 g. Ensure wing valve is shut prior to bringing pumps online. May be a good idea to have WPO isolate the flowline via the lateral valve or inlet valve at the manifold as well. 2. Begin job as designed in the schedule below: a. Displace acid down tubing and flush away into perfs. b. Well is an injector so no flowback will be required and acid is fine to be pushed away near wellbore. 3. Pump 5 bbl 50/50 meth/water spear. 4. Swap to pumping 40 bbls of hot diesel. 5. Swap to 1% KCl for fluid pack/pre-flush. 6. Obtain injectivity test w/ 1% KCl working up to max rate on pump truck if pressure will allow. Pump 1x WBV w/ 1% KCl (136 bbls). 7. Swap to 15% HCl and pump 66 bbls of acid. 8. Swap to 1% KCl and pump 136 bbls for overflush displacing acid into formation. Obtain injectivity rate when acid is cleared. 9. Have operations put well on injection immediately. No need for freeze protect. FB HCl Acid Pump Schedule Stage Description Step Fluid Type Volume (bbls) Cum. Volume (bbls) Pump Rate (bpm) WHP Pressure (psi) Comment 50/50 Spear 1 50/50 MEOH/H2O 5 5 Max 2000 See details above Diesel Perf Wash 2 Diesel 40 45 Max 2000 Clean up perfs Fluid pack/Pre- flush/Injectivity Test 3 1% KCl 136 181 Max 2000 Well was on MI HCl Stage 4 15% HCl 66 247 Max 1580 See details above Overflush 5 1% KCl 136 383 Max 1580 See details above Displacement / Injectivity Test 6 1% KCl 10 393 Max 1580 See details above Attachments: Current Wellbore Schematic Sundry Change Form Acid Stimulation Well: S-101 PTD: 200-115 API: 50-029-22968-00 Current Wellbore Schematic: Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: October 20, 2025Subject: Changes to Approved Sundry Procedure for Well S-101Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) first call engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHNS PreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU S-101 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 200-115 50-029-22968-00-00 11721 Conductor Surface Intermediate Production Scab Liner / Liner 6753 81 3987 8831 3726 9090 20" 10-3/4" 7" 4-1/2" 6819 28 - 109 27 - 4014 24 - 8880 7995 - 11721 28 - 109 27 - 3393 24 - 6773 6313 - 6753 None 470 2480 5410 7500 9090 1490 5210 7240 8430 8850 - 11700 4-1/2" 12.6# L80 22 - 7974 6760 - 6752 Structural 4-1/2" HES TNT Packer 7840 6194 Torin Roschinger Operations Manager Hunter Gates hunter.gates@hilcorp.com (907) 777-8326 PRUDHOE BAY, AURORA OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028257, 0028258 22 - 6297 N/A N/A 2190 2378 50 25 699 900 N/A 13b. Pools active after work:AURORA OIL No SSSV Installed 7840, 6194 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Gavin Gluyas at 2:39 pm, Feb 20, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.02.20 14:17:55 - 09'00' Torin Roschinger (4662) DSR-2/20/25JJL 2/27/25 RBDMS JSB 060325 ACTIVITY DATE SUMMARY 2/8/2025 T/I/O= 618/0/49 LRS Unit 76 Assist E-Line (PROFILE MODIFICATION) Heat 200 BBLS Seawater to 120* in Upright Tank. Pumped 3 BBLS 60/40 to freeze protect water line. Pumped 78 BBLS seawater down the TBG as directed by E-Line to pump them down the TBG to set a plug. Pumped 2 BBLS 60/40 followed by 38 BBLS Crude to Freeze Protect the TBG. FWHP's 1790/0/18 Freeze Protect tag hung on WV. T/I/O= 2007/418/121 Pumped 117 BBLS Seawater down S-120 injector to empty upright tank. FWHP's 2086/438/116 DSO notified of well status upon LRS departure. Injection well is online. 2/8/2025 *** WELL INJECTING WATER ON ARRIVAL *** (SET CIBP W/ PUMPDOWN ASSIST) PAD OP SI INJ LINE AND LRS FP INJ LINE. RU ELINE, FUNCTION WLV AND PT 300/3000 PSI CORRELATED TO: SCHLUMBERGER GR/CCL 29 MARCH 2001 SET YJ 3.5" OD CIBP AT 9090 FT, CCL - PLUG 15.0', CCL STOP 9075.0' USED PUMPDOWN ASSIST TO GET TO TARGET DEPTH. 5 BPM AT 300 PSI. WELL PRESSURES UP AFTER SETTING CIBP, PUMP FREEZE PROTECT AT 1650 PSI, 0.5 BPM. RDMO YJT ELINE *** WELL SI ON DEPARTURE, 38 BBL FP IN TUBING *** Daily Report of Well Operations PBU S-101 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, March 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-101 PRUDHOE BAY UN AURO S-101 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/17/2023 S-101 50-029-22968-00-00 200-115-0 G SPT 6194 2001150 1548 2079 2085 2080 2075 27 40 45 46 4YRTST P Guy Cook 2/4/2023 Testing done with a Little Red pump truck and calibrated gauges. 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:PRUDHOE BAY UN AURO S-101 Inspection Date: Tubing OA Packer Depth 12 2819 2741 2727IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230204054322 BBL Pumped:2 BBL Returned:1.8 Friday, March 17, 2023 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Re gg DATE: Tuesday, February 12, 2019 7 j P.I. Supervisor �`Y� 2{i5 1 tq1 SUBJECT: Mechanical Integrity Tests ll BP EXPLORATION (ALASKA) INC. 5-101 FROM: Lou Laubenstein PRUDHOE BAY UN AURO 5-101 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Sup - NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN AURO 5-101 API Well Number 50-029-22968-00-00 Inspector Name: Lou Laubenstein Insp Num: mitLOL190203160359 Permit Number: 200-115-0 Inspection Date: 2/3/2019 - Rel Insp Num: BBL Pumped: BBL 14turned: 1 TOA 1 les 448 451 448 inte vral 4� M ST P/F I P ✓�-- - — — , Notes: Tuesday, February 12, 2019 Page 1 of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min _r Well 5-101 -T)'pC Inj 1�' TVD bloc Tubing 1924 - 1974 1974 197 PTD 2001150 Tvne Toct SPI TPC[ nci L Is I A 41 2906 ' 2769 9759 BBL Pumped: BBL 14turned: 1 TOA 1 les 448 451 448 inte vral 4� M ST P/F I P ✓�-- - — — , Notes: Tuesday, February 12, 2019 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg7�p-L`� 3k -h DATE: Tuesday, March 5, 2019 SUBJECT: Mechanical Integrity Tests P.I. Supervisor (i BP EXPLORATION (ALASKA) INC. 5-101 FROM: Lou Laubenstein PRUDHOE BAY UN AURO 5-101 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Supry i NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN AURO 5-101 API Well Number 50-029-22968-00-00 Inspector Name: Lou Laubenstein Insp Num: mitLOL190203160359 Permit Number: 200-115-0 Inspection Date: 2/2/2019 Rel Insp Num: Packer Depth Pretest Initial I5 Min 30 Min d5 Min 60 Min Well S -un - Type Inj W jTVD 6194 Tubing a74 - ie74 1974 - 1974 PTD 2001150 Type Test SPT �iTest psi 1548 IA 1.11 '606 -69 BBL Pumped: 1 > BBL Returned: 1 OA 10 1 I -151 - 118 Interval 4YRIS] _ _ 1�P/F P .� Notes: Tuesday, March 5, 2019 Page I of I • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIIIntegrityCoordinator@bp.com> Sent: Tuesday, February 16, 2016 5:16 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD 5;Zoesch, Eric; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA) Subject: OPERABLE:Injector S-101 (PTD#2001150) Stable Pressure Trends Indicate NO TxIA All, Injector S-101 (PTD#2001150) has been monitored and has shown no indication of tubing by inner annulus communication.The anomaly observed earlier is suspected to be a result of thermally sensitive fluid packed annuli. At this time, the well has been reclassified as Operable and may remain online as needed. Please call with any questions. Thank you, Laurie Climer SCANNED MA 1 9 010 (Filling in for Whitney Pettus) BP Alaska-Well Integrity rity Coordinator GWuOgn,vatousn WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Friday, January 22, 2016 11:05 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, S GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Zoesch, Eric; 'chris.wallace@alaska.go ' Cc: AK, D&C Well Integrity Coordinator; A &C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Subject: UNDER EVALUATION: Injector S-101 (PTD #2001150) Possible Inner by Outer Annulus Communication All, Injector S-101 (PTD#2001150) is showing anomalous inner annulus pressure trends while on water injection. The well has been reclassified as Under Evaluation for additional diagnostics. 1 • • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, January 22, 2016 11:05 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Welipad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD 5;Zoesch, Eric; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Morrison, Spencer; Sayers,Jessica; Dickerman, Eric; Regg, James B (DOA) Subject: UNDER EVALUATION:Injector S-101 (PTD#2001150) Possible Inner by Outer Annulus Communication Attachments: Injector S-101 (PTD # 2001150) TIO and Injection Plot.docx All, Injector 5-101 (PTD#2001150) is showing anomalous inner annulus pressure trends while on water injection. The well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: 1. Downhole Diagnostics: MIT-IA to 2500 psi 2. Downhole Diagnostics: Monitor pressures for 7 to 10 days 3. Well Integrity Engineer: Additional diagnostics as needed A copy of the TIO and injection plot has been included for reference. Please call with any comments or concerns. Thank you, Whitney Pettus �n (Alternate:Kevin Parks) SCANNED MAY 2 6 2016 BP Alaska-Well Integrity Coordinator G <, WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinatorPBP.com From: AK, D&C Well Integrity Coordinator Sent: Saturday, November 14,--2(Z.5 9:07 AM To: AK, OPS GC2 OSM; AK, OPS GCZfield O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK,D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr„ PB East Wells Opt Engr; AK, OPS WELL PAD S; Zoesch, Eric; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, &C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B 1 • • Injector S-101 (PTD#2001150) TIO Plot January 22, 2016 90211 5.101 000C OC( 1004 .-.'_'_.�.__ 1 _ 102295 1'2.9 15 11.0515 1101195 1,1915 1016.95 120391 1110,5 129195 1225'15 113115 01.01'0 -- Injection Plot into-sin 3 500 164/. W 1 300 3289 6f.1.1,697' 3 300 3100 0000 1504 900 2800 600. 200 2400 1.1W. 2.500 5100 1.200 2 300 2200 1.100 2.100 — —MI 1.000 1 9002' 00 --SW 1 tont _SMj 500 1700 _4 500 Z _� Sao 4400` 01 1 405 300 1700 3 890 1.00 0a0 S00 900 500 700 500 600200 400 300 00 10021'15 162315 110915 0172115 1,1915 101615 12675 1241015 101705 12124/15 12/21+15 0191101 0511016 01421,16 ', tint._tint_ tint.tint. _tint tint tint tint tint _.. tint.tint tint tint _tint. tint.. tint tint. tint.. , • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, November 14, 2015 9:07 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S;Zoesch, Eric;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers,Jessica; Dickerman, Eric; Regg, James B (DOA) Subject: OPERABLE:Injector S-101 (PTD #2001150) No signs of Inner annulus x Outer annulus communication Attachments: Injector S-101 (PTD #2001150) TIO Plot.docx All, Injector S-101 (PTD#2001150)was showing possible signs of inner by outer annulus communication while on water injection. The inner annulus pressure was increased with gas to maintain a differential pressure between the inner and outer annulus. The annulus was monitored for 5 days showing no signs of communication. The well is reclassified as Operable. A copy of the TIO plot is included for reference. Thank you, Kevin Parks CApto MAY 1 1 61 (Alternate: Whitney Pettit' BP Alaska-Well Integrity Coordinator G'IVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, November 05, 2015 9:29 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Zoesch, Eric Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric Subject: UNDER EVALUATION: Injector S-101 (PTD #2001150) Possible Inner by Outer Annulus Communication All, Injector S-101 (PTD#2001150) is showing possible signs of inner by outer annulus communication while on water injection. The well has been reclassified as Under Evaluation for further diagnostics. Plan Forward: 1 • • • Injector S-101 (PTD#2001150)TIO Plot ti 06 • :9x15 96211, .2.15 411,05 001 le P9'1915 vSY s 14.+6.15 19111 ML1 11£116 11'111 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,February 12,2015 TO: Jim Regg rpr �Zv`IS P.I.Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC S-101 FROM: Jeff Jones PRUDHOE BAY UN AURO S-101 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry_J NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN AURO S-101 API Well Number 50-029-22968-00-00 Inspector Name: Jeff Jones Permit Number: 200-115-0 Inspection Date: 2/10/2015 Insp Num: mitJJ150210170606 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-101 Type Inj W -TVD 6194 Tubing 1153.' 1154 - 1152 - 1153 - i PTD 2001150 Type Test SPT Test psi 1548 IA 1206 1 2514 - 2506 - 2505 - Interval INITAL P/F P - OA 334 423 . 422 - 420 Notes: 0.7 BBLS methanol pumped I well inspected,no exceptions noted. / SCANNED ;:A:; Thursday,February 12,2015 Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, February 11, 2015 10:18 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS WELL PAD S;Wallace, Chris D (DOA);Zoesch, Eric Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer; Regg,James B (DOA);AK, OPS FF Well Ops Comp Rep Subject: OPERABLE:Injector 5-101 (PTD#2001150)AOGCC Witnessed- MIT-IA Passed Attachments: image001.png All, Injector S-101 (PTD#2001150) passed an AOGCC witnessed MITIA on 02/10/2015. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. Please call with any questions. Thank you, Kevin Parks SEED I'll ,h' 1W `i _ ihlJ tE LLQ„ a' C1; BP Alaska-Well Integrity Coordinator GVVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com From: , •&C Well Integrity Coordinator Sent: Thursda , -•ruary 05, 2015 8:38 AM To: AK, OPS GC2 OS ; • OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D: ireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES =: ast Wells Opt Engr; AK, OPS WELL PAD S; 'chris.wallace@alaska.gov'; Zoesch, Eric Cc: AK, D&C DHD Well Integrity Engineer; AK, D& -II Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; 'jim.regg@alaska.gov'; AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION: Injector S-101 (PTD #2001151 • Workover Complete- MIT-IA Passed All, Injector 5-101 (PTD#2001150) underwent a rig workover completed on 10/22/2014.The worko,; replaced the tubing and repaired a production casing leak. A MIT-IA and a MIT-T passed on 10/22/2014. The passing tests firm two competent barriers in the wellbore. The well is reclassified as Under Evaluation and may be placed on Inject'. • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, February 05, 2015 8:38 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS WELL PAD S;Wallace, Chris D (DOA);Zoesch, Eric Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer; Regg, James B (DOA);AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION:Injector S-101 (PTD#2001150) Rig Workover Complete- MIT-IA Passed Attachments: image001.png All, Injector S-101 (PTD#2001150) underwent a rig workover completed on 10/22/2014.The workover replaced the tubing and repaired a production casing leak. A MIT-IA and a MIT-T passed on 10/22/2014. The passing tests confirm two competent barriers in the wellbore. The well is reclassified as Under Evaluation and may be placed on Injection. Plan forward: 1. Operations: Put well on injection 2. DHD: AOGCC MIT-IA when well is stable Please use caution while placing the well online due to fluid packed annuli and the potential for annular fluid expansion. Kevin Parks (Alternate Laurie Climes) BP Alaska-Well Integrity Coordinator GVV Global Wells Organization ` '''scow ' Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com 1 OF T� • • • P w �7, THE STATE Oil and Gas s Alaska ALASKAConservation Commission T-M GOVERNOR SEAN PARNELL 333 West Seventh Avenue p Q. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1 433 Fax: 907.276.7542 David Bjork SCANNED i1;1 v Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 a00 _ ti �- Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Aurora Oil Pool, PBU S-101 Sundry Number: 313-492 Dear Mr. Bjork: 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, Cathy P. oerster Chair, Commissioner DATED this 25 day of September, 2013. Encl. • STATE OF ALASKA • V"" , ECEIVED by R . ALASKA OIL AND GAS CONSERVATION COMMISSION�� $SEp 12 2013 APPLICATION FOR SUNDRY APPROVAL K3 f S 2s t 20 AAC 25.280 AOG�C 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 Suspended Well ❑Stimulate ❑Alter Casing ❑Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. 200-115 • 3. Address: 0 Exploratory 0 Stratigraphic ❑Development ®Service • 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-22968-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? S-101 - Will planned perforations require a Spacing Exception? ❑Yes No 9. Property Designatior , 10.Field/Pool(s): Or( AJS c-+ /z.- j 3 ADL 028258&028257. Prudhoe Bay/Aurora Pool(Uefrrilsd)__, 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11721' • 6753' • 11699' 6752' 7900',8300' None Casing Length Size MD ND Burst Collapse Structural Conductor 81' 20" 28'- 109' 28'- 109' 1490 470 Surface 3987' 10-3/4" 27'-4014' _ 27'-3393' 5210 2480 Intermediate 8856' 7" 24'-8880' 24'-6773' 7240 5410 Production Liner 3012' 4-1/2" 8709'- 11721' 6700'-6753' 8430 7500 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8850'-8960'/Slotted:9535-11699' 6760'-6799'1 Slotted:6780'-6752' Kill String:4-1/2", 12.6# L-80 7867' Packers and SSSV Type: 7"Baker ZXP Packer Packers and SSSV 8709'/6700' MD(ft)and ND(ft): 12. Attachments: 13.Well Class after proposed work: ®Description Summary of Proposal ®BOP Sketch ❑Detailed Operations Program ❑Exploratory ❑Stratigraphic ❑Development ®Service ' 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: October 15,2013 ❑Oil ❑WINJ ❑WDSPL ❑Plugged 16. Verbal Approval: Date ❑Gas ❑GINJ ❑GSTOR ❑Abandoned Commission Representative: . ®WAG ❑SPLUG ❑Suspended 17. I hereby certify that the foregoing is true and correct to the best of n>(knowledge. Contact: Sean McLaughlin,564-4387 Printed Name: David Bjork Title:/Engineering Team Leader Email: Sean.McLaughlin @bp.com Signature: Phone: 564-5683 Date: c /`j,r91/3 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �/ b - { li a ❑Plug Integrity >✓J BOP Test ❑Mechanical Integrity Test ❑Location Clearance Other: �t Sol° trot f 60 2 r fin �d 44 I T ,-A ref i, rrd Gc fi--t r 5-1i �.-, I1 S a_tC IA/ / r55 _( t��1��lKI cc �Gart ),___ Spacing Exception Required? ❑Yes E No Subsequent Form Required: Jr s.o4 RBD'1I . OCT 1 0 2 � ` Approved By: �; APPROVED BY COMMISSIONER THE COMMISSION Date: 2S---/-3 Form 10-403 Revised /2012�/ Approved application isOlimiarNrgkr the date of approval �ub� In Duplicate �� �I � 3 UKV HL j'-' cz/ A • • otZ %it S-101 i Expense Rig Workover _ Revision 1 Well Objective: Perform a rig work over to repair production casing leak at 8,115' and 2,000' ✓ Well History: Well S-101 was drilled into the Kuparuk reservoir in 2000 as a horizontal injector. The well was drilled to support the S-100 producer. The well only supports the producer S-100 and engulfs the largest subsurface acreage in the Aurora horizon. The well failed a MITIA test in March of 2011 and the well was shut in. An acoustic LDL was run in April of 2012 and confirmed a PC leak @ 8,115' MD. The primary objective of this well is to reestablish well integrity to the wellbore to support the S-100 producer. Doyon 16 rigged up on S-101 in July 2013. The tubing and packer were recovered. A run was made to dress the tie back sleeve. The run to test casing found a leak at the 7" casing at 2200'. 9 9 A USIT and caliper log was run to gather information for repair options. The caliper confirmed a leak at a 7" port collar. A decision was made to secure the well while a plan is developed to repair the casing. Two RBP's were set and a kill string will be run. A 7" Weatherford MetalSkin casing p atch will be used to repair the leaking port collar. ✓ MASP: 2630 psi Well TypeTector Estimated Start Date: October 15th, 2013 Intervention Engineer:Sean McLaughlin 564-4387 Pad Engineer: Mackie Derrick 564-5891 Pre-Rig Work Request: V 1 Prep annular valves, Set a BPV in the tubing hanger. O 2 Remove the well house &flow line. Level the pad as needed for the rig. Proposed Procedure 1. MIRU. Pull BPV. Circulate 9.5 ppg brine. Install TWC. Nipple down tree and adapter flange. 2. NU 4 preventer BOP consisting of annular, 2-7/8" x 5" VBR's, blind shear rams, flow cross and 2-7/8" x 5" VBRs. Pressure test BOPE to 4,000psi high /250psi low. Test the annular to 3,500 psi. 3. Pull and lay down 4-1/2" 12.6# L-80 TC-II kill string. 4. Run RTTS to 2230' and test casing to 4000 psi. 5. Pull both deep set RBP's 6. Run 4-1/2" L-80 TC-II Scab Liner and fully cement liner in place 7. Run RTTS to 2230' and test casing to 4000 psi 8. Drill out 4-1/2" shoe track, scrape packer and patch setting areas. 9. Run 7" x 4-1/2" HES TNT seal bore packer with plug in tailpipe. 10. Run RTTS to 2230' and test casing to 4000 psi 11. Set Wfd MetalSkin expandable patch across the port collar. Test to 4000 psi. . ` • • 12. Set Storm packer, Change out 7" IC packoff, Pull Storm packer 13. Run 4-1/2" L-80 TC-II injection completion with seal assembly. Test seals to 4,000 psi. 14. Set TWC. ND BOPE. NU and test tree. Pull TWC, Install BPV. RDMO. Post-riq work: 1 Pull BPV, Ball and Rod, RHC plug TREE= 4-1/16"CNV • S/"NOTES: -WELL ANGLE>–70°@ 8915'**"H2S V1EI_LFEAD= 13-5/8"FMC S-101 READINGS AVERAGE 125 ppm WHEN ON MI*"*WELL ACTUATOR= BAKER C Current ( I REQUIRES A SSSV W-IEN EN ON MI***CHROME TBG"r**14UAL KB.ELEV=--- 64.41' _ — _ 7/9/13 = KOP= 1046' Max Angle= 97°@ 9343' Datum ND= 8859' ' Leaking 7" TAM port Collar at 2200' DatumTVD= 6700'SS 10-3/4"CSG,45.5#,L80 BTC,D=9.950" H 4014' Minimum ID = 3.725" @ 4-1/2" HES XN NIPPLE 4-1/2" XN Nipple at 7835' 4-1/2" L-80 TC-II Kill String at 7867' / 7" HES RBP at 7900' PC leak at 8,115' 7" HES RBP at 8300' - 4-1/2"TBG,12.6#,L-80 VAM TOP, H ??? 8709' —I 7"BAKER ZXP PKR,D=4.437" 0087 bpf,ID=2_992' 8713' H4 1/2"WLEG,D=3.958" 8724' HI7"X 5"BOT LNR HGR-HY DR,D=4.437" 8731' —I 7"X 4-1/2"XO BOT,D=3.938 7"CSG,26#,L-80-BTC-M,ID=6.276" H 8880' —A L 8 • 94.02' H FROFLE NP BOTID SUB,13=3.844" PERFORATION SUMMARY ' I 9410' H BOT FIvICV,ID=3.958" REF LOG: MWD ON 08/08/00 ANGLE AT TOP PERF:65"@ 8850' • 8 9421' H IROFLE NP-BOTND SUB,D=3.844" Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 9429' H EXTERNAL CSG PKR,D=3.958" 4-/12" 6 8850-8960 0 03/30/01 4-1/2" S 9535-11699 SLTD 08/31/00 4 1/2"DRLLABLE P.O.BUSHING,D=3.958" H 11699' 14-1/2"LNR,12.6#,L-80 BT,.0152 bpf M,D=3.958" 11721' DATE REV BY COMvBNTS DATE REV BY COMA: TS AURORA UNIT 09/08/00 N9ES NJTTIAL COMPLETION WELL: S-101 06/24/13 PJC RWO PROPOSAL PH vIT No:`2001150 AR No: 50-029-22968-00 SEC 35,T12N,R12E 781'FVVI_&859'FM_ BP Exploration(Alaska) TREE= 4-1/16"OW SA NOTES: WELL ANGLE>—70°@ 8915'"`H2S WELLIEAD= 13-5/8"FMC S—101 READINGS AVERAGE 125 ppm WHEN ON MI"'WELL ACTUATCA= BAKER C REQUIRES A SSSV WHEN ON MI***CHROME TBG*" _lv AL KB.ELEV= , 64.4V PROPOSAL I I 1 BF .ELEV= KOP= 1046 975' Max Angle= 97 9343' 4 10-1132/"4 H ETS A M X NIP,IT D C=O 3L.L8A13 Datum MD _-- __ 8859' Datum TVD= 6700'SS ii, 7" WFD metalskin casing patch 2180'-2210' ID=5.488" 10-3/4"CSG,45.5#,L-80 BTC,ID=9.950" —I 4014' A H 4-1/2"HES X NP,U=3.813" Packer must be set prior to 7" patch. Upper 11 completion to run into a seal bore above packer. i ■_ —7888 H7"X 4-1/2"HES TNT PKR,D= l —14-1/2"FES X NP,D=3.813" Minimum ID = 3.725" @ ' 4-1/2" HESXN NIPPLE 1 J H4-112"HES XN NIP,ID=3.725" TOP OF 4-1/2"LM --I —8000 i —8007 H4-1/2"WLEG,D=3.958" ' 4-1/2'113G,12.6#,L-80 VAM TOP, - '-8007 ` -.0087 bpf,13=2-992" iv I., AA 4-1/2"TBG,12.6#,L-80 VAM TOP, —H ??? 8709' H7"BAKER ZXP R02,D=4-437" 0087 bpf,ID=2-992• 14 �' W 8713' —14 1/2" LEG,D=3.958" ■ ■ 8724' 1-17"X 5"BOT LNR HGR HY DR,U=4.437" 8731' -17"X 4-1/2"XO BOT,U=3-938 7"CSG,26#,L-80-BTC-M,ID=6-276" H 8880' , 1 9402' H PROFILE NE-BOTH)SUB,D=3.844" PERFORATION SUMMARY I ( 9410' H BOT I-fv C'V,D=3-958" REF LOG: TAM ON 08/08/00 ANGLE AT TOP PERF:65°@ 8850' II 9421' H FROFLE NP-BOTH)SUB,ID=3-844" Note:Refer to R-oduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 0 X 9429' H EXTERNAL CSG PKR,D=3.958" 4-/12" 6 8850-8960 0 03/30/01 4-1/2" S 9535-11699 SLID 08/31/00 4 1/2"DRELABLE P-O-BUSHNVG,D=3-958" —I 11699' 14-1/2"LNR, 12-6#,L-80 BT,.0152 bpfM,D=3.958" 11721' DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT 09/08/00 N9ES F1J AL COMPLETION WELL: S-101 06/24/13 PJC RVVO PROPOSAL PBRMT No:"2001150 AR No: 50-029-22968-00 SEC 35,T12N,R12E 781'FWL&859'FNL BP Exploration(Alaska) \\ s THE STATE Alaska il a Gas V OF T�� °'ALASKA Conservation Commission h, GOVERNOR SEAN PARNELL 333 West Seventh Avenue an Anchorage, Alaska 99501 -3572 OF ALASY' SCANNED ��� 2�1J Main: 907.279.1433 SCAN Fax: 907.276.7542 David Reem Engineering Team Leader BP Exploration (Alaska), Inc. 3 4 P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Aurora Pool, S -101 Sundry Number: 313 -170 Dear Mr. Reem: 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. Foerster Chair DATED this /7 day of April, 2013. Encl. . STATE OF ALASKA • ' ALAS OIL AND GAS CONSERVATION COMMISSION - :07 - 5 4'l (lib APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ,ti 1. Type of Request: '4 " ) 1 ' ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ® Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ® Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ® Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 200 -115 ' 3. Address: ❑ Development ® Service . 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 -6612 50.029- 22968 -00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? S -101 . Will planned perforations require a Spacing Exception? ❑ Yes No 9. Property Designatior . 10. Field / Pool(s): ADL 028258 & 028257 • Prudhoe Bay / Aurora Pool (Undefined) • 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): 11721' • 6753' ' 11699' 6752' 8699' None Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 20" 28' - 109' 28' - 109' 1490 470 Surface 3987' 10 -3/4" 27' - 4014' 27' - 3393' 5210 2480 Intermediate 8856' 7" 24' - 8880' 24' - 6773' 7240 5410 Production Liner 3012' 4 - 1/2" 8709' - 11721' 6700' - 6753' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8850' - 8960' / Slotted' 9535' - 11699' 6760' - 6799' / Slotted 6780' - 6752' 3-1/2", 9.2# 13Cr80 8713' Packers and SSSV Type: 7" x 4 -1/2" Baker S - Packer Packers and SSSV 8674' / 6685' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ❑ Development ® Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: May 10, 2013 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ® WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Sean McLaughlin, 564 -4387 Printed Name: David Reem Title: Engineering Team Leader Email: Sean.McLaughlin @bp.com Signature: a, � Phone: 564 -5743 Date: 4 f 3 dd Commission Use Only _ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �I Sund ❑ Plug Integrity VJ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Al Other: 1g o P tes ; .-,Svc) / 5 �DMS APR 2 Spacing Exception Required? ❑ Yes ❑ No Subsequent Form Required: , _____4 w7 / 1 APPROVED BY Approved By: a j ° _ 1/4 4"---- COMMISSIONER THE COMMISSION Date: ti Forrtit V r y - R rfep ROA L Approved application is valid for 12 months from the date of approval Submit In Duplicate •;17 h II Vi- 47' /j 3 ! 7jJ ,,:C1 • • o p S -101 i Expense Rig Workover Well Objective: Perform a rig work over to repair production casing leak at 8,115'. Well History: Well S -101 was drilled into the Kuparuk reservoir in 2000 as a horizontal injector. The well was drilled to support the S -100 producer. The well only supports the producer S -100 and engulfs the largest subsurface acreage in the Aurora horizon. The well failed a MITIA test in March of 2011 and the well was shut in. An acoustic LDL was run in April of 2012 and confirmed a PC leak @ 8115' MD. The primary objective of this well is to reestablish well , integrity to the wellbore to support the S -100 producer. MASP: 2630 psi Well Type: Injector Estimated Start Date: May 10th, 2013 Intervention Engineer: Sean McLaughlin 564 -4387 Pad Engineer: Mackie Derrick 564 -5891 Pre -Rig Work Request: S 1 Pull PX plug from 8699', Run SBHPS, Set PX plug at 8699'. F 2 MIT -T to 2,000 psi. MIT -OA to 2,000psi. Record LLR as necessary. W 3 Check the tubing and casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT -T & IC. E 4 Power jet cut the 3 -1/2" 9.2# tubing 2' from top of pup joint above the packer at 8663'(leave an 8' stub). (Reference Nabors tubing summary 8/31/2000) F 5 Circulate well with KWF (weight tbd from sbhps) and Diesel F /P. ✓ 5 Prep annular valves, Set a BPV in the tubing hanger. O 6 Remove the well house & flow line. Level the pad as needed for the rig. Proposed Procedure 1. MIRU. Pull BPV. Circulate KWF. Install TWC. Nipple down tree and adapter flange. 2. NU 4 preventer BOP consisting of annular, 2 -7/8" x 5" VBR's, blind shear rams, flow cross and 2 -7/8" x 5" VBRs. Pressure test BOPE to 3,500Qsi huh /�50psi low. Test the annular to 3,500 psi. 3. Pull and lay down 3 -1/2" 9.2# 13Cr -80 tubing to cut. 4. Run test packer and test casing to 4000 psi at 8,050'. 5. Mill and retrieve 7" x 4 -1/2" Baker S -3 Packer and tail pipe. 6. Set 4 -1/2" Fas -Dril plug at 8745'. 7. Run 4 -1/2" L -80 TC -II Scab Liner and fully cement liner in place 8. Change out 7" casing hanger packoff 9. Drill out shoe track and pressure test casing to 4000 psi. 10. Run 4-1/2" L -80 TC -II injection tubing. Test packer to 4000 psi. 11. Set TWC. ND BOPE. NU and test tree. Pull TWC, Freeze Protect, Install BPV. RDMO. Post-rig work: 1 Pull BPV, Ball and Rod, RHC plug , TREE = 4 -1/16" - 5M CIW, Cl-R) 0 . N4aLHEAD = 13 -5/8" - 5M FMC SH NOTES: H2S READINGS AVERAGE 125 ppm S 101 ACTUATOR = BAKER WIEI ON MI. WELL REQUIRES A SSSV WHEN ON KB. ELEV = 6445' ML '""3 -1I2" CHROME TUBING' BE ELEV = WELL ANGLE > -70° @ 8907'. KOP = 1046' Max Angle = 97° @ 9343' 2206' -13 1/2" HES X NP, ID = 2.75" Datum MD = 8859 Datum TVD = 6700' SS 110 -3M" CSG, 45.5#, L -80 BTC, D = 9.950" H 4014' GAS LFT MANDRELS ST MD TVD DEV VLV TYPE LATCH PORT DATE 4 4437 3695 44 DM' MMG BXP RK 0 04/04/11 Minimum ID = 2.75" 2206' 3 7308 5787 40 DMY MMG BXP RK 0 04/04/11 3 -1/2" HES X NIPPLE 2 8248 6488 53 DMY MMG BXP RK 0 04/04/11 1 8552 6634 65 DMY NOG BXP RK 0 04/04/11 I I 8661' H 3-1/2" HES X NP, D= 2.75" X X 8674' IH 7" X 4-1/2" BAKER S-3 PKR: NSCT W/ XO PUPS TO 3 -1/2", D = 3.875" 181 I 8699' H 3-1/2" X NIP, 13= 2.75" 3-1/2" PX RUG (06/09/11) H 8699' I-- X 8709' H 7" BAKER ZXP RCR, D = 4.437" 3-1/2" TBG, 9.2#, 13CR -80 FOX, H 8712' / \ I 8713' —14 1/2" WLEG, D= 3.958" 1 .0087 bpf, D = 2.992" I 8724' —I 7" X 5" BOT LNR HGR HY DR, D = 4.437" TOP OF 4-1/2" LNR H 8736' 1---- _( 8731' N 7" X 4-1/2" XO BOT, ID = 3.938 —I ELMO TT NOT LOGGED I 17" CSG, 26#, L-80-BTC-M, ID = 6.276" —I 8880' , PERFORATION SUMMARY I I I 9402' —I PROFLE NRBOTND SUB, ID = 3.844" REF LOG: MWD ON 08/08/00 ANGLE AT TOP PERF: 65° @ 8850' Note: Refer to Production DB for historical pert data I I 9410' H BOT HMCV, 13= 3.958" SEE SPF NTBRVAL Opn/Sqz DATE 4-112" 6 8850 - 8960 0 03/30/01 4-1/2" S 9535 - 11699 SLTD 08/31/00 I I I 9421' IH PROFLE NRBOTND SUB, 13= 3.844" CE 2KI 9429' H E CTERNAL CSG PKR, D = 3.958" 11699' —14 1/2" DRLLABLEP.O. BUSHNG I I4 -1/2" LNR, 12.6#, L -80 I 11721' DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNT 08/24/00 ORIGNAL COMPLETION 02/15/11 ■B/JMD ADDED SSSV SAFETY NOTE WELL: S -101 11/13/00 SIS -SLT CONVERTED TO CANVAS 04/08/11 RCT/ PJC GLV CIO (04/04/11) PERMIT No: 1 `1 001150 01/26/01 SIS-LG REVISION 04/29/11 RCT/ PJC SET PX RUG (04/04/11) API No: 50- 029 - 22968 -00 03/07 /01 CWKAK CORRECTIONS 06/15/11 ALW PJC PU-U RESET PX (6/8 - 9111) SEC 35, T12N, R12E, 4498' FR & 4421' FSL 04/10/01 KAK PBRFS 01/19/12 TMWJMD ADDED HES SAFETY NOTE 04/09/03 DRS/TP TVD/MD CORRECTIONS BP Exploration (Alaska) 1 TREE AD= 4-1/16" 5 5/8 - 5 FPC SH S m. 101 NOTES: H2S READINGS AVERAGE 125 ppm ACTUATOR = BAKER Proposed RWO W�ON MI. WELL RE WHEN ON KB. REV = 64.45' p MI. WELL ANGLE> -70° @ BF. ELEV = 8907'. KOP= 1046' _ 1 - -_ 4 -1/2" X NIP ID= 3.813" @ 2,200' Max Angle = 97° @ 9343' Datum MD = 8859' i [ Datum TV D = 6700' - 10-3/4" CSG, 45.5#, L -80 BTC, D = 9.950" H 4014' Minimum ID = 3.725" @ xxx' • 1 ----- 4 -1/2" X NIP ID= 3.813" 4 -1/2" HES XN NIPPLE X x - 4 -1/2" x 7" HES TNT Packer @ 7,888' 4-1/2" TBG, 12.6f#, L-80 TGII, H 8007• I - 1 1 — " - 4-1/2" X NIP ID=3.813" 0152bpf, 10= 3.958" 1 1 - - 4 -1/2" XN NIP ID= 3.725" - - 4 -1/2" WLEG @ 8,007' 'TOP OF 4 -1/2' LNR —I - 8,000' I J 8709' — 7" BAKER ZXP FKR, D = 4.437" 8724' H7" X 5" BOT LNR HGR -HY DR, D = 4.437" 1CPCF412' LNR H 8736 8731' H T X 4 -1/2" XO BOT, ID = 3.938 7" CSG, 26#, L- 80- BTC -M ID = 6.276" --I 8880' , 0 PERFORATION R. I I 9402' --I PROFILE N -BOTLD SUB, ID = 3.844" REF LOG: !AM ON 08/08/00 ANGLE AT TOP PBRF: 65° @ 8850' Note: Refer to Production DB for historical pert data I I 9410' I—{ BOT I-IMCV, D = 3.958" SIZE SPF INTERVAL Opn /Sqz DATE 4-1/2" 6 8850 - 8960 0 03/30/01 4 -1/2" S 9535 - 11699 SLTD 08/31/00 I I 9421' H PROFLE NIP - BOTLD SUB, D = 3.844" E 23 I 9429' — I EXTERNAL CSG PKR, D = 3.958" 11699' H 1/2" DRILLABLE P.O. BUSHNG 4 -1/2" LNR, 12.6#, L -80 11721' DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT 08/24/00 ORIGINAL COMPLETION 02/15 /11 MB/JMD ADDED SSSV SAFETY NOTE WELL: S -101 11/13/00 SIS -SLT CONVERTED TO CANVAS 04/08/11 RCT/ PJC GLV C/O (04/04/11) PERMIT No: "2001150 01/26/01 SIS-LG REVISION 04/29/11 RCT/ PJC SET PX PLUG (04/04/11) API No_ 50- 029 - 22968 -00 03/07 /01 CWKAK CORRECTIONS 06 /15/11 ALFV PJC PULL) RESET PX (6/8 - 9/11) SEC 35, T12N, R12E, 4498' FEL & 4421' FSL 04/10/01 KAK PEWS 01/19/12 TMWJND ADDED I SAFETY NOTE 04/09/03 DRS/TP TV D/MD CORRECTIONS BP Exploration (Alaska) • • FLOOR ELEVATION Drilling Mode `__7 - 25' -6" AGL VALVE LEGEND a Q BYPASS 1 I l p COZGZ2 I Q2 KILL Three Rams L i QCHOKE 13 5/8 ", 5000 PSI, HYDRIL ANNULAR BOP, ©�© � O rg ) � Q T om STUDDED TOP /FLANGED BOTTOM 4p LOW PIPE RAMS i • i 0 SHEAR RAMS ` • Li • • • ©TOP PIPE RAMS I I I. I I ■ Q ANNULAR I I I I AGED TOP BX 160 • ACCUMULATOR: KOOMEY TYPE 80, 180 GAL p 3 5 /8', 5000 PSI, 10° MPL OPERATORS, TRIPLEX PUMP: 575 VAC, 30 HP AIR PUMP: 3 ea. KOOMEY I HYDRIL PIPE RAM LL 3 1/8" 5000 PSI SIDE OUTLET 3 CHOKE UNE O FT 13 5/8 ", 5000 PSI, 14" MPL OPERATORS, 1 HYDRIL BOND /SHEAR RAM C) STUDDED BOTTOM BX 160 O O 3 1/8" 5000 PSI HCR VALVE ■'► 4 I► 4II, /III I► 111'.1► 2" KILL UNE 3 1/8" 5000 PSI HCR VALVE / I I 3 1/8 5000 PSI GATE VALVE 1111 iI l � l �� � l l �� 3 1/8 5000 PSI GATE VALVE —r I I w w w ■ I FLANGED TOP BX 160 SINGLE 13 5/8 ", L 5000 PSI, 10" MPL OPERATORS, E ---- � 1 1 STUDDED BOTTOM BX • GL I I ADAPTER SPOOL CHOKE GOP STACK E M I E • WELLHEAD 1 � i�i ∎I ∎I ∎i ∎i ∎i ∎i ∎i ∎i I l>. ACCUMULATOR MANIFOLD " n _� 20 BOTTLES, 10 GALLONS EACH I-7- I T / 0 BOP STACK ELEVATION REMOTE PANEL IN DOGHOUSE lit i AN UTILIT MO DULE 41. Ilmml NITROGEN BACKUP BOTTLES 21 1 00 PSI, 5 EACH w A Nomemem oEYCN a RR wwA;I ,°' I fi' 150 PSI HVDR. H RDRIL BOP NO rag a reansar; aA.r s Aunlawsn a ■ u ral n T- OPERATED KNIFE GATE VALVE STUDDED HRDRIL TOO P /FUNDED GED BOTTOM - FLANGE/FLANGE RD 73 �aYan RO 16 FLG VENT UNE, SCH 80 O ' RIG 16 7 /I /16 3 LEA LEA ND SWAYS DRILLING MODE BOP SYSTEM no w 12 -20-00 2 owe LEA MATE EDP S AC% AND CONTROLS NINNIN■IM SURFACE DIVERTER CONFIGURATION 11 -26 -9e 1 .m1 LET CONN To NM= n CHEMED BY /MOM VI /1/10 REV' uwL W: 1. DESCR ION A NTS MIN WI OM R1 6BOPSYS&CONTROL SC • • � 1�- a -[ � r 1. �wa 1 um # 'I ii `• s •: I Iii 6 .I iHiciipirls NIP i i Il t o I; [1 a 1. • MEMO R 01 MI III i,l�''i j: { :1 O i l • I L 1, • 1 MI I 14 1 or 1, 11 1 1 ..,,r p =: 1 a . 1 1 I— PFI MAR) EQUIPMENT, 4 ' 2' COMPL ET ION - - II TEN' II PART NUMBER iL DESNRI FT ION 1 13- 300 -730 LANDING RING 2 I2- 130 -445 CAS INN HANGER ASSY, 103a 13 -260 - 696 LOWER SPLIT UNIHEAD 4 12- 130 -476 CASING HANGER, 7% 5 12 -160 -025 PACKOFF ASSY. 7% 6 13- 300 -629 UPPER SPLIT UNIHEAD 7 90 -120 -560 GATE VALVE J E 2A- 015 - 646 COMPANION FLANGE 9 25- 320 -069 BULL PLUG - 10 25- 4I0 -2H VR PLUG II 82- 747 -698 TUBING HANGER ASSY. 41/2 IC 02 -047 -689 ADAPTER ASSY I COPIT INGENC) EQUIPMENT I I I TEM H I PART NUMBER II DESCRIPTION I 13 12- 090 -160 CASING HANGER ASSY, I0j4 14 52-110 -094 BELL NIPPLE ASSY IS 10- 093 -i57 CASING HANGER ASS), 7% • • Ferguson, Victoria L (DOA) From: McLaughlin, Sean M [Sean.McLaughlin ©bp.com] Sent: Tuesday, April 16, 2013 4:45 PM To: Ferguson, Victoria L (DOA) Subject: RE: PBU S -101 i (PTD 200 -115, Sundry 313 -170) Attachments: SH -10884 PBD Slim Hole.pdf Victoria, I have attached the wellhead schematic. The casing was run with a mandrel hanger. The packoff can be pulled and run through the 13 -5/8" BOP stack so there are no breaking containment issues. We do not plan to split the stack or set an additional barrier. Regards, lean From: Ferguson, Victoria L (DOA) [mailto :victoria.ferguson @alaska.govl Sent: Tuesday, April 16, 2013 3:51 PM To: McLaughlin, Sean M Subject: PBU S -1011 (PTD 200 -115, Sundry 313 -170) Sean, Please provide the following: 1. Wellhead schematic 2. Detail in procedure to set RTTS barrier and ND BOP or whatever your plan is to change out casing hanger packoff.(Step 8) Thank, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson @alaska.gov 1 act: -t • WELL LOG TRANSMITTAL PROACTIVE DIAGNOSTIC SERVICES, INC. To: AOGCC Christine Shartzer 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MU) The technical data listed below is being submitted herewith. Please acknowledge receipt ley.,,. returning a signed copy of this transmittal letter to the attention of : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Shay Phillips 90 - 1 NNE" APR 2 3 2013 900 Benson Blvd. Anchorage, AK 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Detection - WLD 15- Apr -12 S -101 Color Log / CD 50-029- 22968 -00 2) Signed : )h ` Date : G/ l q ik 2. Print Name: I \14 O• GDUtit PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -8952 E -MAIL : PDSANCHORAGE 5,MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution \TransmittalSheets\BP Transmit.docx AP S WELL LOG TRANSMITTAL PROACTIVE DIAgNosric SERVICES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection[Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning transmittal letter to the following a signed copy of this t g : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2 - 1 ' f . { 6 400,Y 2 a Z U •4 900 Benson Blvd. Anchorage, Alaska 99508 and (1 j9OO— 115 ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C a 0 44 0 -1 Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Detection - STP 04-Apr-11 S -101 BL / EDE 50-029- 22968 -00 2 RECEIVED c. Signed : Date : APR 2011 Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 E-MAIL : pdsanchoraos memorvloa.com WEBSrrE : WWW.memorvloa.com C:\Docoments and Settings \Diane Williams \Desktop\BP_Transmit.docx 1Q2011 Not Operable Injector Rert • Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Sunday, April 03, 2011 7:30 AM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 102011 Not Operable Injector Report Attachments: Not Operable Injector Report 1Q2011.zip Tom, Jim, Phoebe and Guy, C)( Attached is the 10 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 1Q2011.zip» Notes on wells: %AIMED APR 18 2O1 Removed from Quarterly Injection Report: 03 -37: TxIA comm. when on MI. Well placed on production to eval TxIA comm. while on water injection. NGI -14: RWO repaired TxIAxOA comm. on 01/05/11 U -04A: Startinghead leak mitigated with Furmanite wrap on 02/12/11 Added to Quarterly Injection Report: S -101: MIT -IA failed on 03/01/11. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 4/17/2011 I Well S -101 Injection Plot • TIO Plot Well: S -101 o o Pressure vs. Rate o PTD #: 2001150 ° o AA: 22D.002 co • • • : A • A fd Tbg Approval: 03/26/09 r OA Anniversary: lAco r o •_ o Reason: on: TxIA comm rn °o •T• g Requirement: 2 year MITIA . N O N °- A • a a Last witnessed AOGCC MITIA - _ I a 03/07/09 3 8 s MITIA on 03/01/11 Failed 0 0 tif Will cancel AA due to failing •Last 90 days • Last Month t f A-7)h nri MITIA on 03 /01/11 pending o • slickline trouble shooting GLVs o , 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9/8/10 11/29/10 2/19/11 5/12/11 Injection Rate, MCFPD ill Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 04/01/11 0 0 04/01/11 1,300 720 0 03/31/11 0 0 03/31/11 1,300 720 0 03/30/11 0 0 03/30/11 1,300 700 0 03/29/11 0 0 03/29/11 1,300 700 0 03/28/11 0 0 03/28/11 1,300 700 0 03/27/11 0 0 03/27/11 1,300 700 0 03/26/11 0 0 03/26/11 1,300 700 0 03/25/11 0 0 03/25/11 1,300 700 0 03/24/11 0 0 03/24/11 1,300 700 0 03/23/11 0 0 03/23/11 1,300 700 0 03/22/11 0 0 03/22/11 1,300 700 0 03/21/11 0 0 03/21/11 1,300 700 0 03/20/11 0 0 03/20/11 1,300 700 0 03/19/11 0 0 03/19/11 1,300 700 0 03/18/11 0 0 03/18/11 1,300 700 0 03/17/11 0 0 03/17/11 1,300 700 0 III 03/16/11 0 0 03/16/11 1,300 700 0 03/15/11 0 0 03/15/11 1,300 700 0 03/14/11 0 0 03/14/11 1,300 700 0 03/13/11 0 0 03/13/11 1,300 700 0 03/12/11 0 0 03/12/11 1,300 700 0 03/11/11 0 0 03/11/11 1,300 700 0 03/10/11 0 0 03/10/11 1,300 700 0 03/09/11 0 0 03/09/11 1,300 700 0 03/08/11 0 0 03/08/11 1,300 740 0 03/07/11 0 0 03/07/11 1,300 740 0 03/06/11 0 0 03/06/11 1,300 740 0 03/05/11 0 0 03/05/11 1,300 780 0 03/04/11 0 0 03/04/11 1,300 800 0 03/03/11 0 0 03/03/11 1,300 800 0 03/02/11 0 0 03/02/11 2,700 1,000 500 Monthly Injection Report for GPBBPMA, Northstar, Milne Point & Endiccfor Februa... Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @ bp.com] Sent: Monday, March 07, 2011 9:26 AM To: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) Cc: AK, D &C Well Integrity Coordinator; Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for February 2011 Attachments: AOGCC Inj Report 03- 11.zip Tom, There was a bug in the initial Monthly Injection Report that didn't identify all the wells. The bug has been fixed; please use this report for your records. Notes on wells: Added to Report: W -03A: Added to report due to sustained casing pressure on the IA noted 2/17/11, currently performing diagnostics. AGI -05: Added to report due to IA repressurization post TAPS shutdown. Taken off Repo S -101: Taken off report due to a failing MITIA. Added to the Quarterly Not Operable Report. 3o� - 't S Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator MAR ([ 5 FLU 1 ; ' Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, March 07, 2011 9:09 AM To: AK, D &C Well Integrity Coordinator Subject: RE: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for February 2011 Torin, I have just started to review the list. In the message, you list W -03 as being added. Should that be W -03A? Also, when I look at the spreadsheet I do not find W -03 or W -03A included. Could you check into this ?? Thanks in advance, Tom Maunder, PE AOGCC From: AK, D &C Well Integrity Coordinator [mailto: AKDCWeIIlntegrityCoordinator @bp.com] Sent: Sunday, March 06, 2011 11:59 AM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L 3/7/2011 • Monthly Injection Report for GPBoPMA, Northstar, Milne Point & Endiccfor Februa... Page 2 of 2 (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Engel, Harry R Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for February 2011 Tom, Jim, Phoebe, and Guy, Attached is the February 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. <<AOGCC Inj Report 03- 11.zip» Notes on wells: Added to Report: W -03: Added to report due to sustained casing pressure on the IA noted 2/17/11, currently performing diagnostics. AGI -05: Added to report due to IA repressurization post TAPS shutdown. Taken off Report: S -101: Taken off report due to a failing MITIA. Added to the Quarterly Not Operable Report. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 3/7/2011 NOT OPERABLE: Injector S -101 (PTD #2001150) Failed MITIA Page 1 of 1 • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Tuesday, March 01, 2011 5:20 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; Engel, Harry R; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, RES GPB West Wells Opt Engr; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Ops Lead Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Derrick, Mackie; King, Whitney Subject: NOT OPERABLE: Injector S -101 (PTD #2001150) Failed MITIA Attachments: S -101 AA Approval 03- 26- 09.pdf; S -101 TIO Plot 03- 01- 11.doc; S- 101.pdf All, Injector S -101 (PTD #2001150) currently has an AA (AIO 22D.002) for producer water injection due to TxIA communication. On 03/01/11, an MITIA failed with a LLR -.4bpm @ 3100 psi verifying that at least one of the barriers is compromised. The well will be reclassified as Not Operable and needs to be shut -in and freeze protected as soon as safely possible. The plan forward is as follows: MR 22011 1. Slickline: Leak detect log, trouble shoot DGLVs 2. WE: Eval plan forward pending slickline results A copy of the AA, TIO plot and wellbore schematic have been included for reference. «S -101 AA Approval 03- 26- 09.pdf» «S -101 TIO Plot 03- 01- 11.doc» «S- 101.pdf» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 3/2/2011 • • Ws! 5 -101 4,000 ■ 3,000 1 • Tbg • f T IA 2,000 - — } ' OA • OOA + 000A On 1 000 12/04/10 12/11/10 12/18/10 12/25/10 01/01/11 01/08/11 01/15/11 01/22/11 01/29/11 02/05/11 02/12/11 02/19/11 02/26/11 • • • ~ BP Exploration (Alaska) Inc. ~ Attn: Weil Integriry Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 ~ ~ Enclosed please find a spreadsheet with a list of wells from S-Pad 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, ~!~ ;~,i,~~ E ~ j ~ "t.~ ~ ~J U~ e.~s~ ~5if:~+' ~ 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) S-pad Dnte 6/25/2009 Well Name PTD # Ini[ial top of cement Vol, of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corcosion inhibitod sealant date ft bbls ft na af S-016 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 0.25 NA 025 NA 1.7 5/25/2009 5-03 1811900 1325 NA 13.25 NA 92.65 5/20/2009 5-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1951890 0 NA 0 NA 0.9 5/26/2009 S-O6 1821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA 0.9 5/2&2009 S-OBB 2010520 0 NA 0 NA a.85 5/27/2009 5-09 1827040 1.5 NA 1.5 NA 9.4 5/31/2009 S-10A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 5-718 1990530 0.25 NA 025 NA 1.7 5/27/2009 S-12A 1851930 0.25 NA 025 NA 1.7 6/t/2009 5-t3 1821350 8 NA 8 NA 55.3 6/1/2009 S-15 1840170 025 NA 0.25 NA 3 6J2/2009 S-17C 2020070 025 NA 025 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 S-19 1861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 025 NA ~ 025 NA 1.3 5/19/2009 5-21 1900470 0.5 NA 0.5 NA 3.4 5f25/2009 S-22B 1970510 0.75 NA 0.75 NA 3 5l19l2~9 5-23 1901270 025 NA 025 NA 1.7 5J25/2009 S-24B 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 19ffi740 0.5 NA 0.5 NA 2.6 5/25/2009 5-26 1900580 0.75 NA 0.~5 NA 3.4 5/26/2009 5-278 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 S-28B 2030020 0.5 NA 0.5 NA 2.6 5/31/2009 S-29AL7 1960120 0 NA 0 NA 0.85 5/27/2009 5-30 1900660 0.5 NA 0.5 NA 5.t 5/37/2009 S-31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 S-32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 5-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 S34 1921380 0.5 NA 0.5 NA 3.4 5/31/2009 5-35 1921480 0 NA 0 NA .85in 5/31/2009 5-36 1921160 0.75 NA 0.75 NA 4.25 5/27/2009 5-37 1920990 125 NA 125 NA 11.9 5/27/2009 5-38 1921270 025 NA 025 NA 102 5/27/2009 5-41 1960240 1.5 NA 1.5 NA 11.1 5/3W2009 S-42 1960540 0 NA 0 NA 0.9 5/30/2009 5-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 S-44 1970070 025 NA 025 NA 1.7 5/28/2009 S-100 2000780 2 NA 2 NA 21.3 5/29/2009 5-101 2001150 ~ 125 NA 125 NA 71.9 5/29/2009 5-102L/ 2031560 125 NA 125 NA 11.1 5/31/2009 S-103 2001680 1.5 NA 1.5 NA 17.9 5/18/2009 S-104 2001960 1.75 NA 1.75 NA 75.3 5/20/2009 S-105 2001520 4 NA 4 NA 32.7 5/20/2009 5-106 2010120 1625 NA 16.25 NA 774.3 6/2/2009 5-107 2071130 225 NA 225 NA 28.9 5/18/2009 S-to9 2011000 3.5 NA 3.5 NA a0 5/30/2009 5-109 2022450 2 NA 2 NA 21.3 5/30/2009 5-110 2011290 11.75 NA 11.75 NA 98.6 5/30/2009 S-1 t t 2050510 2 NA 2 NA 19.6 5/30/2009 S-112 2021350 0 NA 0 NA 0.5 5/30/2009 5-113 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 S-114A 2021980 125 NA 125 NA 102 5/30/2009 5-715 2022300 2.5 NA 2.5 NA 272 5/29/2009 5-116 2031810 7.5 NA 1.5 NA 13.6 5/28/2009 5-117 2030120 1.5 NA 1.5 NA 15.3 5/29I2009 5-118 2032000 5 NA 5 NA 76.5 5/28/2009 S-U9 2041620 1 NA 1 NA 52 5/30/2009 S-120 2037980 5.5 NA 5.5 NA 672 5/29/2009 5-121 2060410 4.5 NA 4.5 NA 53.8 5/28/2009 St22 2050810 3 NA 3 NA 2i.3 5/29/2009 5-123 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 S-12a 2061360 1.75 NA 175 NA 71.9 5/26/2009 S-125 2070830 225 NA 225 NA 20.4 5/28/2009 S-126 20710970 125 NA 125 NA 15.3 6/1/2009 S-200 1972390 1.25 NA 725 NA 74.5 5/28I2009 S-201 2001840 0 NA 0 NA 0.85 6/19/2009 S-213A 2042130 2 NA 2 NA 13.6 5/29I2009 S-215 2021540 2 NA 2 NA 18.7 6/1/2009 5-216 2001970 4.75 NA 4.75 NA 51 5/29/2009 5-217 2070950 0.25 NA 025 NA 1.7 6/1/2009 S-400 2070740 2 NA 2 NA 9.4 5/28/2009 S-401 2060780 16 NA 16 NA 99.5 6/2/2009 5-504 0 NA 0 NA 0~.85 5/28/2009 ~ • • Page 1 of 1 Regg, James B (DOA) ~~ ~~ ~f 5 From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, March 26, 2009 11:19 AM ~~ ~ . To: Regg, James B (DOA) ~I~C!-~GI ~~~ (~ ~ l Cc: NSU, ADW Well Integrity Engineer Subject: RE: MIT -PBU S-101 Attachments: MIT PBU S-101 03-07-09.x1s Jim, Please see the attached MIT form for S-101. My apologies for not sending it sooner. ~ Thank you, Andrea From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, March 24, 2009 9:07 AM To: NSU, ADW Well Integrity Engineer Subject: MIT -PBU S-101 Need the MIT for PBU S-101 dated 3/7/09 to complete AA; thank you! Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 3/26/2009 • STATE OF ALASKA ALASKA qL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder~alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. ~r ~ ~ ~~ (Z~~ J FIELD /UNIT /PAD: Prudhoe Bay /PBU / S Pad ~~ DATE: 03/07/09 OPERATOR REP: Andrea Hughes AOGCC REP: Packer Depth Pretest Initial Min. 30 Min. Well S-101 Type Inj. W TVD 6,685' ubin 2,600 2,600 .2,600 2,600 Interval O P.T.D. 2001150 T pe test P Test psi 1671 Casin 1,100 3,000 2,860 2,86 P/F P Notes: MITIA to 3000 psi eval TxIA Comm OA 80 80 80 40 Well Type In'. TVD Tubin Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type tn'. TVD Tubin Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W = Wate r TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU S-101 03-07-09.x1s • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 March 19, 2009 • ~.. • ~ :, ~~~,h~ ~~ ~ ~~i~~~a ~~ ` tv ~ e ~9~'~'~yaS~S~t [c3=ail ~tr r ~ ~a.=-c~~ar~~~ P~ ~- ~~©.~~- ~~ ~ ~~n I Mr. Daniel Seamount, Chairman Alaska Oil and Gas Conservation Commission ~ Z2 ~ ~ w 2. 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit well S-101 (PTD #2001150) Request for Administrative Approval: Continued Water Injection Operations Dear Mr. Seamount, BP Exploration (Alaska) Inc. requests approval for continued water injection operations into Prudhoe Bay well S-101 with slow inner annulus re-pressurization. Well S-101 exhibits inner annulus re-pressurization of 35 psi/day when on MI injection. `~ However, a pressure test of the inner annulus passed to 3000 psi, indicating the tubing and production casing are competent. Based upon sound engineering practice, two barriers have been established and the well can be safely operated. Consequently, no repairs are planned at this time. In summary, BPXA believes Prudhoe Bay well S-101 is safe to operate as stated above and requests administrative approval for continued water injection operations. If you require any additional information, please contact me at 564-5637 or Anna Dube / Winton Aubert at 659-5102. Sincerely, R. Steven Rossberg BPXA, Weiis Manager LJ Attachments: Technical Justification TIO Plot Cc: Injection Plot Wellbore Schematic Bixby/Olsen Dube/Hughes West Area Manager Patrick Collins Harry Engel Janice Vosika • ~dhoe Bay Oil Pool well S-1~ Technical Justification for Administrative Approval Request March 19, 2009 Well History and Status Prudhoe Bay well S-101 (PTD #2001150) exhibits inner annulus repressurization indicated by wellhead pressure trends on a TIO plot. An MIT-IA to 3000 psi passed on 03/07/09 indicating competent tubing and production casing. Recent Well Events: > 02/23/09: Notify AOGCC of TxIA while on MI '~ > 03/07/09: MITIA Passed to 3000 psi > 03/09/09: Decision made to not pursue MI Injection but AA for PWI Only v > 03/16/09: IA re-pressurization ~ 35 psi /day, request swap to PWI - Barrier Evaluation The primary and secondary barrier systems consist of tubing and production casing and associated hardware. A pressure test of the inner annulus passed to 3000 psi, demonstrating competent primary and secondary barrier systems. Proposed Operating and Monitoring Plan 1. Record wellhead pressures and injection rate daily. /,. 2. Submit a report monthly of well pressures and injection rates to the AOGCC. ~ Y`om` 3. Perform a 4~ear MIT-IA to 1.2 times maximum anticipated injection pressure. f~ 4. The well will be shut-in and the AOGCC notified if there is any change in the ' wells mechanical condition. • • S-101 TIO Plot • 3 1]00 2.500 2,000 d ~ 1,500 1,OOD I I 50U S-101 Injection Plot 14,000 12,000 10,000 ~ -WHIP „ - SW 8,000 ° - PW 6,000 ~ GI 4.000 =' - 0~ On 2:000 12/20/08 12!21108 01/03/09 01110.'09 01/11/09 01/24/09 01/31/09 02101109 02/14/09 02/21109 02/20109 03/07/09 03/14/09 RE: UNDER EVALUATION•101 (PTD #2001150) Exhibiting Slov~ Repressurizati... Page 1 ~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~ 3~Z3`cx~ Sent: Tuesday, March 17, 2009 3:01 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad SW; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers Cc: Townsend, S. Eliot; Collins, Patrick J; NSU, ADW Well Integrity Engineer Subject: RE: UNDER EVALUATION: S-101 (PTD #2001150) Exhibiting Slow IA Repressurization All, A request for AOGCC Administrative A al to limit this well to PW injection only due to IA repressurization will be submitte shortly. Please have Operations swap this well to water injection as soon as safely possible. ~ Please let me know if there are any questions. Thank you, Anna 1~ude, ~.~'.~E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~~@@{{ [[tr AJ~ ~~qf R From: NSU, ADW Well Integrity Engineer Sent: Monday, February 23, 2009 10:59 PM To: GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad SW; Rossberg, R Steven; Engel, Hany R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot; Collins, Patrick ] Subject: UNDER EVALUATION: 5-101 (PTD #2001150) Exhibiting Slow IA Repressurization Hi all, Well S-101 (PTD #2001150) is exhibiting slow IA repressurization. The IA pressure was bled on 01/17/09 from 1710 psi to 800 psi. Since then the IA pressure has slowly increased. The well has been reclassified as Under Evaluation and may remain on MI injection while diagnostic work is completed. The plan forward is to review the possibility of running an LDL while the well is on MI infection to help determine the cause of the IA repressurization. -" A wellbore schematic, TIO plot, and Injection Plot have been included for reference. « File: S-101.pdf» « File: 5-101 TIO and Injection Plot.doc» ~'" Please let us know if you have any questions. Thank you, Anna l~u6e, ~.~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 3/23/2009 PBU S-101 PTD 200-115 2/23/2009 TIO Pressures `` g 4 Mini, I' I ~ 3,000 2.000 ~ $ 1:000 11}29}08 12106}08 12113100 12}20108 12127}08 01103/03 01110}09 01117}09 01123,'09 01131109 02}071n9 oL114,'U9 ULJ11/U~ Injection Plot 2,501 2,000 iZ = 1,500 1:000 51JI 1 12,000 1 o,nnn # Tbg -~- IA --~- OA _. ODA ~- OOOA -~- On °? WHIP 8,000 ~ SW p , PEA/ 6,000 ~_ MI ten' G I 4:000 ~ Other -~ 0 n 2.000 ~J • 12}06108 12120108 01}03109 01}17}09 01}31}09 02114}09 TREE= 41/16" - 5M CM/, CHROME WELLH64D= 135/8" - SM FMC SH ACTUATOR= BAKOt KB. ELEV = 64.45' BF. REV = KOP= 1046' Max Angle = 97 @9343' Datum MD = 10122' Datum ND= 6700' SS I 10-3/4" CSG, 45.5# / ft, L-80, BTC, ID = 9.950" ~ 4014' Minimum ID = 2.75" @ 2206' 3-1 /2" HES X NIPPLE 3-1 /2" TBG, 9.2#, 13CR-80 FOX, I-i 8712' r .0087 bpf, ID = 2.992" TOP OF 412" LNR 8736' 7" CSG, 26# / FT, L-80-BTGM, ID = 6.275' 8880' PERFORATION SUMMARY REF LOG: MWD ON 08/0&00 ANGLE AT TOP PERF: 96 @8850' Note: Refer to Production OB br historical pert data P IN L pn/ qz DA 4-/17' 6 8850 - 8960 O 03/30/01 41/2" S 9535 -11 699 SLID 08/31/00 S-101 SAFETY NOTES: WELL HAS 3-1/2" CHROME TUBING I 312" FES X NP, ID = 2.75" ~ !~C I ICT AAA MRFI R ST MD TVD DEV VLV TYPE LATCH PORT DATE 4 4437 3690 44 CA M MG BXP RK 3 7309 5786 40 CA MMG BXP RK 2 8248 6487 52 CA MMG BXP RK 1 8553 6634 65 CA MMG B)Q' RK . 8861' 312" HES X NP, ID = 2.75" 8674' 7" X 4-1/2" BAKER S-3 PKR-NSCT VW XO PUPS TO 31 /2", ID = 3.875" 8689' --{ 312" X NIP, ID= 2.75' 8709' 7" BAKERZXPPIQ2, D=4.437" 8713' 412" XO, w MA.EG $724' 7" X 5" BOT LN2 HGR-HYDR, ID= 4.4i 8731' 7" X 4-1/2" XO BOT, D = 3.938 1~ ELMD TT NDT LOGGED 9402' -i PROFILE NIP-BOTIND SUB, ID= 3.844" 9410' 1 BOT HMCV, ID = 3.958" 9421' ~ PROFILE NIP-BOTIND SUB, ID= 3.844" 9429' IXTERNA L CSG PKR, ID = 3.958" TOP OF 4-1 /2" SLTD LNR 9536' I I 12.6#, L-80 IBT, ID = 3.958" I I I 1 I 1 BOTTOM OF SLOTTED LNR 11700' I I 41 /7' LNR, 12.6#/ft, L-80 11721' DATE REV BY COMMENTS DATE REI/ BY COMMENTS 08/24/00 ORIGINAL OOMPLETION 11/13/00 SIS~LT CONVERTEDTOCANVAS 01/26/01 SIS-LG REVISION 03/07/01 CHIKAK OORRECTIONS 04/10/01 KAK PERFS 04/09/03 DRSJTP NdMDCORR~TIONS . AURORA UNIT WELL: S-101 PERMIT No: 2001150 A PI No: 50-029-22968-00 S~ 35, T12N, R12E, 4498' FEL & 4421' FSL BPEzploration (Alaska) 11699' ~~ 4 12" DRILLABLEP.O. BUSFING • MEMORANDUM 1 To: Jim Regg ~ ~' ~ ~ P.I. Supervisor ~1~~ t FRONt: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 21, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 5-101 PRUDHOE BAY UDI AURO S-101 t Src: Inspector //~~'^ G ~~ ~~(l Reviewed By: P.I. Suprv~~ ~i~~~~7 NON-CONFIDENTIAL Comm Well Name' PRUDHOE BAY UN AURO S-101 Insp Num: mitRCN071120080507 Rel Insp Num: API Well Number: 50-029-22968-00-00 Permit Number: 200-I 15-0 Inspector Name: Bob Noble Inspection Date' 11/19/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ' s-lol ,Type Inj. ' ~' TVD ~ 66ss~' IA ' ~ Tao aooo v 3920 3920 ' P T zoollso ~TypeTest ~ sPT i, Test psi aooo pA; 30 ` 2so '~ zoo z7o i ' Interval 4YRTST P~ P / TUbing' I 0 1350 j 1350 I ]350 I Notes: ~~~ ~E~ pEC 1 ~ 2.007 Wednesday, November 21, 2007 Page I of I - ,- .~ - - --..._~..\. .- ì . ".~""",","""'" Winton, Jim and Bob, Please see the attached MIT forms for the following wells: ./PBU 03-10: CMIT-IAxOA for Waiver compliance 'j !ù::c:; / ) PBU 04-08: MITIA to evaluate the well for an IAxOA AA and waiver ,,/ PBU R-25A: MITIA Pre-dewatering C ~¿ I 2...:5- ~ y/PBU 04-13: MITIA Pre MI swap !;'j Z~-3> ~) ",/PBU P1-25: MITIA Pre MI swap (;¡ ,,,I7Z':;f. " {ti55 /PBU S-101: MITIA Pre MI swap !\I<:3 lCC3 :5:> I,/PBU NK-13: MITIA for UIC Compliance, Chuck Schéve witnessed ::J ~~ .~-~; -¿\.,".A ;.: c/'The MIT form for PBU X-36 (PTO #1961670) was emailed by Anna Oube on 9/10/06. If you need an additional copy or did not receive the email, I will gladly send it again. Thank you for your patience. «MIT PBU S-101 11-23-03.xls» «MIT GPMA P1-25 09-06-06.xls» «MIT PBU 04-13 08-10-03.xls» «MIT PBU 04-08 08-04-05.xls» «MIT PBU R-25A 06-12-05.xls» «MIT PBU 03-10 09-30-05.xls» «MIT PBU NK-13 09-19-06.xls» Andrea Hughes (Filling in for Joe Anders) Well Integrity Engineer Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~#*."It..U::::·, SE'" 'J 0 'JOO!: v"-'nD"51J~!,¿} r f; r:¿ £" ~,i_1 Hi Jim, Thank you for the note. To update you on MITs that are ~ 1) PBU 04-13; due 1/8/2006 ,2) PBU S-101; due 2/25/2006 3) PBU NK-13; due 5/4/2006 ,,4) PBU X-36; due 5/20/2006 5) PBU R-25A; due 7/24/2006 past due: Completed Completed Completed Completed Completed 8/10/03 11/23/03 9/9/06 9/5/06 - 6/12/05 Sent in earlier e-mail We agree to schedule MITs on the following wells once on injection: lof4 9/25/2006 9: 15 AM ._,' ,_... ..v_.v¡, v' v~ V'~ . .~~'.n ~J" \' ,'-' '/... . Schedule when Schedule post Rig Schedule when Schedule post Rig 1) MPU H-06; due 2/28/2006 (SI since 7/2002) returned to injection 2) PBU WGI-01; due 4/22/2006 (SI since 12/12/2005) Sidetrack later this year 3) MPU F-41; due 5/14/2006 (SI since 5/2005) returned to injection v 4) PBU S-31A; due 6/1/2006 (SI since 12/2004) Workover J 5) PBU P1-01; due 6/4/2006 (SI since 6/2006 for workover) A patch to restore integrity is planned. Scheduel when returned to injection .. 6) PBU Pl-25; due 7/2/2006 (SI since 6/2006) 7) PBU GC-02C; due 7/22/2006 (SI since 4/2006) returned to injection, estimated some time in '07. Completed 9/6/06 Schedule when Others ,/1) PBU 03-10; MIT 9/30/2005 (CMIT IAxOA) 2) PBU 04-08; MITs (IA and OA) doneper monthly injector rpt; date unknown- '..' this well is currently SI with an AA and Waiver being drafted. I apologize for this office dropping the ball on these wells. Thank you for your patience in this matter, Ron Wilson WI Tech 659-5524 ------------------------------ We have recently completed a mid year review of MIT data from our inspection database to see how many injection wells may be in question regarding MIT timing. Results of our review relating to BP-operated fields are as follows: MITs are past due for the following wells (injecting as of 7/31/2006) 1) PBU 04-13; due 1/8/2006 2) PBU S-lOl; due 2/25/2006 3) PBU NK-13; due 5/4/2006 4) PBU X-36; due 5/20/2006 5) PBU R-25A; due 7/24/2006 The following shut in wells are past their due date for MIT 1) MPU H-06; due 2/28/2006 (SI since 7/2002) 2) PBU WGI-01; due 4/22/2006 (81 since 12/12/2005) 3) MPU F-41; due 5/14/2006 (SI since 5/2005) 4) PBU 8-31A; due 6/1/2006 (81 since 12/2004) 5) PBU P1-01; due 6/4/2006 (SI since 6/2006 for workover) 6) PBU Pl-25; due 7/2/2006 (SI since 6/2006) 7) PBU GC-02C; due 7/22/2006 (SI since 4/2006) A MIT for each well injecting on the list should be conducted as soon as practical; please notify the Commission for an opportunity to witness. Regarding SI injectors, the Commission suggests deferring testing (at least 20f4 9/25/20069:15 AM . v " ,~ .. . . / V_. v j. ~ . V~ \' ,~ .. ~v ,.n ~J" \' ,'--' " '/... . the Commission's witnessed test) until injection is recommenced and well conditions have stabilized. There's also two wells with MITs that have apparently been done (not witnessed) that we would like to have for our database: 1) PBU 03-10; MIT 9/30/2005 (CMIT IAxOA) 2) PBU 04-08; MITs (IA and OA) done per monthly injector rpt; date unknown As with all operating companies, the Commission is willing to work with you to take advantage of operating efficiencies in scheduling MITs (perform multiple MITs per pad; perform tests during the more temperate months; etc.). Feel free to call if you have any questions, and thank you in advance for your prompt attention to those MITs that are past due. Jim Regg AOGCC Content-Description: MIT PBU S-lOl 11-23-03.xls MIT PBU 8-101 11-23-03.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 Content-Description: MIT GPMA Pl-25 09-06-06.xls MIT GPMA P1-25 09-06-06.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU 04-13 08-1O-03.xls MIT PBU 04-13 08-10-03.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU 04-08 08-04-05.xls MIT PBU 04-08 08-04-05.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU R-25A 06-12-05.xls MIT PBU R-25A 06-12-05.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 3 of 4 9/25/2006 9: 15 AM V~ IV'-.! lLJ ,. /v~,vh v-.-vu \' ,'--' cr, 'VV'."-kJn \' .lU cr, /... . Content-Description: MIT PBU 03-10 09-30-05.xls MIT PBU 03-10 09-30-05.xIs Content-Type: applicationlvnd.rns-excel Content-Encoding: base64 Content-Description: MIT PBU NK-13 09-19-06.xls MIT PBU NK-13 09-19-06.xIs Content-Type: applicationlvnd.rns-excel Content-Encoding: base64 4 of 4 9/25/2006 9: 15 AM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test q (ZÇ(D0 ''R êt{tt Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay 1 PBU 1 S pad 11/23/03 Jeff Rea Packer Depth Pretest Initial 15 Min. 30 Min. We1l1S-101 I Type Inj. , W TVD I 6,685' Tubing 1,820 1,820 1,820 1,820 Interval I 0 P.T.D. 2001150 I Typetest I P Test psi I 1671.25 Casing 100 4,000 3,930 3,920 P/FI P Notes: MIT-IA pre-MI swap. OA 200 540 550 550 Weill I Type Inj. I I TVD I Tubing Interval P.T.D.I I Type test I I Test psil Casing P/F Notes: OA Weill I Type Inj.' I TVD I Tubing Interval I p.T.D.1 I Typetestl I Test psi I Casing I P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval P.T.D.I I Type testl Test psil Casing I I P/FI Notes: OA I I Weill Type Inj.1 TVD I Tubing Interval I P.T.D.I I Type test I Test psil Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT PBU 5·101 11·23·03-1.xls MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Suspend 0 Repair Well 0 Pull Tubing 0 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate 0 WaiverD Stimulate 0 Time ExtensionO Re-enter Suspended Well 0 Conversion to Inj 5. Permit to Drill Number: 200-1150 Other[!] Name: BP Exploration (Alaska), Inc. 64.41 8. Property Designation: ADL-0028258 11. Present Well Condition Summary: Stratigraphic D 9. Well Name and Number: S-101 10. Field/Pool(s): Prudhoe Bay Field / Aurora Oil Pool Exploratory 0 Service ŒI 6. API Number 50-029-22968-00-00 Development D 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Plugs (measured) RECEIVED MAR 0 5 ZOQAne Total Depth measured 11721 feet true vertical 6753.0 feet Effective Depth measured 11700 feet true vertical 6752.1 feet Junk (measured) p'l 'ë~, f'~~ CO""! 'AJmrm~sìon ~,hr:l!! .'" \\ ,;'\"~ ~ I, It., ' i~nc.honigB Casing Conductor Liner Production Surface Length 81 3012 8881 3987 Size 20" 91.5# H-40 4-1/2" 12.6# L-80 7" 26# L-80 10-3/4" 45.5# L-80 MD TVD Burst 1490 8430 7240 5210 Collapse 470 7500 5410 2480 28 109 28.0 - 109.0 8709 - 11721 6700.2 - 6753.0 27 - 8908 27.0 - 6784.0 27 - 4014 27.0 - 3392.8 Perforation depth: Measured depth: 8850 - 8930, 8930 - 8960, 9535 - 11700 :'VE.D¡ , ,,( 0 5 200~ True vertical depth: 6760.49 - 6791.24,6791.24 - 6799.64,6780.41 - 6752.13 Tubing ( size, grade, and measured depth): 3-1/2" 9.3# L-80 @ 23 8713 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer 4-1/2" External Casing Packer @ 8673 @ 8709 @ 9429 .Þ'¡ I'~~, G~S Comt ~nt~'~O~;};\p)r, ':,;c\n 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Prior to well operation: Subsequent to operation: Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure 494 9.5 1 1860 1380 0 0 4500 1860 1838 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD Service ]] 16. Well Status after proposed work: S'ï¡" Operational Shutdown D OilD GasO WAG' GlNJO WINJŒ WDSPLD Daily Report of Well Operations. 1{ Prepared by Garry Catron (9 7) 564-4657. 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: Contact Garry Catron 301-085 Printed Name Garr Catron Title Production Technical Assistant Copies of Logs and Surveys run- Signature Phone 564-4657 Date 3/5/04 Form 1 0-404 Revised 12/2003 ,"" "..,i::", 'I ' ",II,',:, ~~~~¡Î~;~I~' .. @ ,~Q) ! "(1JW~ . OR'GiNAl S-101 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/14/01 Dummy off GL V Station 4 04/15/01 Dummy off GL V Stations 3 and 2. Load IA w/seawater & freeze protect to 2000' w/Meth/water. T est to 3000 psi. 04/16/01 MITIA to 3000 psi, passed. 12/09/01 Put on Injection. FLUIDS PUMPED BBLS 130 Seawater 60 60/40 Methanal 190 TOTAL Page 1 lREE=4-1/16"- 5MCW, a-IROME WELLHEL\D = 13-518" - 5M FMC SH ACTUA. TOR = BAKER KB. REV = 64.45' BF. REV = KOP= 1046' Max Angle = 97 @ 9343' Datum MJ = 10122' Datum TVD = 6700' SS 8-1 01 10-3/4" CSG, 45.5# 1ft, L-80, BTC,ID = 9.950" SAFETY NOTES: WELL HAS 3-1/2" CHROME TUBING 3-112" foES X NIP, ID = 2.75" ST MD 4 4437 3 7309 2 8248 1 8553 GAS LIFT MANDRELS TVD DEV VLV lYPE LATCH PORT DAlE 3690 44 CA M MG BXP RK 5786 40 CA M MG BXP RK 6487 52 CA M MG BXP RK 6634 65 CA M MG BXP RK 3-1/2" TBG, 9.2#, 13-CR-80 FOX, .0087 bpf, ID = 2.992" Minimum ID = 2.75" @ 2206' 3-1/2" HES X NIPPLE I TOP OF 4-112" LNR 1 I 7" CSG, 26# 1FT, L-80-BTC-M, ID = 6.276" (-I 8880' PERFORATION SUMMARY REF LOG: MWD ON 08/08100 ANGLE AT TOP PERF: 96 @ 8850' Note: Refer to Production œ for historical perf data SIZE SPF INlERVAL Opn/Sqz DAlE 4-/12" 6 8850 - 8960 0 03/30101 4-1/2" S 9535 - 11699 SLID 08/31/00 --1 3-112" ÆSX NIP,ID =2.75" 1 7" BAKERZXPPKR, D =4.437" I 4 112" XO, w IWLEG I 7" X 5" BOT LNR HGR-HYDR, ID = 4.437" I 7" X 4-1/2" XO BOT, D = 3.938 I ELMD TT NOT LOGGED I -I PROFILE NIP-BOllND SUB, ID = 3.844" I I I 9410' -i BOTHMCV, ID= 3.958" I TOP OF 4-1/2" SLTD LNR 12.6#, L-80 IBT, ID = 3.958" -I 9535' -i PROFILE NIP-BOllND SUB, ID = 3.844" I -i EXlERNAL CSG A<R,ID = 3.958" I 1 11699' 1--1 4112" DRILLABLE P.O. BUSHNG I 11721' I BOTTOM OF SLOTTED LNR I I 4-1/2" LNR, 12.6#/ft, L-80 1 11700' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/24/00 ORIGINAL COrvPLErION 11/13/00 SIS-SL T CONVERfED TO CANVAS 01/26/01 S IS- L G REVISION 03/07101 CHiKA K CORRECTIONS 04/10101 KAK ÆRFS 04/09/03 DRSlTP lV D'MD CORREellONS AURORA UNIT WRL: S-101 PERMIT No: 2001150 API No: 50-029-22968-00 SEe 35, T12N, R12E, 4498' FEL & 4421' FSL BP Exploration (Alas ka) November 12, 2003 BP Exploration (Alaska) Inc 900 E Benson Blvd PO Box 196612 Anchorage, AK 99519-6612 (907) 561-5111 Tom Maunder Alaska Oil and Gas Conservation Commission 333 W 7th Ave, Ste 100 Anchorage, AK 99501 Re: Sundry Notice for S- 101 HPBD Dear Tom: A High Pressure Breakdown (HPBD) will be performed to stimulate injector S-10Ii. The HPBD will use fracturing equipment to provide short-term 40-50Mb/d Injection rates with viscous fluid and establish increased fracture conductivity to reservoir. Rock salt will be used to divert injection to more reservoir and achieve multiple fractures for maximum injectivity. If you have any questions, please contact Jim Young, Aurora Petroleum Engineer at 564- 5754 or by email at Youn~j3@bp.com. Sincerely, !3 Jim Young ', Aurora Petroleum Engineer Enclosures (2) in duplicate ac STATE OF ALASKA ~ ALAS OIL AND GAS CONSERVATION CO ,..,SSION APPLICATION FOR SUNDRY APPROVAL 2O AAC 25.28O 1. Type of Request: Abandon BI Suspend D Repair Well Pull Tubinq Alter Casin.q D Chan.qe Approved Pro.qram D BP Exploration (Alaska), Inc. 2. Operator Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 64.41 KB 8. Property Designation: ADL-0028258 Operation Shutdown D Perforater'-~ Plu.q Perforations D StimulateD[] Variancer-] Annular DisposalD Time Extension E] Otherr-1 Perforate New Pool D Re-enter Suspended Well r-~ 4. Current Well Class: 15. Permit to Drill Number: Development D Exploratory r~] 16 200-1150 · APl Number I StratigraphicE] Service ~-] 50-029-22968-00-00 9. Well Name and Number: S-101 10. Field/Pool(s): Prudhoe Bay Field ! AURORA Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): 11721 Casing Total Depth TVD (ft): 6753.0 IEffective Depth MD (ft): i Effective Depth TVD (ft): 11700 6687.7 Length Size top 28 MD bottom TVD top bottom 28.0 Plugs (md): None Burst Junk (md): None Collapse Conductor 81 20" 91.5# H-40 - 109 109.0 1490 470 Liner 3012 4-1/2" 12.6# L-80 8709 - 11721 6700.2 6753.0 8430 7500 Production 8881 7" 26# L-80 27 - 8908 27.0 6784.0 7240 5410 27.0 3392.8 3987 27 Surface 5210 - 4014 10-3/4" 45.5# L-80 2480 Perforation Depth MD 8850 - 11700 8930 - 8960 9535 - 8930 Perforation Depth TVD (ft): Tubing Size: 6780 - 6752.13 3.5" 6791 - 6799.64 6760 - 6791.24 9.3 # Tubing Grade: L-80 I Tubing MD (ft): 23 - 8713 I Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer 4-1/2" External Casin~l Packer 2. Attachments: Description Summary of Proposal [X~ Detailed Operations Program ["] BOP Sketch ['-I 14. Estimated Date for November 16, 2003 Commencin~j Operatic 6. Verbal Approval: Date: Commission Representative: Packers and SSSV MD (ft): /~ .. ;,,, ? "' 2003 8709,~ ,. 942c~,~,E~ -' . .., 3. Well Class after proposed work: ~J~ Exploratow~ Development~ Se~ice~ 5. Well Status after proposed work: Oil E] GasE] PluggedE] Abandoned E] WAG D G'NUD WINJ[~ WDSPLD Perpared by Garry Catron 564-4657, 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Title Phone Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP TestD Mechancial Integrity TestD Contact Jim Youn9 Petroleum Engineer 564-5754 11/12/03 I Location Clearance E~ Sund~¢~m~,er:F ~,~ d Other: Subsequent Form Required: Approved by: Form 10 403 Revised~/2003 BY ORDER OF THE COMMISSION Date: SUBMIT IN DUPLICATE Sl01i HPBD Pump Schedule STEP COMMENTS FLUID PUMP DIRTY VOLUME DIRTY VOLUME PROPPANT/DIVERTERS CLEAN VOLUME # TYPE RATE STAGE CUM STAGE CUM PPA STAGE CUM PROP CUM RS GROSS GW DSL (BPM) (BBL) (eeL) (GAL) (GAL) (LBS) (LBS) (LBS) (BBL) (BBL) (BBL) Stage #1 HPBD I HPBD/SDT Slick Water (1 gpt J313) 40 200 200 8400 8400 200 200 2* I ppa 16/20 Slick Water (1 gpt J313) 40 50 250 2100 10500 I 2011 2011 48 48 3* HPBDIFlush Slick Water (1 gpt J313) 40 200 450 8400 18900 200 200 Perform a SDT during last 10 bbls, SD and obtain ISlP Stage #2 DiversionlHPBD/Scour 4 2 ppg Rock Salt Gelled Diesel 10 40 490 1680 20580 2 3360 3360 37 37 5 GD Spacer Gelled Diesel 10 t 0 500 420 21000 10 10 6 2 ppg Rock Salt Gelled Diesel 10 30 530 1260 22260 2 2520 5880 28 30 7 GD Spacer Gelled Diesel 10 15 545 630 22890 15 15 8 HPBD Slick Water (1 gpt J313) 15-20 100 645 4200 27090 100 1 O0 9 I ppa 16/20 Slick Water (1 gpt J313) 20-25 25 670 1050 28140 1 1006 3017 24 24 10 HPBDIFlush Slick Water (1 gpt J313) 40 130 800 5460 33600 130 130 Perform a SDT during last 10 bbls, SD and obtain ISlP Stage ~ DiversionlHPBD/Scour 11 2 ppg Rock Salt Slick/Gelled Diesel 10 20 820 840 34440 2 1680 7560 18 18 12 GD Spacer Slick/Gelled Diesel 10 10 830 420 34860 10 10 13 2 ppg Rock Salt Slick/Gelled Diesel 10 15 845 630 35490 2 1260 8820 14 15 14 GD Spacer Slick/Gelled Diesel t0 10 855 420 35910 10 10 15 HPBD Slick Water (1 gpt J313) 15-20 100 955 4200 40110 1 O0 1 O0 __ 18 HPBD YF130LG 40 100 1055 4200 44310 100 100 17 2ppa 16/20 YF130LG 20-25 75 1130 3150 47460 2 6034 9051 72 72 18 HPBDIFlush Slick Water (1 gpt J313) 40 90 t 220 3780 51240 90 90 TOTALS 1220 51240 9051 8820 1205 1064 145 RATE FRICTION FRICTION EST Pipe <<for slick water WELL AND TREATING PRESSURE INFORMATION FACTOR PRESSURE WHTP Time with J313 FRAC GRADIENT= 0.65 BHTP-- 4794 5 0.0070 61 2560 16.4 FLUID GRADIENT= 0.443 HYD HEAD= 2995 10 0.0240 209 2708 8.2 MD TO Tbg Tail = 8712 PERF FRIC-- 700 15 0.0510 444 2944 5.5 TVD TOP A SAND PERF= 6760 20 0.0860 749 3249 4.1 MD TOP A SAND PERF= 8850 25 0.1310 1141 3641 3.3 TUBING HANGER= 0 30 0.1830 1594 4094 2.7 UPPER TUBING SIZE= 3.500 0.o087 bbls.lfl 35 0.2440 2126 4625 2 MIDDLE TUBING SIZE= 4.500 o.o152 bbls./ft 40 0.3120 2718 5217 2.0 LOWER TUBING SIZE= 4.500 0.0152 bbls./ff TANKS REQUIRED= 2.4 <<60 deg Seawater f/CPF2 LENGTH OF MIDDLE TBG= 138 GD REQUIRED= 145 <<bring 160 bbls LENGTH OF LOWER TBG= 0 PROPPANT REQUIRED=- 9051 << bring 10,000~ CASING SIZE= 7.000 0.0382 bbls./lt ROCK SALT REQUIRED= 8820 <<brin~110000~ FLUSH VOLUME TO TOP PERF= 82.0 NOTES: 1. Pump HPBD at MAX rate possible. **Only pump if deemed necessary from SDT 2. The diversion stages should be modified as appropriate, pending success of the rock salt slugs. 8/21/2oo3 TREE= 4-1/1~" - 5M Ck, V, CHROIVE WELLHEAD: 13-5/8" - 5M FMC SH ACTUATOR: BAKER KB. ELEV: 64.45' BF. ELEV = KOP = 1046' Max Angle = 97 @ 9343' Datum ~ = 10122' Datum TVD = 6700' SS S-101 2206' SAFETY NOTES: WELL HAS 3-112" CHROME TUBING H 3 -1/2"FESXNIP, ID=2.75" I I 10-3/4"CSG, 45.5~/ft, L-80, BTC, ID H 4014' IMinimum ID = 2.75" @ 2206' 3-1/2" HES X NIPPLE 3-1/2"TBG, 9.2#, 13-CR-80 FOX, 8712' .0087 bpf, ID: 2.992" TOP OF 4-1/2" LNR I-"~ 8736' I 7" CSG, 26# / FT, L-80-BTC-M, ID = 6.276" Id 8880' 8661' 8674' 8699' 8709' 8713' 8724' 8731' I H H H I-I I-I GAS LIFT MANDRELS 'PE I ATCHIPORTI CAMMG B:~ IRK I I CA MMG B'XP IRK I I ' CA MMG B)~P ]RK ] I i CA MMG BN:)] RK I I I 3-1/2" FESX NIP, ID =2.75" 7" X 4-1/2" BAKER S-3 FKR-NSCT W/ ] I XO PUPS TO 3-11Z', ID = 3.875" 3-1/2" X NIP, ID = 2.75" I 7" BAKERZXPPKR, D =4.437" I 4 1/2" XO, w/WL EG I 7" X 5" BOT LNR I-IGR-HYDR, ID = 4.437" 7" X 4-1/2" XO BOT, D = 3.938 ELIVO TI' NOT LOGGED PERFORATION SUMMARY REF LOG: MWD ON 08/08/00 ANGLE AT TOP PERF: 96 @ 8850' Note: Refer to Production DB for historical )erf data SIZE SPF INTERVAL Opn/Sclz DATE 4-/12" 6 8850 - 8960 O 03/30/01 4-1/2" S 9535 - 11699 SLTD 08/31/00 TOP OF 4-1/2" SLTDLNR I.-I I 9535' I I BOTDOMOFSLO'ITEDLNR H 11700' I 4-1/'Z' LNR, 12.6##t, 1_-80 H 11721' 9402' Id 9410' Id H ~ i9429' H DATE REV BY COIVIVIENTS DATE REV BY COMMENTS 08/24/00 I ORIGINAL COrvPL ETLON 11/13/00 SIS-SLT OONVERTED TOCANVAS 01/26/01 SIS-LG REVISION 03/07/01 CH/KAK CORRECTIONS 04/10/01 KAK PERFS 04/09/03 DRS/TP TV D/MD CORRECTIONS , PROFILE NIP-BOTIND SUB, ID: 3.844" I BOT HMCV, ID = 3.958" PROFILE NIP-BOTIND SUB, ID: 3.844" EXTERNAL CSG PKR, ID = 3.958" 4 1/2" DRILLABLEP. O. BUSHING AURORA UNIT WELL: S-101 PERMIT No: 2001150 APl No: 50-029-22968-00 SEC 35, T12N, R12E 4498' FEL & 4421' FSL BP Exploration (Alas k a) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ SCHMOO-B-GONE Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 859' FNL, 4499' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 1644' FNL, 4306' FEL, Sec. 34, T12N, R12E, UM At effective depth 4715' FNL, 745' FEL, Sec. 28, T12N, R12E, UM At total depth 4699' FNL, 759' FEL, Sec. 28, T12N, R12E, UM 5. Type of Well: Development _ Exploratory__ Stratigraphic__ Service X (asp's 618930, 5980624) (asp's 613856, 5979760) (asp's 612101, 5981943) (asp's 612087, 5981959) 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-101 9. Permit number / approval number 200-115 / 301-085 10. APl number 50-029-22968-00 11. Field / Pool Prudhoe Bay Field/Aurora Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 109' Surface 3984' Production 8850' Liner 3012' 11721 feet Plugs (measured) 6753 feet 11700 feet Junk (measured) 6752 feet Size Cemented Measured Depth True Vertical Depth 20" 260 sx AS (Approx) 139' 139' 9-5/8" 750 sx AS III, 241 sx 'G' 4014' 3393' 7" 690 sx Class 'G' 8880' 6773' 4-1/2" 73 sx Class 'G' (solid & 8709' - 11721' 6700' - 6753' slotted liner) Perforation depth: measured Open Perfs 8850'-8960', Slotted Liner 9535' - 11699' true vertical Open Perfs 6775'-6800', Slotted Liner 6780'-6752'. Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3-1/2", 9.2#, 13-CR-80, TBG @ 8674' MD; 3-1/2", 9.2#, 13-CR-80, Tubing Tail @ 8712' MD. 7" x 4-1/2" Baker 'S-3' PKR @ 8674' MD w/XO PUPS to 3-1/2". ~E tV E ~09'. 3-1/2" HES 'X' Nipple @ 2206' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see NOV 0 '2002 Treatment description including volumes used and final pressure 14. ., Representative Daily Averaqe Production or Iniecti ~ t]~ ~,u,~. ,,,~,-~ .... -,--- Am,.h IOEi1 0rue OiI-Bbl Gas-Ucf Water-Bbl Ca§ifl~'P?essb1'~ Tubing Pressure Prior to well operation 10/15/2002 4502 1907 Subsequent to operation 10/24/2002 5145 2011 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil_ Gas_ Suspended__ Service WATER INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~,~p~.~ ,~~~ Title: Technical Assistant e ayne R. Schnorr Form 10-404 Rev 06/15/88 · Date October 25, 2002 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE 04/16/2001 05/30/2001 06/03/2001 06/28/2001 08/31/2001 09/01/2001 11/28/2001 12/09/2001 1 2/18/2001 1 2/21/2001 12/25/2001 04/03/2002 10/17/2OO2 1 O/23/2OO2 04/16/01 05/30/01 06/03/01 06/28/01 08/31/01 09/01/01 11/28/2001 12/09/2001 12/18/01 02/21/02 $-101 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ANNCOMM --- MITIA PASSED TO 3000 PSI, PRE-INJECTION START SBHP/FBHP SURVEY: D/T SBHPS MISC-CAP SUST.: HOT OIL TUBING SBHP/FBHP SURVEY: DRIFT/TAG IPROF: RST WFL / INJECTION PROFILE IPROF: RST WFL / INJECTION PROFILE CONVERTED TO WATER INJECTION WELL FIRST DAY OF WATER INJECTION AFTER CONVERSION ANNCOMM --- T/I/O = 2000/900/580. IA FL for up coming MIT-IA @ ANN-COMM (UIC PROGRAM): AC-MITIA ANN-COMM (UIC PROGRAM): AC-MITIA T/I/O: 1200/100/0 MEASURED INSIDE DEPTH OF FLUTES ON THE CONDUCTOR PIPE. FRONT SIDE IS 1' 2", BACK SIDE IS 1' 2". SCMOO-B-GONE--SBG: SCMOO-B-GONE TESTEVENT--- INJECTION PRESSRUE, PSI: 2,011 TYPE: PW VOL: 5,145 BPD. EVENT SUMMARY ANNCOMM --- MITIA PASSED TO 3000 PSI, PRE-INJECTION START. RIH W/2.28" CENT& SAMPLE BAILER SET'DOWN @ 845' SLM TAP DOWN SD @ 854' SLM UNABLE TO WORK PAST POOH RDMO. <<< WELL SHUT-IN FOR SBHPS >>>. HOT OIL TUBING W/10 DIESEL AND 61 CRUDE. DRIFTED TO 9006'SLM W/2.70"CENT, TOOLS STOPPED FALLING DUE TO DEVIATION (HAW). RAN INJECTION PROFILE / STEP-RATE INJECTION PRESSURE TEST AND RST. RST WFL DID NOT DETECT FLOW BEHIND CASING ABOVE PERFS. POSSIBLE GCC @ 8860' DID NOT CONFIRM. MAX'D PUMP OUT @ 5.5 BPM @ 1750 PSI, UNABLE TO LOG @ HIGHER INJECTION PRESSURES. CONVERTED TO WATER INJECTION WELL. FIRST DAY OF WATER INJECTION AFTER CONVERSION. ANNCOMM --- T/I/O = 2000/900/580. IA FL FOR UP COMING MIT-IA @ SURFACE. MITIA PASSED TO 3000 PSI (PRE-STATE WITNESSED, NEW INJECTION WELL). NOTE INITIAL IA FL @ 1800'. Page I S-101 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/23/02 O4/O3/O2 MITIA PASSED to 2800 psi (AOGCC WITNESSED - JEFF JONES, NEW INJECTOR). ANNCOMM --- T/I/O = 1200/100/0 MEASURE INSIDE DEPTH OF FLUTES ON THE CONDUCTOR PIPE. FRONT SIDE IS 1'2", BACK SIDE IS 1' 2". 10/17/02 SCHMOO-B-GONE TREATMENT ON TBG/PUMPED 200 BBLS SCHMOO-B-GONE MIX / 3 HOUR SOAK / FLUSH WITH 175 BBLS HOT SH20 / TURNED WELL OVER TO PAD OPERATOR FOR 3 HOUR SOAK. 10/24/02 TESTEVENT--- IN3ECTION PRESSURE, PSI: 2,011 TYPE: pw VOL: 5,145 BPD. Fluids Pumped BBLS 0 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL 82 METHANOL WATER 13 DIESEL 61 CRUDE 850 2% KCL WATER 175 SEAWATER 201 SCHMOO-B-GONE 1382 TOTAL Page 2 TREE=4-1/16" - 5M CIW, CFROME WR LHEAD=I 3-5/8" - 5M FMC SH A CTUA TOR= BAKER KB. ELEV = 64.45' BF. ELEV = KOP = 1046' Max Anc~le: 97 ~_ 93_ ~43; Datum MD = 9592' Datum TVD= 6764' 10-3/4" CSG, 45.5ffift, L-80 I I 4014' BTC, ID= 9.950" IMinimum ID = 2.75"@ 2206' I 3-1/2" HES 'X' NIPPLE S-101 3-1/2" 'I'BG, 9.2#, 13Q'-80 FOX I .0087 bpf, D= 2.992" TOP OF 4 1/2" LNR I 8712' 8736' 8880' 7" CSG, 26#/ft, L-80-BTC-M .0383 bpf, ID= 6.276" PERFORATION SUMMARY RIE: LOG: IVlWD 8/8/00 ANGLE AT TOP PEF~: I ~ I Note: Refer to Production DB for historical ~erf data SIZE SPF INTERVAL Opn/SqZ DATE 4-/12" 6 8850-8960 O 03130101 4-1/2" S 9535-11699 SLOT 08/31/00 TOPOF 4 1/2" SLOTTED LNR I i 9535' 2.6#, L-80 IBT, ID= 3.958" I BOTTOM OF SLOTTED LNRI I 7oo' 4-1/2'' LNR' 12.~/ft' L'80 I I 11721' I DATE FEV BY COMrvENTS 08/24/00 ORIGINAL COIVPL EFION 11/13/2000 SIS-SLT CONVERTED TO CANVAS 1/26/2001 SIS-LG REVISION 03/07/01 CH/KA K CORRECTIONS 4/9/2001 KAK PERFS SAFETY NOTES: WELL HAS 3-1/2" CFROME TUBING 2206' I I 3-1/2'I-IES"X" Nipple, ID= 2.75" I GAS LFT MAhDRELS TYPE MAN CA MMG BXP CA MMG BXP CA MMG BXP CA MMG BXP RK RK RK 8661' I I 3-1/2" HES 'X' Nipple' ID= 2'75" I 8674' I I 7" x 4-1/2" Baker 'S-3' FKR-NSCT with I XO PUPS to 3-1/Z', D= 3.875 8699' I I3-1/2'' 'x' Nipple' ID= 2'75'' I 8709' I I 7"BAKERZXPPKR'ID=4'437"I I I I 8724' I I BOTiD=4.437,7X 5" Lher Hanger-HYDR, 8731' I I BOtXT'~ x 4'1'2" XO'ID:3'938 I I1-1' ELM NOT LOGGED I 9402' ~ Profile Nipple-BOTIND. SUB '1 ID= 3.844" 9410' h"l BOTHMCV, ID=3.958"I 9421' H Profile Nipple'BOTIND'SUB' ID= 3'844" I EXTERNAL CSG PACKER I ID= 3.958" I 11699' m---1 41/2,, DRILLABLE I RO. BUSHNG AURORA UNIT WELL: S-101 PERMIT No: 200-1150 APl No: 50-029-22968-00 SEC35, TEN, R12E BP Exploration (Alas ka) , Permitto Drill 2001150 MD 11721 ~ TVD DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. PRUDHOE BAY UN AURO S-101 Operator BP EXPLORATION (ALASKA) INC 6753 ~- Completion Dat 9/8/2000 ~ Completion Statu 1-OIL Current Status 1-OIL APl No. $0-029-22968-00-00 UIC Y REQUIRED INFORMATION Mud Log N._~o Sample N_go Directional Survey N...~o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments ED T RS Reservoir Saturation R R 1 TVD GR/Res 2 ]~ t FINAL MD ROP/GR/Res 2 y~l~l FINAL TVD GR/Litho/CNP/ 5 ~ / FINAL Neu Por MD GPJLitho/CNP/Neu 5 ~ ~ I FINAL Por 9832 ~1 FINAL LIS Verification FINAL 9812'~ 1-6 SCMT 5 FINAL RST Sigma 5 FINAL MWD Formation Eval comp MWD LIS Res/GR MD 2/5 FINAL Res/GR 'rVD. 2/5 FINAL "~Nea/Den MD' 2/5 FINAL ~n TVD 2/5 FINAL 9946 FINAL ~Profile 2/5 FINAL 449 8113 8827 449 503 503 503 503 3700 6500 449 503 5O3 5O3 503 8113 6500 11670 9002 8975 9843 9894 9894 9894 9894 8700 9000 9843 11721 11721 11721 11721 9002 9000 Open 10/5/2000 09812/-'4'~9-11670 Case 3/9/2001 09946 ~ 13-9002 Case 10415 ,Caeeb~ 2/22/2001 09832 '-~t~-9843 CH 2/21/2001 503-9894 BL, Sepia CH 2/21/2001 503-9894 BL, Sepia CH 2/21/2001 503-9894 BL, Sepia CH 2/21/2001 503-9894 BL, Sepia 2/22/2001 9832 ~."L~S Verification Digital Data 2/22/200,1 LIS Verification Paper Copy OH 10/5/2000 9812 ~-SPERRY IMP/GR/EWR4/CNP/SLD CH 9/26/2000 BL(C) 3700-8700 ch 10/30/2001 6500-9000 BL, Sepia 1/9/2001 449-9843 Digital Data 1/9/2001 Verification Listing CH 1/9/2001 503-11721 BL, Sepia CH 1/9/2001 503-11721 BL, Sepia CH 1/9/2001 503-11721 BL, Sepia CH 1/9/2001 503-11721 BL, Sepia ch 3/9/2001 9946--""8113-9002 Digital Data CH 10/16/2001 6500-9000 BL, Sepia Permit to Drill 200t 150 DATA SUBMITTAL COMPLIANCE REPORT 91912002 Well Name/No. PRUDHOE BAY UN AURO S-101 Operator BP EXPLORATION (ALASKA) INC MD 11721 TVD 6753 Well Cores/Samples Information: Name Completion Dat 9/8/2000 Completion Statu 1-OIL Interval Start Stop Sent Received Current Status 1-OIL Dataset Number Comments APl No. 50-029-22968-00-00 UIC Y ADDITIONAL INFORMATION Well Cored? Y/N~ Chips Received? Analysis ..~ Y / N R~.c~.ived? Daily History Received? Formation Tops (~N Comments: Compliance Reviewed By: Date: 10/24/2001 Scblumbe Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-$711 ATTN: Sherrie NO. 1562 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Aurora Well Job # Log Description Date Color Sepia BL CD S-101 ,C~OC~tlc--~ 21428 RST-SIGMA ~/"~ 09/01/01 1 1 1 L-117 0':,~1-1t.~ '"'1 21407 DSI/CMR '/ 09/25/01 1 L-117 21407 DSl v"" 09/25/01 1 1 L-117 21407 CMR ~ 09/25/01 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED OCT 50 2001 /v. asl~ Oil & Gas Cons. Commissior, An~orage Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATrN: Sherrie 10/15/2001 Schh berger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1526 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Well Job # Log Description Date Color Sepia BL CD S-t01 ~ ~)-- j' J ~ INJECTION PROFILE 09/01101 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED OCT 1 6 2001 Alaska Oil & Gas Co~s. comm'asio~ Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie S-101 Water-flow log for injection certification ( Subject: S-101 Water-flow log for injection certification Date: Wed, 16 May 2001 14:55:13 -0500 From: '~'oung, Jim" <YoungJ3@BP.com> To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak. us> CC: "Smith, Bruce W" <SmithBW@BP.com> Tom, Attached is a draft of the proposed injection test & logging to certify S-101 as capable of injection in accordance with 20 AAC 25.412. i've changed the logging program to identify fluid entry via temperature and confirm with a water-flow log (RST tool) to avoid the need for borax. After logging at Iow injection pressure, the repeat passes are designed to be above frac pressure to meet or exceed permanent injection conditions. Please let me know if this type of log would be acceptible for certification or if you have any questions. BPX would like to do this log a.s.a.p, so that we have time to evaluate & perform remedial work if necessary without impacting injection startup should the Area Injection Order be approved. > Jim Young > PE, GPB New Developments > youngj3@bp, com > (907) 564-5754 fax 5016 > <<S-101 Injector CertificationS-O1.ZIP>> ~--~S-101 Injector Certification5-01 .ZIP Name: S-101 Injector CertificationS-Ol.ZIP Type: Zip Compressed Data (application/x-zip-compressed) Encoding: base64 1 of I 6/19101 3:21 PM Aurora Reservoir Surveillanc( bp Memorandum To: G. McBride/J. Smart Date: May 15, 2001 GPB Well Ops Team Leaders From: Subject: Jim Young 564-5754, hm: 248-0133, cell: 440-8007 PE, GPB Westend New Developments S-101 Injector Certification PECT: F58AUR Est. Cost: $25,000 Est. IOR 3000 BOPD Due to questionable results from the cement bond log in S-101, a PITs/water-flow log is proposed to certify S-101 for permanent water injection. Per discussion with AOGCC, a Io.q is needed to provide a positive indication of iniection containment to the Kuparuk reservoir. Injection could begin after an area injection order is approved, as early as late June, so this information is needed in case the well needs remedial work prior to injection startup. The spinner will also be used to determine injection splits. s-101 1 s Drift/tag, SBHPS S-101 2 E Step-rate test, Water-flow log w/spinner. 7 day shut-in, late May, prior to rig-move Requires filtered 2% KCL water 1. Drift & obtain static temp/press at 8864' MD (6700' ss) and 8623' MD, (15-min stops). 2. Make base-line temp pass at 6500' while RIH at ~100fpm to 8960' (btm perf) 3. Load tubing & perform step-rate test with 2% filtered KCL water at: a. 1000psi,1500psi, 2000psi, and 2500psi Wellhead Injection Pressure (WHIP) b. Minimum 40 bbls each stage (tubing volume is ~80 bbls) c. Objective is to determine frac gradient and pre/post frac injectivity. d. Estimated frac pressure is 1800psi at 5bpm. 4. RIH with WFL (RST) tool in UPFLOW-mode, spinner, press/temp. a. Pump at minimum rates to sustain overbalance on perfs (>200psi WHIP) b. POOH from 8960'-6500' at 100fpm for temp survey while pumping. c. If temp anomaly above perfs is found, repeat passes at 30fpm near anomaly. d. Take station stops with WFL at 8840' and top of upward fluid movement as indicated by temp log for confirmation. e. Increase WHIP to > 1800psi (above frac pressure); repeat steps c&d. 5. Log spinner & RST passes 8850'-8960'+ (HAW/open hole below) to determine flow- splits and possible GOC at 8860' (log spinner at 1500psi WHIP). 6. Freeze protect, RDMO. LEAVE WELL SHUT-IN. Minimum ID: 2.750" ~ three X-nipples, see schematic Max. Deviation: 99° ~ 9440' md Last Tag TD: -9024' (HAW) Latest SBHP: 3060 psia, 149F at 9024' MD Recent events: Well Date Description of Work S- 101 Deviation at Tbg Tail: 65°~8712' Last Downhole Op: CT Perf 8850'-8960' Welltest: 900 BOPD, 24MMCFD, 2000psi 04/15/2001 MISC-CAP SUST.: DUMMY OFF GLM'S / PT IA 3000 PSI (PRE INJ) Aurora Reservoir Surveillanc(' ~ s- 04/14/2001 MISC-CAP SUST.: DUMMY OFF GLM'S (PRE WATER 1NJ) 101 S- 04/11/2001 MISC-CAP SUST.: C/O GLV'S TO DGLV'S (PRE-INJ CONV) 101 Re: FW: Aurora Water Injection Test - Application for Injection Order. (' Subject: Date: From: Organization: To: CC: Re: FW: Aurora Water Injection Test - Application for Injection Order. Fri, 04 May 2001 17:31:09 -0800 Jack Hartz <jack_hartz@edmin.state.ak.us> AOGCC '~oung, Jim" <YoungJ3@BP.com>, "Pospisil, Gordon" <PospisG@BP.com>, "Bakun, Fred E" <BakunFE~BP.com> Thomas E Maunder <tom_maunder@admin.state.ak. us>, Robert Crandall <bob_crandall~admin.state.ak. us> Jim, Commissioner Taylor informed me today that BPX needs to apply for an injection order to do the pilot test at S-101. The regulation is fairly straight forward as to what data and evaluation are needed for the order. You would have to do the same thing for the Area Injection Order so consider making the effort a one time application for the AIO. Also, it is my understanding that there amy be problems with the formation cement isolation in S-201. Those problems have to be addressed before injection can begin, after an injection order is issued. Email or call if you have any questions. Jack Hartz Jack Hartz wrote: Jim, I have been reading the regulation on Enhanced Recovery Operations, 20 AAC 25. 402, and it appears there may not be latitude for us to allow pilot test injection operations without going through the process of an application, public notice and opportunity for hearing under 20 AAC 25.540. That process takes about 30 days at the least, from receipt of application notice to earliest hearing date. A hearing is scheduled when the application is noticed in a newspaper. ! have asked the Commission for feedback on this issue, but I believe we are required to go this route. Let me know if you have any more questions. Jack "Young, Jim" wrote: Jack, I've been unable to catch you on the phone, so I'm using e-mail to get some information to you about Aurora so we can talk. BPX will be filing Pool Rules & AiO for Aurora within a month. Prior to approval of the AIO we would like to get a waiver to convert well S,101 to an injector and do a 6.month water injection test. S-101 was drilled as a horizontal well in the southern portion of the V.200 fault block as the second well of Phase I development drilling. Log 1 of 2 5/10/01 3:16 PM Re: FW: Aurora Water Injection Test - Application for Injection Order. analysis indicates the well had over 2500 feet of net pay. The 12/21/2000 production test produced 1062 bopd at a GOR of 20707 scf/stb. Well logs suggest a possible GOC in the toe of the well at ,~6660 feet tvdss. Initial AP! gravity was 47,~ °. Simulation indicates recovery from the V-200 block can be optimized by converting S-101 to injection and that there is potential to add additional injection wells. Recovery in this development block reaches 31% of the oil initially in place. Purpose of the test is as follows: 1) Establish injectivity into the Kuparuk formation with GC-2 produced water to determine needs for a booster pump. 2) Monitor reservoir pressure response to confirm inter-well connectivity injection rate requirements. Implementation plan: 1) Obtain water, flow log to verify injection containment into Kuparuk reservoir & certify well for injection service. 2) Measure injection rates at various injection pressures. 3) Obtain static pressure surveys in wells S-101 and S-100. 4) After 6-months, if results look ok and AIO is approved, continue permanent injection into S-101. Jim Young PE, GPB New Developments youngj3@bp.com (907) 564-5754 fax 5016 Jack Hartz <lack hartz~admin.state.ak, us> Sr. Petroleum Reservoir Engineer Alaska Oil & Gas Conservation Commission 2 of 2 5/10/01 3:16 PM Subject: S-101 Date: Wed, 18 Apr 2001 14:03:37 -0500 From: "Young, Jim" <YoungJ3@BP.com> To: "~tom_maunder~admin.state.ak. us'" <tom_maunder@admin.state.ak.us> ---Original Message~---- From: Young, Jim Sent: Wednesday, April 18, 2001 9:00 AM To: G ANC Wellwork Program; Stone, Dan M Cc: Pospisii, Gordon Subject: US letterhead generic (electronic) Gentlemen, Due to questionable results from the cement bond log in S. lOli, an injection temperature pass will need to be made prior to putting S-101i on permanent water injection. Per discussion with Tom Maunder with AOGCC on 4/16/01, a log is needed to provide a positive indication of injection containment to the Kuparuk reservoir. If the temperature log is not conclusive, a borax/RST log may be necessary. Injection into Well S-~O~ is proposed to provide pressure support to S-100 and replace voidage from the Aurora Reservoir. Jim Young PE, GPB New Developments youngj3@bp, com (907) 564-5754 fax 5016 S-101 E Injection temp/RST, possible Borax After Inj. conversion tie-in -5/1 S-~01 E MITIA to 3000psi post-injection startup After stabilized WHT, notify AOGCC < <S- l Ol i Conversion V2. doc> > Name: S-101i ConversionV2.doc ~S-101i ConversionV2.doc! Type: wINWORD File (application/msword) .!~Enc0dJng! base64 I of t 4/119/01 11:46 AM Aurora Reservoir Surveillance(~ bp Memorandum To: G. McBdde/J. Smart Date: 18 Apdl 2001 GPB Well Ops Team Leaders From: Subject: Jim Young 564-5754, hm: 248-0133, cell: 440-8007 PE, GPB Westend New Developments S-101 Injector Conversion PECT: F58AUR Est. Cost: $25,000 Est. IOR 3000 BOPD Due to questionable results from the cement bond log in S-101L an injection temperature pass will need to be made prior to putting S-101i on permanent water injection. Per discussion with Tom Maunder with AOGCC, a log is needed to provide a positive indication of injection containment to the Kuparuk reservoir. If the temperature log is not conclusive, a borax/RST log may be necessary. Injection into Well S-101 is proposed to provide pressure support to S-100 and replace voidage from the Aurora Reservoir. S-101 E Injection temp/RST, possible Borax S-101 E MITIA to 3000psi post-injection startup After Inj. conversion tie-in ~5/1 After stabilized WHT, notify AOGCC 1. RIH with FB spinner, temp, press, and RST and make baseline pass from 8712'(TT)-8880'. 2. Pull to safety depth as necessary, start PW injection at maximum rate and pressure. 3. Make passes as necessary from top perf, 8850' to tubing tail (8712'). ?W Temp-135F. 4. If temperature log indicates injection confinement, RDMO. 5. If no obvious temperature response or confirmation of confinement is present, pump ~100 bbls borax & look for presence of channels. 6. If confinement confirmed or no channels present, leave well on injection. 7. MITIA to 3000 psi after WHT stabilizes, Notify AOGCC in advance for opportunity to witness. S-101 Max. Deviation: Minimum ID: Last Tag TD: Latest SBHP: Recent events: WeRDate S-101 04/15/200 1 S-101 04/14/200 1 S-101 s-101 99° @ 9440' md Deviation at Tbg Tail: 65°@8712' 2.750" @ three X-nipples, see schematic ~9024' (HAW) Last Downhole Op: CT Perf 3060 psia, 149F at 9024' MD Welltest: 1800 BOPD, 24MMCFD, 2000psi Description of Work MISC-CAP SUST.: DUMMY OFF GLM'S / PT IA 3000 PSI (PRE INJ) MISC-CAP SUST.: DUMMY OFF GLM'S (PRE WATER INJ) 04/11/200 1 MISC-CAP SUST.: C/O GLV'S TO DGLV'S (PRE-INJ CONV) 04/10/200 SBHP/FBHP SURVEY: D/T-SBHP-SET DGLVS-MITIA (PRE H20 INJ)- 1 INPROGRESS Sou=ce AWGRS PBU PBU AWGRS PBU AWGRS PBU ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ (Injection test) Other _X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 858' FNL, 4498' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 1644' FNL, 4306' FEL, Sec. 34, T12N, R12E, UM At effective depth At total depth 4698' FNL, 758' FEL, Sec. 28, T12N, R12E, UM 5. Type of Well: Development __X Exploratory __ Strat~raphio _ Servia___ (asp's 618930, 5980625) (asp's 613856, 5979760) (asp's 612087, 5981959) 6. Datum elevation (DF or KB feet) RKB 64.41 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-101 9. Permit number / approval number 200-115 10. APl number 50-029-22968 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 109' 20" Surface 3950' 10-3/4" Production 8817' 7" Liner 3012' 4-1/2" 11721 6753 11721 6753 feet Plugs (measured) feet feet Junk (measured) feet Cemented 260 Sx AS 750 Sx AS Lite III & 241 Sx G 690 Sx Class G 73 Sx Class G (solid & slotted liner) Measured Depth 109' 4014' 8881' 11721' True vertical Depth 109' 3393' 6774' 6753' Perforation depth: measured 8850' - 8960'; Slotted liner interval f/9535' - 11699'. RECEIVED true vertical 6775' - 6800'; Slotted liner interval f/6780' - 6752'. Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) APR 0 G 2001 3-1/2", 9.2#. 13CR-80 Tbg @ 8713' MD. Alaska 0il & Gas Cons. Commission Anchorage 7" x 4-1/2" Baker S-3 Packer @ 8674' MD; 4-1/2" X 7" Baker ZXP Packer @ 8709' MD; External CSG Packer @ 9429' MD. 3-1/2" HES X Nipple @ 2206' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operation April 13, 2001 16. If proposal was verbally approved Name of approver Date approved Oil __ X Gas __ Suspended _ Service 17. I hereby certify t~t~he foregoing is true and correct to the best of my knowledge. Signed ~ {~'~l Title: Aurora Petroleum Engineer Jim Young f [, t FOR COMMISSION USE ONLY Questions? Call Jim Young @ 564-5754. Date April 5, 2001 Prepared by Paul Rauf @ 564-5799. Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance _ Mechanical Integrity Test _ Subsequent form required 10- I Appr°va' n°~,~d/' Approved by order of the Commission ,Original Signed By _.~ ..... fl,~heli Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE bp DS S-101 (r'~ Sundry Notice 10-403 Application 4/5/2001 BP Exploration (Alaska) Inc. 900 East Benson Boulevard Discussion ~.0. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Injection into Well S-101 is proposed to provide pressure support to S-100 and replace voidage from the Aurora Reservoir. Well is currently shut-in on must-not produce status due to high GOR. The well will be water only injectiOn into the Kuparuk Formation. Action Plan 1. Perform MIT prior to injection startup. 2. Hookup and pressure test injection flow-line with fail-safe automatic surface safety valve. 3. Establish stabilized injection at approximately 2000 psig injection pressure. 4. State witnessed MITIA after well temp/pressure stabilized and every 4 years to verify integrity thereafter. 5. Record wellhead presSures and rates daily and check annulus pressures V'¢ weekly to ensure there is no leakage. $~,'~ t\', ~,, ~~, 6. Notify AOGCC on next business day if the monitoring indicates any problem. RECEIVED APR 0 ~ 2001 Alaska Oil & Gas Cons. Commission Anchorage bp ( BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 995196612 (907) 561-5111 April 5, 2001 Jack Hartz Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Fax 276-7542 Re: S-101 Sundry Notice Dear Commissioners: Attached is a Sundry Application for BP Exploration (Alaska), Inc for well S-101. This Sundry Application requests a classification change for Well S-101 from a shut-in producer to an injector. The well. will be used for water injection only to do a six month injection test. The 7" casing will have an MIT test prior to and during injection and we believe control and proper monitoring of PWl injection can be maintained. Details of the proposed monitoring and testing routines to assure isolation are included as attachments to this correspondence. If you have any questions, please contact Jim Young @ 564-5754 or email me at youngi3 @ bp.com. Sincerely, Jim Young GPB West End New Developments Production Engineer RECEIVED APR 0 b 2001 Alaska Oil & Gas Cons, Commission Anchorage STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 858' FNL, 4498' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 1644' FNL, 4306' FEL, Sec. 34, T12N, R12E, UM At effective depth At total depth 4698' FNL, 758' FEL, Sec. 28, T12N, R12E, UM 5. Type of Well: Development _X Explorato~__ StratigraphY__ (asp's 618930, 5980625) (asp's 613856, 5979760) (asp's 612087, 5981959) 6. Datum elevation (DF or KB feet) RKB 64.41 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-101 9. Permit number / approval number 200-115 10. APl number 50-029-22968 11. Field / Pool Prudhoe Bay Field/Aurora Pool (undefined) 12. Present well condition summary Total depth: measured true vertical 1 1721 feet Plugs (measured) 6753 feet Effective depth: measured true vertical 11721 feet Junk (measured) 6753 feet Casing Length Conductor 109' Surface 3950' Production 8817' Liner 3012' Perforation depth: Size Cemented Measured Depth True vertical Depth 20" 260 sx AS 109' 109' 10-3/4" 75O Sx AS Lite III & 241 Sx G 4014' 3393' 7" 690 sx Class G 8881' 6774' 4-1/2" 73 Sx Class G (solid & slotted 11721' 6753' liner) measured 8850' - 8960'; Slotted liner interval f/9535' - 11699'. RECEIVED APR 06 2001 true vertical 6775' - 6800'; Slotted liner interval f/6780' - 6752'. Tubing (size, grade, and measured depth) 3-1/2", 9.2#, 13CR-80 Tbg @ 8713' MD. Alaska 0il & Gas Cons. C0mmissl0n Anchorage Packers & SSSV (type & measured depth) 7" X 4-1/2" Baker S-3 Packer @ 8674' MD; 4-1/2" X 7" Baker ZXP Packer @ 8709' MD; External CSG Packer @ 9429' MD. 3-1/2" HES X Nipple @ 2206' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 799 1725 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 19827 0 21920 15 Casing Pressure Tubing Pmssum 1549 1920 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X 16. Status of well classification as: Oil__X Gas__ Suspended_ Service 17. I hereby certify that tJ~ foregoing is true and correct to the best of my knowledge. Signedjim Young / ~t /~/Fyi ~'/~~ Title: Aurora Petroleum Engineer / t Form 10-404 Rev 06/15/88 · L.. Date 4/05/2001 Prepared by Paul Rauf 564-$799 SUBMIT IN DUPLICATE S-101 DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date 3/26/2001: 312712001 - 3/2912001: Event Summary MIRU CTU. PT'd equip. RIH w/Mem GR/CCL logging tools (well flowing 1350 psi WHP). Logged f/9000' to 8700' CTM. POOH w/logging tools. RIH w/CT conveyed 2-1/2" PJ2506-HMX perforating guns (multiple runs). Shot a total of 90' of add perforations from: 8850' - 8960' MD (Kuparuk C Sand) All shots @ 6 SPF, 60° phasing, random orientation, & @ underbalanced press. POOH w/ guns - ASF. RD CTU. Placed well BOL & obtained well test data. Well is currently shut in. Page 1 RECEIVED APR 06 2.001 Alaska 0il & Gas Cons. C0mmissi0r, Anchorage Ua/ZZ/:'UUI. IU:~U FAA 907 564 4Z~4 BP EXPLORATION bp March 21,2001 BP Explotnfion (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchornge, Alaska 99519-6612 (907) 561-5111 tffiO01 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: RECEIVED MAR 2 J 2001 AiwJm Oil & Gas Cons. Commit~n An~orage Re: Pmdhoe-EOA, Pt. Mac, &.Lisbume Well Work This listing is provided as required under the terms o,f Cons, ervation Order No. 341C (Rule 14) & Order No. 342. This is a list ~f well work tentatively sch6duled for March 19 - 26, 2001: 05-01C 05-18A Work Planned CTE PERFORATION CTE ADD PERFORATION 06-24A 12-15 CT ACID STIMULATION W/DIVERTER SAG HYDRAULIC FRACTURE TREATMENT 13-27A 16-23Ai NK-65i S.103 CT ADD PERFORATION W/WORK PLATFORM CHEMICAL CUT TUBING (PRE RIG ST) CTE ADD PERFORATION ADD PERFORATION INITIAL PERFORATION If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at raufpc @bp.com. Sincerely, ~ ~'. Paul C. Rauf Technical Assistant, BPXA Alaska Drilling & Wells 0;~/14/ZUU1 18:41 i,'A,X 907 564 4264 BI' EXPLORATION bp March 14, 2001 lulie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: _Re: pmdhoe-EOA, Pt. Mac, & Lisburne Well Work Igj. oo! BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 This listing is provided as required under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for March 12 - 19, 2001: Wel.__.] 03-27 03 -28 05-18A 12-15 13-27A 16-21 NK-65i S-103 Work Planned REPERFORATION / HYDRAULIC FRACTURE TREATMENT REPERFORATION CTE ADD PERFORATION SAG HYDRAULIC FRACTURE TREATMENT CT ADD PERFORATION W/WORK PLATFORM REPERFORATION CTE ADD PERFORATION ADD PERFORATION INITIAL PERFORATION If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at _raufpc @bp.com. Sincerely, Paul C. Rauf TeChnical Assistant, BpXA Alaska Drilling & Wells TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC Lori Taylor 3001 Porcupine St. Anchorage. Alaska 99501 RE · Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of ' Robert Richey ProActive Diagnostic Services, Inc. 310 K Street Suite 200 Anchorage, AK 99501 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE REPORT WELL DATE TYPE OR SEPIA LINE OR CD-ROM FILM PRINT(S) COLOR Open Hole I I 1 Res. EVai. CH I i 1 .... , ....... aO l,l$ ..... S, 101 11-28-00 Mech. CH 1 ,,, .......... , ........ Caliper SurVey Print Name' ProActive Diagnostic Services, Inc., 310 K Street Suite 200, Amchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage~jnemorylog, com Website: ww~¥memorx, log.com 05/08/2001 15:43 FAX 907 564 4264 BP EXPI.ORATION ~uuJ bp March ?, 2001 00-I I BP Bxploration (Alaska) Inc. 90O Easl Benson Boulev'ani P.O. Box 196612 Anchorage, Alas~'a 99519-6612 (9O/) 56~-5111 Julie Heusser, Dan Seamount, & Cammy Oe~hsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7t~ Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: · . Re: Pmdhoe-EOA, Pt. Mac, & Lisbume Well Work This listing is provided as required under the terms of Conservation' Order No. 341C (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for March 5 - 12, 2001: Well 03-08 03-25A 03-27 03-28 06-18 13-27A 16-05Ai 16-21 NK-22 .... ~ ....... ~ '?'~,, S-103 Work Planned REPERFORATION REPERFORATION REPERFORATION / HYDRAULIC FRACTURE TREATMENT ' REPERFORATION ' ' CT ACID WASH - GEL CEME~ SQUEEZE GSO CT ADD PERFORATION W/WORK PLATFORM CTD SIDETRACK (NABORS 3S) REPERFORATION ADD PERFORATION ADD PERFORATION INITIAL PERFORATION S-I05 INITIALPERFORATION If additional data or scheduling information is needed, please call me at 564-5799 or E-mail me at rau~c@bp.com~ -'/ ~ Sincerely, /ff//~ PTae;~nCi~aR:UAfs~istant,BPx~''''-'''--L'~ , Alaska Drilling & Wells RECEIVED MAt 0 8 2001 Alaska Oil & Gas Cons. Commission Anchorage bp February 28, 2001 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P,O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Julie Heusser, Dan Seamount, & Cammy Oechsli.Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re: Pmdhoe-EOA, Pt. Mac, & Lisbume Well Work This listing is provided as required under the terms of Conservation Order No. 341C (Rule 14) & Order No. 342. This is a list of well work tentatively scheduled for Februm3, 26 -' March 4, 2001: Well 03-28 02-34A 15-41A 16-05Ai 13-27A 11-32 15-35 16-21 WOrk Planned REPERFORATION CT SET'CIBP FOR GSO CTD SIDETRACK (NABORS CDR1) CTD SIDETRACK (NABORS 3S) CT ADD PERFORATION W/WORK PLATFORM ADD PERFORATION ADD PERFORATION REPERFORATION ADD PERFORATION ff additional data or scheduling information is needed, please call me at 564-5799 orE-mail me at raufpc @bp.com. SpianulerCilYl uf~ ~~' Technical Assistant, BPXA Alaska Drilling & Wells FEB 26 '01 09:05PM BP MILME POIMT GROUP BP Exploration Endloott Well Operations ¸P.2 .,,Sunday ~licklin~i" [E:i[ne: I,other: 2/25 4-1o 1-47 Dummy off GLV~s a'r[d drift tul~'ng to 3.625' Leak detection water flow log.. Monday IlSiiOkiin' : ~Other: 2/26 3-25 2-14 Pull SSSV, drift w!t_h dummy w.h.[pstock Water flow log__ Tuesday $1ickline; E-line: Other: 3-25 Run statio pressure survey 3-39 gas-lift suwey & FSPL 1-0.5~ 2-12; 3-45! .4-101 5-01 & 5-02 MJ.T,'s w/AOGCC witness Wednesday 2/28 $1ickline: 1-25 Other: ........ Brush, Flush & pull ,8,$SVi':d~'iit'tubing Thursday 3/01 I licl<line: 1-25 ther: 2-5S Caliper s~rvey tubi~{] & liner ......... PFO ............. .F,r,!.d..aV 3m2 ISlicl<line: Other! 1-2S Static pressure Saturday 3/04 $1ickline: 1-21 Caliper survey of tubing. I njeetivity test Ot.h_.er.; .............. 1-25 ., To-' WELL LOG TRANSMITTAL State of Ahska Alaska Oil and Gas Conservation Comm. Atm.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 02, 2001 MWD Formation Evaluation Logs · S-101 PB1, AK-MM-00132 S-101 PBI: 2" x 5" MD Resistivity & Gamma Ray Logs · 50-029-22968-70 2" x 5" TVD Resistivity & Gamma Ray Logs · 50-029-22968-70 2" x 5" MD Neutron & Density Logs: 50-029-22968-70 2" x 5" TVD Neutron & Density Logs' 50-029-22968-70 1 Blueline,,,'" 1 Rolled Sepia 1 Blueline ~ 1 Rolled Sepias/" 1 Bluelina/ 1 Rolled Sepia,'" 1 Bluelin," 1 Rolled SePia" PLEASE ACKNOWLEDGE RECEItrr BY SIGNING AND RETURNING A COPY TRANSMITTAL LETrER TO THE ATrENTION OF: Sperry-Sun Drilling Services Arm: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 OF STATE OF ALASKA ALASK,[' ,L AND GAS CONSERVATION COMI[~ ,,~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service , 2. Name of Operator ..... . ~.L- ~ 7. Permit Number BP Exploration (Alaska) Inc. i LOCATIONS 200-115 3. Address.,.~r~ --~._.'~ V~ 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 'Iii ~ i 50-029-22968-00 4. Location of well at surface r-------- ..... '~~ r 9. Unit or Lease Name 4422' NSL, 4499' WEL, SEC. 35, T12N, R12E, UM! ............. F Prudhoe Bay Unit At top of productive interval 3635' NSL, 4306' WEL, SEC. 34, T12N, R12E, UM -~_'_~i 10. Well Number '" Attotal depth ~ Viii~i:::~ i: S-101 581' NSL, 758'WEL, SEC. 28, T12N, R12E, UM I ...... ~ ..... ~ 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Leas~ Designafi&i~'and Serial No. Prudhoe Bay Field / Aurora Pool KBE = 64.41' ADL 028258 (Undefined) 12. Date Spudded 8/9/2000 113' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband' 9/1/2000 9/8/2000 115' Water depth' if °fish°re N/A MSL I' 16. No. of Completions One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey1 20. Depth where SSSV set121. Thickness of Permafrost 11721 6753 FTI 11721 6753 ETI [] Yes [] NoI (Nipple) 2205' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD / GR, MWD / GR / RES / NEU / DEN / PWD, CBL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM' SIZE CEMENTING RECORD AMOUNT PULLED P0" ,. 91.5# H-40" Surface 109' 30" :)60 sx Arctic'Set {Approx.) ' , .... ' ...... ,,, "', ........ 10-3/4" , 45.5# L-80 surface .4014' 13-1/2" 750 sx AS Lite II17 241 Class 'G' . .. 7" ' 26# ......... L-80 ' Surface 8881' 9-7/8" 500 SX Class 'G', 190 sx Class 'G' 4;!/? " 1216#" L-so"... 8709' 1"1721'.'" 6-1/8''~'' 73 sxclass,G, (So!id & Slotted Liner) . '" i. ' 24. Perforations .open to, ProductiOn (MD+TVD of Top and 25. TUBING RECORD Bottom and ~merva~, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Liner 3-1/2", 9,2#, 13Cr 8713' 8673' MD TVD MD TVD 9535'- 11699' 6780'-6752' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect with 77 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) I I~ ~'~ L December 16, 2000 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER'BBL CHOKE SIZE ~ GAS'OIL RATIO 12/21/2000 4 TEST PERIOD 1062 21,984 0 83I 20,707 Fiow Tubing Casing Pressur~ CALCU'LATED ...... OIL-'BBL ..... GAs-McF W'ATER-BBL' OIL G~,WTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED JAN 2 4 2001 Alaska Oil & Gas Cons. Commission A L Form 10-407 Rev. 07-01-80 AHchora(]e Submit'In Duplicate ,,, 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. , Ugnu 4343' 3628' Schradder Bluff 5938' 4765' West Sak 6141' 4910' Kuparuk 8844' 6758' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak-Off Test Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubb,e~"~~ Title TechnicalAssistant Date 01',~4'/'"0[ - S-101 200-115 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, 1% I._ ~.~ I.... IV i-- i..,, ITEM 28: If no cores taken, indicate 'none'. JAN Form 10-407 Rev. 07-01-80 Alaska Oil & Gas Cons. Commission Anchorage Legal Name: S-101 Common Name: S-101 8/15/2000 LOT (ft) (ft) (ppg) (psi) (psi) 13.12 (ppg) 8/16/2000 LOT 4,012.0 (ft) 3,390.0 (ft) 10.50 (ppg) 1,030 (psi) 2,879 (psi) 16.35 (ppg) 8/23/2000 LOT 8,880.0 (ft) 6,775.0 (ft) 10.30 (ppg) 1,350 (psi) 4,975 (psi) 14.14 (ppg) Printed: 9/19/2000 4:12:33 PM ~BP EXPLORATION Page 1 of 9 Operations Summary Report Legal Well Name: 8-101 Common Well Name: S-101 Spud Date: 8/9/2000 Event Name: DRILL+COMPLETE Start: 8/9/2000 End: 9/8/2000 Contractor Name: NABORS Rig Release: 9/8/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Date:: From ~ TO HOUrs A~ivi~ Code phase DesCription of oPeratiOns: 8~9~2000 00:00 - 03:00 3.00 DIVRTR SURF Install 21 1/4" 2000 psi diverter, riser, flow line and lines. 03:00 - 08:00 5.00 DRILL SURF Load 5" drill pipe into pipe shed. Mix spud mud. 08:00 - 09:00 1.00 DIVRTR SURF Function test diverter. Gas alarms, Pvt, and accumulator per direction of Jeff Jones AOGCC. 09:00 - 14:30 5.50 DRILL SURF Pick up 102 joints 5" drill pipe and stand in derrick. 14:30 - 19:30 5.00 DRILL SURF Pick up BHA. Rig up wire line unit. Hold pre-spud meeting with drilling crew and all service company hands 19:30 - 20:00 0.50 DRILL SURF Drill 13 1/2" hole from 0' to 133'. WOB 5-10. RPM 40~76. GPM 450. PSI 450. 20:00 - 21:00 1.00 DRILL TDRV SURF Repair top drive. 21:00 - 22:00 1.00~ DRILL SURF Run gyro directional survey on wire line. 22:00 - 00:00 2.00 DRILL SURF Drill from 133' to 226' WOB 5-10. RPM 40/76. GPM 450. PSI 475 8/10/2000 00:00 - 00:30 0.50 DRILL SURF Drill from 226' to 256'. WOB 5-10. RPM 40/76. PSI 480. AST 0.5 00:30 - 01:00 0.50 DRILL PROC SURF Clean up mud and cutting spill from around cuttings tank and Vacumme trucks. 01:00 - 07:30 6.50 DRILL SURF Drill from 256' to 503'. WOB 5-19. RPM 40/76. PSI 600. AST 1.5 ART 3. 07:30 - 08:30 1.00 DRILL SURF Circulate and condition mud for trip. 08:30 - 11:00 2.50 DRILL SURF POOH to change BHA. Lay down jars. 11:00 - 11:30 0.50 DRILL SURF Service rig 11:30 - 14:30 3.00 DRILL SURF Change BHA. Pick up new bit and jars. RIH 14:30 - 00:00 9.50 DRILL SURF Drill from 503' to 926'. WOB 10-20. RPM 40/67. PSI 1150. AST 2.5. ART 3. 8/11/2000 00:00 - 00:00 24.00 DRILL SURF Directional drill 13 1/2" hole from 926' to 1900'. Rotating and sliding to maintain angle and direction. ART 5 1/2. AST 11 1/4. 8/12/2000 00:00 - 00:00 24.00 DRILL SURF Directional drill 13 1/2" hole from 1900' to 3315'. Rotating and sliding to maintain angle and direction. ART 10.5. AST 6. 8/13/2000 00:00 - 12:45 12.75 DRILL SURF Directional drill 13 1/2" hole from 3315' to 4025'. Rotating and sliding to maintain angle and direction. ART 7 1/4". AST 1 1/4". 12:45 - 13:45 1.00 DRILL SURF CBU > Shakers cleared soon after BU. 13:45 - 16:00 2.25 DRILL SURF Wiper trip to 770'. (Top of 8" DC above KOP) No Exess drag. Hole fill OK. 16:00 - 17:30 1.50 DRILL SURF RIH to 3950' 17:30 - 20:00 2.50 DRILL SURF Wash to 4025' no fill. Circulate and condition mud. Pump 50 bbl hi-vis sweep. 20:00 - 22:30 2.50 DRILL SURF POOH. No drag. Drop ESS. Stand back 5" HWDP. 22:30 - 00:00 1.50 DRILL SURF Lay down 13 1/2" BHA. Recover ESS. Lay down MWD, mud motor and bit. 8/14/2000 00:00 - 01:00 1.00 DRILL SURF Flush out motor. LD, bit, motor and Lead DC. 01:00 - 04:00 3.00 CASE SURF RU for 10.75" Csg. PU landing Jt. MU Hanger and dummy run. PJSM. 04:00 - 09:00 5.00 CASE SURF Run 10.75", 45.5#, L-80, BTC casing to 2900' w/no excess drag. Stacked out at 2900' MD = 2625' TVD. 09:00 - 12:00 3.00 CASE SURF Attempt work pipe. Casing collar hanging on Conductor shoe on upstroke. Work and wash free and wash to 2940'. Work in hole to 3050' wo/circ. Work and wash to 3110' MD = 2760' TVD. 12:00 - 12:45 0.75 CASE SURF RIH to 3630' w/50 to 80 K intermitent running drag. Stacked out at 3630' MD = 3120' TVD. 12:45 - 14:00 1.25 CASE SURF Wash and work pipe to 4014'. Ran trotal of 96 jts. of 10.75" 45.5 # L-80 BTC casing. Shoe at 4014.33'. FC at 3929.11' 14:00 - 15:00 1.00 CASE SURF Make up FMC casing hanger and land casing in FMC head. 15:00 - 15:30 0.50 CASE SURF Rig down fill up tool. Install cementing head and lines. Printed: 9/1912000 4:12:17 PM B PLORATI NIPEX O Page2 of 9 Operations Summa Report Legal Well Name: 8-101 Common Well Name: S-101 Spud Date: 8/9/2000 Event Name: DRILL+COMPLETE Start: 8/9/2000 End: 9/8/2000 Contractor Name: NABORS Rig Release: 9/8/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es :Date :, TO: Hours: 'Activi~ Code phase: : OesCriPtion°fioPerations ~ ~ 8/14/2000 15:30 - 18:00 2.50 CASE SURF Circulate and condition mud. 18:00 - 22:00 4.00 CASE SURF Test cementing lines. Drop bottom plug. Pump 75 bbl hi-vis weighted spacer at 10.4 ppg. Mix and pump lead slurry of 580 bbl 750 sx ARCTICSET Lite III at 10.7 ppg. Mix and pump tail slurry of 50 bbls, 241 sx Class 'G' at 15.8 ppg. Drop top plug. Displace with rig pumps, 373 bbls of mud at 9.5 bbls per minute. Full returns, cement returns 260 bbl. Bump plug wuth 2500 psi. Blead off pressure. Floats held. 22:00 - 22:30 0.50 CASE SURF Lay down landing joint and flush riser and diverter. 22:30 - 23:00 0.50 CASE SURF Rig down casing running tools and clear floor. 23:00 - 00:00 1.00 CASE SURF Nipple down 21 1/4" diverter and riser. 8/15/2000 00:00 - 02:30 2.50 DIVRTR SURF Nipple Down 21.1/4" Diverter and riser. 02:30 - 06:30 4.00 BOPSUF SURF Nipple up FMC casing head, Tubing Spool and BOP. 06:30 - 07:30 1.00 BOPSUF SURF Change out saver sub on Top drive to 4" HT 07:30 - 10:30 3.00 BOPSUF SURF Test BOPE to 250/3500 psi. Perform Accumulator test. Install wear ring in well head. 10:30 - 12:30 2.00 DRILL INT1 Puck up new bit and BHA with mud motor set at 1.57, LWD and PWD. 12:30 - 14:30 2.00 DRILL INT1 Load and test LWD and MWD. 14:30 - 16:30 2.00 DRILL INT1 Run BHA and dril pipe to 3825' 16:30 - 17:00 0.50 DRILL INT1 Test MWD 17:00 - 18:30 1.50 DRILL INT1 Slip and cut 67' drilling line. 18:30 - 19:00 0.50 DRILL INT1 Service Top Drive. 19:00 - 19:30 0.50 DRILL INT1 Wash from 3825' to 3900'. Tag up on cement plugs. Drill plugs and cement to 3927'. 19:30 - 20:30 1.00 DRILL INT1 Circulate. 20:30 - 21:30 1.00 DRILL INT1 Test 10 3/4" casing to 3000 psi, 4.6 bbls and held for 30 minutes. Pressure drop off 100 psi in 30 minutes. Bleed back 4.6 bbls. 21:30 - 23:00 1.50 DRILL INT1 Drill float collar, cement in shoe track, float shoe and 20 feet of formation. 23:00 - 00:00 1.00 DRILL INT1 Circulate and change over from Spud Mud to LSND mud. 8/16/2000 00:00 - 01:00 1.00 DRILL INT1 Performed LOT at 10 3/4" casing shoe. Pump 4.6 bbl, obtain leak off at 1030 psi with 10.5 ppg mud at 3390' TVD. EMW 16.3 ppg 01:00 - 00:00 23.00 DRILL INT1 Drill 9 7/8" directional hole from 4045' to 5742' pump 25 bbl hi-vis pills every 300' drilled. Rotate and slide to maintain angle and direction. No Drag. No Losses. BHA tending to build 0.6 deg / 100'. Reactive Torque 220 deg @ 75 psi Differential. Sliding OK. ART = 12.5 hrs AST = 3.25 hrs 8/17/2000 00:00 - 03:00 3.00 DRILL INT1 Directionally Drill 9.7/8" Hole from 5,742' to 5,940'. No Drag, No Losses. ART= 2 03:00 - 04:30 1.50 DRILL CIRC INT1 Swabs on Number 1 pump out. Replace same while working pipe and circulating hole @ 300 GPM/1500 psi. 04:30 - 06:00 1.50 DRILL INT1 Directionally Drill 9.7/8" Hole to 6,073 ft ( All 4" pipe in derrick used ART=1.25 06:00 - 07:00 1.00 DRILL INT1 Sweep Hole clean @ 600 GPM/3100 psi rotating @ 70 RPM. 07:00 - 08:30 1.50 DRILL INT1 Make wiper trip back to 10.3/4" Shoe @ 4,014ff. Evidence of minor cuttings bed from 5,500' to 4,700 ft ( 15 k-20 klbs overpull). Overpulls getting BHA into shoe ( 25-30 Klbs). Suspect partially balled bit from Cuttings bed. 08:30 - 09:30 1.00 DRILL TGHT INT1 Circulate BHA clean with Bit outside shoe and rotating @ 50 RPM, 300 GPM/1500 psi. 09:30 - 10:00 0.50 DRILL INT1 Pull Back into 10.3/4" casing ( 10 k o/pull) Printed: 9/19/2000 4:12:17 PM BP EXPLORATION Page 3 of 9 Operations Summa Report Legal Well Name: S-101 Common Well Name: S-101 Spud Date: 8/9/2000 Event Name: DRILL+COMPLETE Start: 8/9/2000 End: 9/8/2000 Contractor Name: NABORS Rig Release: 9/8/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Date From, TO;~ HOurs:ActiVity Code Phase Description of Operations , · : : 8/17/2000 10:00 - 11:30 1.50 DRILL INT1 Change out Top Drive Saver sub to 5" Drillpipe and Service Top drive 11:30 - 13:00 1.50 DRILL INT1 'RIH - hole in good shape. Break curculation at 5980' 13:00 - 00:00 11.00 DRILL INT1 Directionally drill from 6073' to 6825'. ART 7.25 AST 0.75 All Drilling Parameters steady. No Drag. No Losses. Reactive Torque @ 270 deg 50 psi differential 8/18/2000 00:00 - 01:00 1.00 DRILL INT1 Drill from 6825' to 6873'. Sliding and rotating to maintain direction and angle. ART=0.75 01:00 - 01:30 0.50 DRILL INT1 Repair pump #2. Circulate with pump #1 01:30 - 18:30 17.00 DRILL INT1 Drill from 6873' to 7957'. Sliding and rotating to maintain direction and angle. Sweep hole with hi-vis pills every 500' drilled. Lo Vis unaffective. Returned to Hi Vis sweeps. Off Bottom Torque increased f/8000 filbs @ 7,000 fi to 13,000 ft lbs @ 7,900 ft. Attempt to slide - difficult. ART=I 1.25 AST= 1.75 18:30 - 20:00 1.50 DRILL INT1 Circulate and condition mud increase lubricants in mud to 1% EP Mudlube and 1.5 % Lubetex. Off Bottom Torque down to 8000 ft lbs. 20:00 - 00:00 4.00 DRILL INT1 Drill from 7957' to 8037'. Rotating and sliding to maintain direction and angle. ART 0.5 hrs AST 1.5 hrs. Reactive Torque 240 degs w/40 psi Differential/5 klbs WeB, ReP @ 15-20 ft/hr. Sliding 60 fi of each stand with "vigilence" in maintaining toolface 8/19/2000 00:00 - 09:00 9.00 DRILL INT1 Directionally drill 9 7/8" hole from 8037' to 8196'. ART=0.28 hrs AST=7.5 hrs Maintaining toolface with 40 psi differential, 180-270 deg reactive itorque. ReP @ 15-25 fi/hr. Achieving 5-7 deg DLS with 100% sliding (Full capability of BHA= 10 deg DLS) 09:00 - 10:00 1.00 DRILL INT1 Rig repair. Replace swab an dliner on #2 pump. Work pipe and circulate with # 1 pump. 10:00 - 23:00 13.00 DRILL INT1 Directionally drill from 8196' to 8423'. ART=l/4 hrs. AST=8 3/4 hrs. Comments for drilling with DS70 - same as 0000-0900 hrs 23:00 - 00:00 1.00 DRILL INT1 Pull one stand. Circulate. Pump hi-vis pil, work pipe. No noticable amount of cuttings over shaker on bottoms up. 8/20/2000 00:00 - 01:00 1.00 DRILL INT1 Sweep Hole clean @ 510 GPM / 3300 psi while Working Pipe. 01:00 - 04:00 3.00 DRILL INT1 Make Check trip to old hole @ 6,000 fi. Some drag ( 25 klbs) across Schreader Bluff ( Filter Cake?). Work pipe. OK. 04:00 - 15:00 11.00 DRILL INT1 Rotate Ahead 9.7/8" Hole to Casing Point @ 8,875 fi. AST= 0.5 hrs ART=8.5 hrs. No Drag, No Losses. Provisional Top HRZ @ 8,474 ft MD ( 6,601 ' TVD). Observe drilling break @ 8,865 fi with Auto Driller set on WeB: P-rate f/50 fph to 80 fi/hr. 15:00 - 16:30 1.50 DRILL INT1 Circulate bottoms up@ 500 GPM/3200 psi - 40% Sandstone. Geologist confirm in Kuparuk ( Provisonal, 6,765 fi 'I'VD) 16:30 - 17:00 0.50i DRILL INT1 Make check trip to old hole @ 8,409 fi above HRZ- OK. 17:00 - 17:30 0.50 DRILL INT1 Drill from 8875 to 8880' 17:30 - 19:00 1.50 DRILL INT1 Pump sweep @ 510 GPM/3200 psi and spot 50 bbl Casing pill w/5% lubetex 19:00 - 00:00 5.00 DRILL INT1 Pull out of the hole, lay down 5" drill pipe. Stand back 4" drill pipe. Drop ESS at 5782'. Continue POOH. Hole in Good shape. 8/21/2000 00:00 - 00:30 0.50 DRILL INT1 POOH stand back 4". Printed: 9/19/2000 4:12:'17 PM BP EXPLORATION Page 4 of 9 Operations Summar Report Legal Well Name: 8-101 Common Well Name: S-101 Spud Date: 8/9/2000 Event Name: DRILL+COMPLETE Start: 8/9/2000 End: 9/8/2000 Contractor Name: NABORS Rig Release: 9/8/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es D From-To HourS ActiVi~ COde Phase Descripti°n of Operati°ns i. : 8/21/2000 00:30 - 04:00 3.50 DRILL INT1 Lay down 9 7/8" BHA. Recover ESS. Good Correlation. JORPS satisfied. 04:00 - 06:30 2.50 BOPSUF INT1 Change rams to 7" and test BOP ram doors to 300/3500 psi. 06:30 - 09:00 2.50 CASE INT1 Rig up to run 7" casing. Install Franks Fill Up/Circulating Tool and Air Slips/Elevators. Hold PJSM. 09:00 - 15:30 6.50 CASE INT1 Check Floats, bakerlock shoetrack. Run 7" casing to 10.3/4" shoe @ 4,012 ft. 15:30 - 16:00 0.50 CASE INT1 Circulate casing contents- 160 bbls @ 5 BPM/350 psi. 16:00 - 22:00 6.00 CASE INT1 Run 7" Casing to 8,880 ft: 218 joints 26 Ib/ft, L-80, BTC-Mod + 2 Pup Joints and Port Collar @ 2,194 ft. Tag Bottom On depth- Hole Good, No fill. 22:00 - 22:30 0.50 CASE INT1 R/D Franks fill up/circulating tool and R/U Cement Head. 22:30 - 00:00 1.50 CASE INT1 Circulate at 3 BPM with 525 psi and clowly increase circulating rate to 7 BPM with 615 psi. Full returns. 8/22/2000 00:00 - 00:30 0.50 CASE INT1 Circulate with 7" casing at 8880' @ 7 BPM/600 psi. Held pre-job safety meeting with Dowell cementers and rig crew. No Losses. 00:30 - 02:00 1.50 CEMT INT1 Test cement lines to 4000 psi. Pump 50 bbl B45 Viscosified Spacer at 12.2 ppg. Drop bottom plug. Mix and pump 245 bbl (500 sx) class 'G' cement at 11.5 ppg lead slurry and 39 bbl (190 sx) class 'G' cement at 15.8 ppg tail slurry. Drop top plug. 02:00 - 03:00 1.00 CEMT INT1 Displaced with 335 bbl mud using rig pumps at 7 BPM with 615 psi. Bump plug with 3000 psi. Full returns throughout. 03:00 - 08:00 5.00 VVHSUR INT1 Nipple down BOP and casing spool. Land casing with 65 K lbs tension in slips. Make final cut and stand back BOPE. R/D casing bails and R/U Drlg Bails and P/U 5" HWDP. 08:00 - 09:00 1.00 WHSUR INT1 N/U Tubing Spool with pre-installed packoff and test same to 4,300 psi- ;Good. 09:00 - 13:30 4.50 BOPSUF; INT1 N/U BOP and clean up cellar area. Change rams to 2.7/8" x 5" and i change saver sub on topdrive to 4" HT. 13:30 - 18:30 5.00 BOPSUF; INT1 Test BOPE to 300/3500 psi. John Crisp of ^OGCC observing. 18:30 - 23:00 4.50 DRILL PROD1 M/U 6.1/8" build assembly- 2.12 deg Bend motor/LWD tools, ABI and PWD. Orientate and test- OK. 23:00 - 00:00 1.00 DRILL PROD1 RIH picking up 4" drillpipe. 8/23/2000 00:00 - 03:00 3.00 DRILL PROD1 ;RIH with 4" picking up 93 joints to 3,821 ft. 03:00 - 04:30 1.50 DRILL PROD1 i Slip and Cut Drilline. Service Top Drive. 04:30 - 08:00 3.50 DRILL PROD1 Continue to RIH picking up 96 more joints to 8,546 ft. 08:00 - 09:00 1.00 DRILL PROD1 Wash down from 8,546 ft and tag Float Collar on depth @ 8,797 ft. 09:00 - 09:45 0.75 DRILL PROD1 Circulate bottoms up. Fluid from across Permafrost Interval Viscous reulsting in higher pump pressures ( 2900 psi/220 GPM). Once thinner fluid out Pressures down to 2500 psi/220 GPM 09:45 - 10:30 0.75 DRILL PROD1 Test 7" Casing to 300/3500 psi for 30 minutes. Volume pumped /returned= 3.35 bbls. Hold Pre-reservoir meeting while conducting I casing test. 10:30 - 12:00 1.50 DRILL PROD1 Drill shoetrack. Unable to rotate @ Iow RPM. Drill @ 80-140 fi/hr with 5 klbs WeB/40 psi differential. 12:00 - 14:30 2.50 DRILL PROD1 Displace well to 10.4 ppg KCL mud @ 220 GPM/2400 psi. Flowcheck. Good. 14:30 - 15:30 1.00 DRILL PROD1 Slide Drill 20 ft new formation to 8,900 ft. 15:30 - 16:00 0.50 DRILL PROD1 !CBU and Conduct Safety Stand down while circulating to discuss latest i GIobal Fatalities in BPX 16:00 - 16:30 0.50 DRILL PROD1 Conduct LOT :1350 psi= 14.1 ppg EMW. 1.6 bbls Pumped, 0.6 bbls ;returned. TVD Shoe @ 6,775 ft. 10.3 ppg Mud Weight. 16:30 - 00:00 7.50 DRILL PROD1 I Slide Drill 6.1/8" Hole f/8.900 ft to 9,046 ft. Achieve DLS of 23 -28 ., Printed: 9/19/2000 4:12:17 PM BP ~EXPLORATION Page5 of 9 Operations summa Report Legal Well Name: 8-101 Common Well Name: S-101 Spud Date: 8/9/2000 Event Name: DRILL+COMPLETE Start: 8/9/2000 End: 9/8/2000 Contractor Name: NABORS Rig Release: 9/8/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Date From-To HoUrs ActiVi~ Code Phase DesCriPtion of Operations :~ , 8/23/2000 16:30 - 00:00 7.50 DRILL PROD1 degs/100'. No Drag, No Losses. 8/24/2000 00:00 - 02:00 2.00 DRILL PROD1 Slide Drill 6.1/8" hole and build/turn angle achieving an average of 22-33 deg DLS. Offset Pad on 2.12 deg Motor @ 5.75". AST= 1.75 hrs 02:00 - 03:00 1.00 DRILL ! PROD1 Sweep Hole clean @ 220 GPM/2200 psi. 03:00 - 06:30 3.50 DRILL PROD1 POOH to BHA. 06:30 - 08:30 2.00 DRILL PROD1 Lay Down Bit and Download MWD. 08:30 - 10:00 1.50 DRILL PROD1 M/U PDC Lateral BHA with 1.83 bend. Surface test MWD. 10:00 - 15:00 5.00 DRILL PROD1 RIH and wash down last stand. Hole in Good Shape. 15:00 - 00:00 9.00 DRILL PROD1 Directionally Drill 6.1/8" Hole f/9,139' to 9,410'. ART=6, AST=1.25 No Drag. No Losses. ECD steady @ 11.8-12.0 ppg. Formation dip @ 2.6 :degs. Increase RPM after 9,387' ( Jars out of high dogleg). 8/25/2000 00:00 - 11:00 11.00 DRILL PROD1 Directionally Drill 6.1/8" Hole crossing up dip looking for Top C3^ marker. Attempt to slide to build angle- no go. Some overpulls ( 25 i klbs). ECD @ 12.1 ppg, Off Bottom Torque Increasing f/8,000 ftlbs to 10,000 ftlbs. ART=5.75 AST=I 11:00 - 12:00 1.00 DRILL PROD1 Spot 20 bbls Stickless Beads @ 15 ppb and work into open hole w/25 RPM. 12:00 - 16:00 4.00 DRILL PROD1 Slide to build angle to 98 degs Inclin- good. Rotate ahead 6.1/8" hole looking for markers. Observe same. Prepare to drop angle @ 9,807 FT ART=2.5 hrs AST=0.75 hrs 16:00 - 16:30 0.50 DRILL PROD1 Spot 20 bbls Stickless Beads @ 15 ppb and work into open hole. 16:30 - 21:30 5.00 DRILL PROD1 Directionally Drill 6.1/8" hole to 9,896 ft. Encounter HRZ @ 9,850 MD, 6736 ft TVD. Suspect Fault w/15-20 ft Throw in well path. Fault Picked at 9,840 ft MD, 6,735 ft TVD 21:30 - 23:30 2.00 DRILL PROD1 Pull back one stand and work pipe while reviewing options. 23:30 - 00:00 0.50 DRILL PROD1 Initiate Time drilling @ 9,668 ft to Open Hole sidetrack 6.1/8" Hole. 8/26/2000 00:00 - 00:00 24.00 DRILL PROD1 Attempt to Time Drill/Build Ledge in 6.1/8" hole f/9,683' to 9,710 to sidetrack well. No Go. Appear to make progress with weight and Differential Pressure and then loose ground. Maybe a result of hole geometry and BHA geometry ( ABI pad is 5.5/8" 8/27/2000 00:00 - 01:00 1.00 DRILL PROD1 Time Drill 6.1/8" Hole in attempt to sidetrack well. Stacking weight. AST=0.75 01:00 - 01:30 0.50 DRILL PROD1 Spot 20 bbls Stickless Beads @ 15 ppb and wojk into open hole 01:30 - 09:00 7.50 DRILL PROD1 Continue to attempt to sidetrack well. Vary flowrates. Work pipe. Observing some increases in Differential Pressure with Iow weight and then loose differential. AST=7 hrs 09:00 - 09:30 0.50 DRILL PROD1 POOH to 9160 ft. Sump of well. Attempting to use hole geometry and BHA geometry to force Bit into side of hole. Prepare to sidetrack well @ 9,190 ft, ( start of highside slide in orginal hole) 09:30 - 00:00 14.50 DRILL PROD1 Orientate and Trench for 4 hours. Spot Stickless Bead and Time Drill 6.1/8" Hole to 9,201 ft. Observiing some differential. 8/28/2000 00:00 - 05:00 5.00 DRILL PROD1 Time Dril and Sidetrack from old hole @ 9,205 ft to 9,230 ft. Good indications from ABI and recative torque well sidetracked. AST = 5 05:00 - 00:00 19.00 DRILL PROD1 Directionally Drill 6.1/8" Hole f/9,230 ft to 9,840 ft. Torque/Drag higher than original hole. Slight Breathing on connections- probably from old hole. Provisional Pick on Fault @ 9,805 ft MD, 6,758 ft TVD. AST= 3.5 hrs, ART=I 1 hrs 8/29/2000 00:00 - 01:00 1.00 DRILL PROD1 Directionally drill to original hole equivalent MD at 9896'. 01:00 - 05:30 4.50 DRILL PROD1 Directionally drill 9896' to 9946'. Torque and drag higher than original hole. Pump bead Pill at 9920'. 05:30 - 06:00 0.50 DRILL TGHT PROD1 Circulate and pump bead pill for torque and drag. 06:00 - 09:00 3.00 DRILL LMWD PROD1 No signal from MVVD. TrOuble shoot MWD, pump brine pill and work Printed: 9/19/2000 4:12:17 PM Bp EXPLORATION Page 6 of 9 Operations Summa Report Legal Well Name: S-101 Common Well Name: S-101 Spud Date: 8/9/2000 Event Name: DRILL+COMPLETE Start: 8/9/2000 End: 9/8/2000 Contractor Name: NABORS Rig Release: 9/8/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es : ~. DeSCription of oPerations Date ~ From-To Hours ACtivityC°de Phase 8/29/2000 06:00 - 09:00 3.00 DRILL LMWD PROD1 pipe and attempt to clear tools. No sucsess. 09:00 - 10:00 1.00 DRILL LMWD PROD1 POOH to 7" casing shoe. 10:00 - 10:30 0.50 DRILL i LMWD PROD1 Attempt to clear MWD. No success. 10:30- 15:00 4.50 DRILL LMWD PROD1 POOH 15:00 - 18:00 3.00 DRILL LMWD PROD1 Change out MWD and mud motor. 18:00 - 21:00 3.00 DRILL PROD1 Test BOP. 250 psi and 3500 psi. AOGCC rep' Jeff Jones waived i witnessing test. 21:00 - 00:00 3.00 DRILL LMWD PROD1 Make up new mud motor, install new MWD, 8/30/2000 00:00 - 01:00 1.00 DRILL LMWD PROD1 MU BHA ~ Orient and function test MVVD. 01:00 - 04:00 3.00 DRILL LMWD PROD1 RIH to 8828'. 04:00 - 05:30 1.50 DRILL PROD1 Slip and cut drilling line. Service Top Drive. :05:30 - 08:00 2.50 DRILL PROD1 MADD pass 8880' to TD. Check survey at 9280' and 9780' confirmed re-entry to new hole. No excess drag or ledging noted. 08:00 - 00:00 16.00 DRILL PROD1 Orient and drill form 9946' to 10,506'. Slide and rotate to steer for C4A sand. Encountered C4A @ 9955' to 10100'. Steer up in C3B in attempt to relocate C4A. Change out 750 bbl drilling mud to maintain MBT below 2.0. 8/31/2000 00:00 - 00:00 24.00 DRILL PROD1 Directionally drill form 10,506' to 11500'. Slide and rotate to chase C4A sand. 9/1/2000 00:00 - 05:30 5.50 DRILL PROD1 Directionally drill to 11721'. 05:30 - 07:00 1.50 DRILL PROD1 Survey and CBU for TD Sample. 07:00 - 17:00 10.00 DRILL PROD1 MAD pas from TD to 9790' Check survey at 9790'. Good Corelation. Hole condition generally good. Minor seepage loss < lbph. Tight to 20 K OP at 10411' and 10 K at10125'. Broke back to no excess drag at both depths and then pulled clean. 17:00 - 17:30 0.50 DRILL PROD1 POOH standing back DP to 7" shoe at 8881'. 17:30 - 00:00 6.50 DRILL PROD1 POOH lay down 4" drill pipe. 9/2/2000 00:00 - 01:00 1.00 DRILL PROD1 RIH w/ 4" DP from derrick. 01:00 - 05:00 4.00 DRILL PROD1 Slug pipe and POOH laying down. 05:00 - 07:00 2.00 DRILL PROD1 LD Jars. PJSM. Stand back DC. LD Nuclear Sources from MWD tools. LD remaining BHA. 07:00 - 08:00 1.00 CLEAN COMP Clear floor and change over to 3 1/2" HT-38 handling tools. 08:00 - 12:00 4.00 CLEAN COMP PU 30 std. 3 1/2" DP and stand back in derrick 12:00 - 14:30 2.50 CLEAN COMP PU BHA #7 and check tools. 14:30 - 17:30 3.00 CLEAN COMP RIH to 4400' picking up 3 1/2" drill pipe. 17:30 - 18:00 0.50 CLEAN COMP Break circulation at 4400'. 18:00 - 21:30 3.50 CLEAN COMP RIH to 8850' picking up 3 1/2" drill pipe. 21:30 - 23:00 1.50 CLEAN COMP Circulate at 7" casing shoe. No significant gas on bottoms up. 23:00 - 00:00 1.00 CLEAN COMP Slip and cut drilling line. 9/3/2000 00:00 - 00:30 0.50 CLEAN COMP Service top drive 00:30 - 02:30 2.00 CLEAN COMP RIH w/stands to 9275'. Check survey. RIH to TD. No excess drag. Mud loss constant at 1 bph. Cleaning pits as RIH. 02:30 - 06:30 4.00 CLEAN COMP Circulate and condition w/10.4 ppg mud. Moderate returns of CaCo3" settlings" from "sump". No significant settling or cuttings from TD. Max. gas at BU = 60 units. Pump 30 bbl Lo-vis 30 bbl Hi-vis sweep. Minor solids returns with sweep. Hole taking 1.5 bph @ 12.4 ppg ECD. PU = 175K SO = 109K 06:30 - 09:30 3.00 CLEAN COMP Pump 25 bbl HI-vis spacer & displace w/40 NTU, 10.2 ppg brine @ 3400 psi w/215 gpm. PU increasing to 190K and SO decreasing to 90 K w/drag becoming "jerky" as wall cake eroded. Fluid loss increasing as soon as brine entered open hole. Dumped 50 bbl interface of spacer and muddy brine. Printed: 9119/2000 4:12:17 PM BP EXPLORATION Page 7 of 9 Operations SUmmary RepOrt Legal Well Name: S-101 Common Well Name: S-101 Spud Date: 8/9/2000 Event Name: DRILL+COMPLETE Start: 8/9/2000 End: 9/8/2000 Contractor Name: NABORS Rig Release: 9/8/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es Date From_ To~ :Hours ACtiVi~ COde phase ' : · :Description of OperatiOns 9/3/2000 09:30 - 12:30 3.00 CLEAN COMP Circ and attempt to condition hole and brine. Started filtration with 40 NTU in and NTU off scale coming out. Pump rate limited to -3 bpm by filtration capability. Static Iossincreased to 12 bph and dynamic loss 20 bph. C & C w/little change. Lost filtration due to failure of Filtration unit pulsation dampener drain valve. Repaired same. Drag and losses increasing. Static loss 15 bph. Dynamic loss 24 bph at 4 bpm. 12:30 - 14:30 2.00 CLEAN CIRC COMP Pump 102 bb110.4 ppg mud and balance in open holew/58 bbl 10.2 brine. 14:30 - 16:30 2.00 CLEAN CIRC COMP POOH to 8875'. Filter brine in pits while POOH. Drag reduced to previous values after placing pill. Fluid loss decreased to 2.5 bbl/hr. 16:30 - 19:30 3.00 CLEAN COMP Filter brine in pits at 1.5 bbl per minute. Filter press blinding off with clean CaCo3 settlings and polymer contamination solids. Brine out of filter at 25 NTU. Brine in pits off the scale. Losses with well static, 1.5 bbl per hour.' Total losses to well 210 bbl. 19:30 - 22:30 3.00 CLEAN COMP Pull out of the hole stand 3 1/2" drill pipe and HWDP in derrick. 22:30 - 00:00 1.50 CLEAN COMP Lay down 6 1/8" clean out BHA. 9/4/2000 00:00 - 01:30 1.50 RUNCOI~ COMP Rig floor and tools for 4 1/2" isolated slotted liner completion. Hold PJSM 01:30 - 04:30 3.00 RUNCOr~ COMP Run 3012' of 4.5" liner: guide shoe & packoff bushing, 53 jts 12.6# L-80 IBT slotted liner, 2 jts. 12.6# L-80 IBT liner, ECP inflatible packer w/ HMCV cementing port, 16 jts liner. 04:30 - 10:00 5.50 RUNCOI~ COMP Change to 2 7/8" tools and run 2 7/8" inner stinger w/Cementing tools. 10:00 - 11:00 1.00 RUNCOI~ COMP Tag packoff. Measure and space out stinger. Change to 3 1/2" DP tools. PU HMC liner hanger - ZXP Packer assembly and MU on liner. RD 2 7/8" tools. 11:00 - 12:00 1.00 RUNCOI~ COMP PUI std HWDP. Break circ and circ. 20 bbl 10.2 brine @2.5 bprn & 250 psi. 12:00 - 16:00 4.00 RUNCOI~I COMP RIH w/7 std HWDP & 3 1/2" DP to 8830'. 16:00 - 17:00 1.00 RUNCOr~! COMP Displace DP and stinger w/5 bbl HI-vis spacer and 50 bb110.4 ppg mud. PU = 185K, SO = 116 K, Rot = 145K. Pumped 2.5 bpm @ 750 psi. Lost 8 bbl while pumping. 17:00 - 19:00 2.00 RUNCOr~! COMP RIH to TD at 11721'. No exess drag. Did not see any indication of'old hole at sidetrack depth. Picked up and spaced out for cementing. PU = 195K SO = 95K. 19:00 - 20:00 1.00 RUNCOr~! COMP RU cement lines through manifold and TD. PJSM. Liner stuck on bottom after PJSM. Work liner to PU = 250K SO = 75 K. No change. Park liner w/150 K. Pressure test lines to 500 & 5000 psi. 20:00 - 21:00 1.00 RUNCOr~! COMP Drop ball and pump down w/10.4 ppg mud. Pumped 50 bbl @ 2.5 bpm.and slowed to 1 bpm to limit pressure to less than 1000 psi. Calculated 73.3 bbl to ball seat. Pumped 95 bbl. ball did not seat. 21:00 - 22:00 1.00 RUNCOr~I COMP Dropped dart and displace to RPC w/62.25 bbl 10.2 ppg brine. Calculated displacement was 59.8 bbl. Pressure fluctuating between 1100 psi and 1800 psi at 1.5 BPM. Possitioned liner tension and pressure to 1800 psi and set HMC Liner hanger. Pressure up to 2600 psi and release liner hanger running tool. 22:00 - 22:30 0.50 RUNCOI~I COMP Pick up string and close PPIT. Pressure test to 1000 psi. Pick up 50' to ECP. Good indication on weight indicator. Inflate ECP with 1/'10 bbl at 850 psi. Volume indicates hole in gauge. Pick up and locate HMCV. 22:30 - 00:00 1.50 RUNCOI~! COMP Lay down 1 jt drill pipe and pup joint. Connect circulating head and Printed: 9/19/2000 4:12:17 PM Bp ExPLO~TiON Page 8 of 9 Operations Summa Repo Legal Well Name: 8-101 Common Well Name: S-101 Spud Date: 8/9/2000 Event Name: DRILL+COMPLETE Start: 8/9/2000 End: 9/8/2000 Contractor Name: NABORS Rig Release: 9~8/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es i Date From- TO: :Hours Activi~ COde Phase ilDesCriPtion of OPerations 9/4~2000 22:30 - 00:00 1.50 RUNCOI~ COMP cementing line. Pressure up to 2100 psi, open HMCV. Pump 5 bbl at 3 BPM to confirm port open, returns OK. Dowell batch mix spacers and cement. 9~5/2000 00:00 - 01:30 1.50 CASE COMP Cement 4 1/2" liner. Pump 20 bbl 11.0 ppg weighted spacer followed by 15 bbl class "G" cement at 15.5 ppg, followed by 5 bbl 11.0 ppg weighted spacer pumped at 2.5 BPM with 600 psi. Displace with 56.75 bbl brine with Dowell pump truck at 3 BPM. Final presure 1000 psi, full returns. Held pressure and closed HMCV. Check for flow. OK. Pressure test HMCV with 3200 psi. OK. 01:30 - 02:30 1.00 CASE COMP Set ZXP packer with 50,000 lbs weight down while rotating string. :02:30 - 04:00 1.50 CASE COMP Pressure up to 4000 psi down drill pipe to open drain valve. Circulate 30 bbl hi-vis pill around with brine at 4 BPM with 2000 psi. Reciprocate pipe slowly. 04:00 - 10:30 6.50 CASE COMP POOH lay down 3 1/2" drill pipe. 10:30 - 13:00 2.50 CASE COMP RIH 3 1/2" drill pipe from derrick. POOH and lay down drill pipe. Stand HWDP back in derrick. 13:00 - 16:30 3.50 CASE COMP POOH and lay down 2 7/8" tubimg inner string and Baker tool assembly. 16:30 - 23:00 6.50 EVAL COMP Rig up Schlumberger. PJSM. Run CBL Temperature log: PSP,SRO-PBMS and CMTB from 8700' to 3700' 23:00 - 00:00 1.00 CASE FILL COMP Pressure up on 10 3/4"X 7" casing annulus to obtain injetivity rate. Pump 1 bbl at 1/2 BPM, pressure up to 3500 psi. Bleed offto 2500 psi ~n 10 minutes. Repeat three more times with same result but pressure bleading off in 8, 6 and 5 minutes each time. Bleed pressure to zero, flow back 0.8 bbl. 9/6/2000 00:00 - 01:00 1.00 CASE FILL COMP Attempt to establish injection. Pressure to 3500 psi w/1 bbl. Bleed to 1450 psi in 40 min. Bleed off and recover 0.85 bbl. 01:00 - 02:00 1.00 CASE FILL COMP POOH and RD e-tine loggers 02:00 - 03:30 1.50 CASE COMP PU port collar shifting tool and pin shear sub to 2700 psi. RIH to port collar on 3 1/2" from derrick. 03:30 - 05:45 2.25 CASE !COMP MU FOSV and DP pup to Top Drive.. PJSM. Load DP w/3 bbl HI-vis FW spacer and 10 bb110.2 ppg FW Iow vis-flush. Latch port collar tool and test cups to 1000 psi. Bleed to 400 psi. and open PC. 05:45 - 07:30 1.75 CASE COMP Break circ w/1/2 bpm @ 1900 psi. Pumped 12 bbl Lo-vis flush and 125 bb110.2 ppg brine. Final circ. @ 3 bpm & 1700 psi. Recovered 10.8 ppg mud and brine cut mud. Final returns were somewhat "dirty" 10.2 ppg brine w/minor suspended fines. 07:30 - 09:00 1.50 CASE COMP TeSt lines to Hot oiler and pump dead crude Freeze protect, pumped @ 2 bpm & 1000 psi. Pumped 83 bbl then had oil cut in returns. 09:00 - 10:15 1.25 CASE FILL COMP Shut down pump, shutin DP and eA. Monitor and let stabilize. OA pressure = 375 psi. DP pressure = 175 psi. ( Both OA and DP ballanced against 10.2 ppg mud in IA.) Calculated 6 bbl oil in DP and 77 remaining in eA. 10:15 - 10:45 0.50 CASE COMP Opened against choke on DP and pumped 27 bbl oil @ 2 bpm and 1450 psi. Returns recovered ~ 7 bbl mud and 20 BBL oil. Total of 110 bbl oil pumped. Calculated oil in OA as: 110 bbl pumped - 20 bbl recovered - 12 bbl in DP = 78 bbl remaining in eA. 10:45 - 12:00 1.25 CASE COMP Close Port collar and U-tube 12 bbl oil from DP. Bullhead eA. Broke circ @ 0.25 bpm & 2950 psi. Pumped 20 bbl oil. Final injection was 0.70 bpm @ 2650 psi. Calculated total oil in OA as 78 bbl + 20 bbl = 98 bbl. Minimum Depth of oil - mud contact at 100 % displacement efficiency calculates at 2018' MD. & 1950' TVD. 12:00 - 13:30 1.50 CASE COMP Shut in eA. Bleed to 0 psi in 5. RD hot oiler OA wing valves. PU & Printed: 9/19/2000 4:12:17 PM BP ~PLORATION Page 9 of 9i Operations Summar Report Legal Well Name: S-101 Common Well Name: S-101 Spud Date: 8/9/2000 Event Name: DRILL+COMPLETE Start: 8/9/2000 End: 9/8/2000 Contractor Name: NABORS Rig Release: 9/8/2000 Group: RIG Rig Name: NABORS 9ES Rig Number: 9es iDatei: FrOm,TO HOURS ActiVi~ COde:Phase Description of Operations . 9/6/2000 12:00 - 13:30 1.50 CASE COMP release PC tool. Shear choke sub w/2950 psi. Flow check well. 13:30 - 14:30 1.00 CASE COMP POOH and LD PC tool. 14:30 - 19:00 4.50 CASE COMP PU RTTS test packer and RIH. Set RTTS at 2264' and test 7" casing and PC to 3500 psi for 30 min. Lost 75 psi. Bleed off and unseat packer. Flow check. POOH laying down 3 1/2" DP, HWDP and RTTS packer. 19:00 - 21:00 2.00 RUNCOI~ COMP Rig up to run 3 1/2" 13CR tubing. PJSM 21:00 - 00:00 3.00 RUNCOI~ COMP Run 3 1/2" 13CR tubing as per completion procedure. 9/7/2000 00:00 - 05:30 5.50 RUNCOI~I COMP Run 3 1/2" tubing to 6200'. 05:30 - 07:30 2.00 RUNCO~DRAW COMP Repair draworks. Pneumatic pilot valve on draworks disk brakes stuck. 07:30 - 08:30 1.00' RUNCO~I COMP Pull back to 5400' to confirm questionable makeup. See remarks. 08:30 - 13:30 5.00 RUNCO~I COMP Run tubing completion to 8660'. 13:30 - 16:15 2.75 RUNCO~I COMP PU space out joints and circulate down to PBR. Taged PBR @ 8709'. Worked into PBR and measured for spaceout pups. PU and MU spaceout and tubing hanger. Check land tubing. PU and prep to reverse heated completion brine. 16:15 - 20:30 4.25 RUNCO~I COMP Reverse circulate and displace fluid in hole to clean 1407 F, 10.2 ppg brine at 2.5 BPM. 20:30 - 23:30 3.00 RUNCO~ COMP Land tubing on tubing hanger. Run in lock down screws. Drop ball and rod with wire line fishing neck. Presure up to 3500 psi and set Baker S-3 packer. Test tubing with 3500 psi for 30 minutes. OK. Pressure drop 100 psi in 30minutes. Bleed tubing to 2000 psi. Pressure annulus to 3500 psi to test packer. Held for 30 minutes. OK. Pressure drOp100 psi in 30 minutes. Bleed pressure down from tubing and open RP shear valve at 2500 psi. Install two way valve in tubing hanger and test up tubing to 3500 psi. 23:30 - 00:00 0.50 RUNCOr COMP Nipple down BOP. 9/8/2000 00:00 - 08:00 8.00 BOPSUF COMP Nipple down and remove BOPE. Remove rams and clean cavitys, Remove lines, Split stack at double gate. Set out stack. 08:00 - 09:30 1.50 WHSUR COMP Prep wellhead. Install production tree and test to 5000 psi. 09:30 - 12:00 2.50 WHSUR COMP RU hot oiler. Test lines. Reverse 7.9 bbl diesel. Allow to U-tube. Secure well. SIWHP = 275 psi. RELEASE RIG @ 12:00 9/8/00 Printed: 9/19/2000 4:12:'17 PM North Slope Alaska Alaska State Plane 4 PBU_ WOA S Pad S-101 Surveyed: 1 September, 2000 SURVEY REPORT 15 September, 2000 Your Ref: API.500292296800 Surface Coordinates: 5980624.83 N, 618930.03 E (70° 21' 20.5864" N, Kelly Bushing: 64.41ft above Mean Sea Level 149° 02' 02.9225" W) Olq I I..L. I NOl Survey Ref:. svy10082 Sperry-Sun Drilling Services Survey Report for S-101 Your Ref: AP1.$00292296800 Surveyed: I September, 2000 North Slope Alaska Measured Depth (fi) Incl. Azlm. Sub-Sea Depth (fi) 9189.57 94.188 322.858 6748.66 9203.00 94.190 322.858 6747.67 9217.78 93.262 325.415 6746.71 9248.77 94.619 327.281 6744.58 9278.81 95.976 328.809 6741.81 9343.01 96.963 328.396 6734.58 9374.69 96.725 328.677 6730.80 9405.96 95.420 328.647 6727.49 9437.11 94.864 328.234 6724.70 9468.08 94.371 328.558 6722.21 9499.42 95.669 328.603 6719.47 9530.05 95.604 328.477 6716.46 9561.54 95.175 328.917 6713.50 9592.74 94.678 328.516 6710.82 9622.84 95.048 328.730 6708.27 9654.03 95.668 330.018 6705.36 9685.89 95.360 330.312 6702.30 9716.63 94.990 330.595 6699.52 9747.95 94.438 330.159 6696.95 9778.81 93.944 330.187 6694.69 9809.85 93.944 329.884 6692.56 9840.40 90.428 325.046 6691.39 9869.53 91.480 323.815 6690.91 9900.99 92.770 324.505 6689.74 9929.90 91.782 324.725 6688.59 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings EaStings (fi) (ft) (ft) (ft) (ft) 6813.07 616.93 $ 6812.08 606.26 S 6811.12 594.31S 6808.99 568.57S 6806.22 543.19 S 6798.99 488.74 S 6795.21 461.91S 6791.90 435.36S 6789.11 408.92S 6786.62 382.63S 6783.88 355.99 S 6780.87 329.99 S 6777.91 303.20 S 6775.23 276.64S 6772.68 251.03 S 6769.77 224.31S 6766.71 196.80 $ 6763.93 170.17 S 6761.36 143.03S 6759.10 116.33 S 6756.97 89.50 S 6755.80 63.78 $ 6755.32 40.09 S 6754.15 14.60 S 6753.00 8.95 N 5361.95W 5979922.85 N 613578.55 E 5370.03W 5979933.40 N 613570.30 E 5378.67W 5979945.21N 613561.47E 5395.81W 5979970.67N 613543.93E 5411.64W 5979995.79 N 613527.70 E 5444.87W 5980049.71N 613493.61E 5461.29W 5980076.27 N 613476.76E 5477.46W 5980102.57 N 613460.17 E 5493.70W 5980128.74 N 613443.52E 5509.87W 5980154.77 N 613426.93 E 5526.15W 5980181.15 N 613410.23 E 5542.06W 5980206.90 N 613393.91E 5558.34W 5980233.43 N 613377.20 E 5574.49W 5980259.73 N 613360.64E 5590.10W 5980285.09 N 613344.62 E 5605.92W 5980311.55 N 613328.38 E 5621.70W 5980338.81N 613312.16 E 5636.80W 5980365.20 N 613296.65 E 5652.22W 5980392.08 N 613280.79 E 5667.53W 5980418.54 N 613265.06 E 5683.00W 5980445.12 N 613249.17 E 5699.41W 5980470.58 N 613232.35 E 5716.35W 5980493.99 N 613215.03 E 5734.76W 5980519.18 N 613196.22E 5751.49W 5980542.47N 613179.13 E Dogleg Rate (°ll00ff) 0.015 18.370 7.434 6.787 1.665 1.158 4.174 2.220 1.903 4.144 0.461 1.947 2.044 1.419 4.567 1.334 1.513 2.243 1.603 0.974 19.565 5.558 4.649 3.501 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 5098.85 5109.07 5120.11 5142.43 5163.41 5207.70 5229.57 5251.14 5272.74 5294.26 5315.95 5337.13 5358.87 5380.41 5401.22 5422.48 5443.87 5464.41 5485.38 5506.13 5527.07 5548.69 5570.39 5593.90 56.15.36 Tie-on Survey Window Point Continued... DrillQuest 1.05.05 15 September, 2000 - 23:07 .2 - Sperry-Sun Drilling Services Survey Report for S-101 Your Ref: API-500292296800 Surveyed: 1 September, 2000 North Slope Alaska Measured Depth (fi) Incl. Azlm. Sub-Sea Depth (it) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 9963.80 88.710 326.007 6688.45 6752.86 9995.43 85.502 325.429 6690.04 6754.45 10026.27 85.555 325.077 6692.45 6756.86 10057.29 86.986 324.942 6694.46 6756.87 10088.56 87.229 324.735 6696.04 6760.45 10119.55 87.229 324.795 6697.54 6761.95 10150.51 87.046 324.284 6699.08 6763.49 10180.11 87.165 324.657 6700.58 6754.99 10211.26 87.110 324.714 6702.13 6766.54 10243.08 86.984 324.108 6703.77 6768.18 10277.11 86.983 323.299 6705.56 6769.97 10307.82 86.862 322.459 6707.21 6771.62 10336.87 89.572 323.414 6708.12 6772.53 10368.68 90.679 324.768 6708.05 6772.46 10398.98 90.679 324.320 6707.69 6772.10 10430.30 92.091 324.193 6706.93 6771.34 10461.47 93.447 324.827 6705.42 6769.83 10491.76 93.880 325.000 6703.49 6767.90 10523.66 93.941 325.237 6701.31 6765.72 10555.53 94.002 324.514 6699.11 6763.52 10586.34 93.998 323.919 6696.96 6761.37 10616.45 94.065 323.669 6694.84 6759.25 10647.69 94.066 323.583 6692.63 6757.04 10678.80 94.249 324.240 6690.37 6754.78 10709.69 94.127 323.592 6688.11 6752.52 36.84 N 5770.75W 5980570.05 N 613159.42 E 62.93 N 5788.54W 5980595.86 N 613141.22 E 88.20 N 5806.07W 5980620.84 N 613123.30 E 113.56 N 5823.82W 5980645.91N 613105.15 E 139.09 N 5841.80W 5980671.16 N 613086.76 E 164.37 N 5859.66W 5980696.15 N 613068.50 E 189.56 N 5877.60W 5980721.05 N 613050.16 E 213.61N 5894.78W 5980744.83 N 613032.60 E 239.00N 5912.76W 5980769.93 N 613014.22 E 264.84N 5931.25W 5980795.48 N 612995.32 E 292.23 N 5951.37W 5980822.54 N 612974.77 E 316.68N 5969.88W 5980846.70 N 612955.88E 339.85 N 5987.38W 5980869.58 N 612938.01 E 365.61N 6006.03W 5980895.05 N 612918.95E 390.29 N 6023.61W '5980919.45 N 612900.99 E 415.71N 6041.90W 5980944.56 N 612882.30 E 441.05N 6059.97W 5980969.62N 612863.82 E 465.80 N 6077.34W 5980994.08 N 612846.06 E 491.91N 6095.53W 5981019.91N 612827.46 E 517.91N 6113.82W 5981045.62 N 612808.76 E 542.85 N 6131.79W 5981070.26 N 612790.39 E 567.08N 6149.53W 5981094.21N 612772.27 E 592.17 N 6168.01W 5981119.01N 612753.39 E 617.25 N 6186.29W 5981143.79 N 612734.72E 642.14 N 6204.44W 5981168.39 N 612716.18 E Dogleg Rate (°llOOfl) 9.819 10.305 1.156 4.601 1.020 0.193 1.751 1.321 0.254 1.943 2.374 2.760 9.890 5.498 1.478 4.526 4.801 1.592 0.645 2.271 1.927 0.858 0.275 2.187 2.129 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 5640.23 5663.28 5685.89 5708.74 5731.85 5754.79 5777.78 5799.79 5822.87 5846.55 5872.14 5895.53 5917.66 5941.48 5964.00 5987.39 6010.55 6032.89 6056.33 6079.85 6102.82 6125.41 6148.92 6172.21 6195.35 Continued... 15 September, 2000 - 23:07 - 3. DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-101 Your Ref: AP1-$00292296800 Surveyed: I September, 2000 North Slope Alaska Measured Depth Incl. Azlm. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (fi) (ft) (ft) (ft) 10742.48 90.680 324.408 6686.74 6751.15 10770.91 90.309 323.906 6686.49 6750.90 10803.09 90.183 324.051 6686.36 6750.77 10836.66 90.371 324.227 6686.19 6750.60 10866.43 90.245 323.789 6686.03 6750.44 10898.42 90.183 323.798 6685.91 6750.32 10929.01 90.000 323.134 6685.87 6750.28 10961.17 92.035 323.474 6685.29 6749.70 10990.89 92.154 323.917 6684.21 6748.62 11023.31 91.970 323.406 6683.04 6747.45 11052.92 91.845 322.956 6682.06 6746.47 11084.58 91.663 323.226 6681.09 6745.50 11114.79 91.480 323.139 6680.26 6744.67 11145.70 91.355 322.481 6679.49 6743.90 11177.90 91.662 322.252 6678.65 6743.06 11209.16 91.664 322.551 6677.74 6742.15 11240.31 91.479 322.469 6676.88 6741.29 11271.25 90.126 322.845 6676.45 6740.86 11301.89 89,320 322.982 6676.60 6741.01 11332.88 89.137 323.122 6677.02 6741.43 11365.02 88.464 321.780 6677.69 6742.10 11395.60 87.781 320.576 6678.69 6743.10 11426.35 87.909 320.473 6679.85 6744.26 11457.08 88.275 320.535 6680.87 6745.28 11488.15 89.572 321.522 6681.45 6745.86 668.64N 6223.69W 5981194.58 N 612696.51E 691.69 N 6240.34W 5981217.36 N 612679.50 E 717.72N 6259.26W 5981243.08 N 612660.16 E 744.92 N 6278.93W 5981269.98 N 612640.07 E 769.01N 6296.42W 5981293.78 N 612622.19 E 794.82N 6315.32W 5981319.29 N 612602.89 E 819.40 N 6333.53W 5981343.58 N 612584.29 E 845.18 N 6352.74W 5981369.05N 612564.67 E 869.12 N 6370.33W 5981392.70 N 612546.71E 895.21N 6389.52W 5981418.49 N 612527.10 E 918.90 N 6407.26W 5981441.90 N 612508.99 E 944.21N 6426.26W 5981466.90 N 612489.59E 968.38N 6444.36W 5981490.78N 612471.11E 993.00N 6463.04W 5981515.10 N 612452.04 E 1018.49 N 6482.69W 5981540.27 N 612431.98 E 1043.25 N 6501.76W 5981564.73N 612412.53E 1067.95 N 6520.71W 5981589.13 N 612393.19 E 1092.55 N 6539.47W 5981613.42N 612374.03E 1116.99 N 6557.95W 5981637.57 N 612355.17 E 1141.76 N 6576.58W 5981662.03 N 612336.16 E 1167.23 N 6596.16W 5981687.19 N 612316.17 E 1191.04N 6615.32W 5981710.70 N 612296.64 E 1214.76 N 6634.85W 5981734.11N 612276.73E 1238.46 N 6654.39W 5981757.49 N 612256.82E 1262.61N 6673.93W 5981781.33 N 612236.90 E Dogleg Rate (°llOOfl) 10.802 2,196 0.597 0.767 1.531 0.196 2.252 6.415 1.542 1.674 1.576 1.028 0.671 2.166 1.189 0.956 0.650 4,539 2.668 0.743 4.670 4.525 0.534 1.208 5.245 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 6219.91 6241.18 .6265.31 6290.43 6312.75 6336.82 6359.94 6384.31 6406.69 6431.11 6453.58 6477.64 6500.57 6524.16 6548.89 6572.89 6596.77 6620.44 6643.80 6667.37 6692.03 6715.92 6740.15 6764.38 6788.70 Continued... 15 September, 2000 - 23:07 - 4 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S- 101 Your Ref: API.500292296800 Surveyed: I September, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 11520.03 89.509 321.542 6681.71 6746.12 1287.57 N 6693.76 W 11550.84 89.018 321.342 6682.11 6746.52 1311.66 N 6712.96 W 11583.20 87.910 321.087 6682.97 6747.38 1336.88 N 6733.22 W 11613.51 87.722 320.634 6684.13 6748.54 1360.37 N 6752.34 W 11646.25 87.602 320.281 ' 6685.46 6749.87 1385.60 N 6773.17 W 11721.53 87.602 320.281 6688.61 6753.02 1443.45 N 6821.23W Global Coordinates Northings Eastings (ft) (ft) 5981805.97 N 612216.68 E 5981829.75 N 612197.09 E 5981854.64 N 612176.43E 5981877.83 N 612156.94E 5981902.72 N 612135.72 E 5981959.81N 612086.74 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to S-101. Northings and Eastings are relative to S-101. Dogleg Rate (°llOOft) 0.207 1.721 3.513 1.617 1.138 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (fi) Comment 6813.50 6837.48 6862.75 6886.53 6912.35 6971.86 Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from S-101 and calculated along an Azimuth of 282.580° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11721.53ft., ~"~The Bottom Hole Displacement is 6972.28ft., in the Direction of 281.948° (True). Continued... DrillQuest 1.05.05 15 September, 2000 - 23:07 - 5 - Sperry-Sun Drilling Services Survey Report for S-101 Your Ref: API-500292296800 Surveyed: 1 September, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad Comments Measured Station Coordinates Depth TVD Northinga Eastings (ti) (~t) (~t) (~t) 9189.57 6813.07 616.93 S 5361.95 W 9203.00 6812.08 606.26 S 5370.03 W 11721.53 6753.02 1443.45 N 6821.23 W Comment Tie-on Suwey Window Point Projected Survey Survey tool program From Measured Vertical Depth Depth (~t) (~t) 0.00 0.00 612.00 611.51 To Measured Vertical Depth Depth (~t) (~t) 612.00 611.51 ' 11721.53 6753.02 Survey Tool Description ,. AK-2 BP_CG AK-6 BP_IFR-AK -6- DrillQuest 1.05.05 15 September, 2000 - 23:07 North Slope Alaska Alaska State Plane 4 PBU_ WOA S Pad S-101 MWD Surveyed: 1 September, 2000 SURVEY REPORT 15 September, 2000 Your Ref: API-500292296800 Surface Coordinates: 5980624.83 N, 618930.03 E (70° 21' 20.5864" N, Kelly Bushing: 64.41ft above Mean Sea Level 149° 02' 02.9225" W) Survey Ref: svylO080 Sperry-Sun Drilling Services Survey Report for $-101 MWD Your Ref: API.500292296800 Surveyed: 1 September, 2000 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (~t) (ft) (ft) (ft) 9189.57 94.190 322.870 6748.75 6813.16 9203.00 94.190 322.860 6747.77 6812.18 9217,78 93.260 325,250 6746.81 6811,22 9248.77 94.620 326.760 6744.68 6809.09 9278.81 95.980 327.430 6741.91 6806.32 9310.20 95,050 328.000 6738.89 6803.30 9343.01 96.970 328,630 6735.45 6799.86 9374.69 96.730 329.100 6731,68 6796.09 9405.96 95.420 328.300 6728.37 6792.78 9437.11 94.860 328.550 6725.58 6789.99 9468.08 94.370 328.290 6723.08 6787.49 9499.42 95.670 328.390 6720.34 6784,75 9530.05 95.610 328.000 6717.33 6781.74 9561.54 95.180 328,930 6714.37 6778.78 9592.74 94.680 328.460 6711.69 6776.10 9622.84 95.050 328.730 6709.14 6773.55 9654,03 95.670 330.080 6706.22 6770.63 9685.89 95,360 330.440 6703.16 6767.57 9716.63 94.990 330,550 6700.39 6764.80 9747.95 94.440 330.830 6697,81 6762.22 9778.81 93.940 330.160 6695.56 6759.97 9809.85 93.940 330.650 6693.43 6757.84 9840.40 90.430 326.640 6692.26 6756.67 9869.53 91.480 323,740 6891.78 8756.19 9900.99 92.770 324.200 6690.61 6755.02 604.55 S 5363.34 W 5979935.21 N 613576.96 E 593.87 S 5371.43 W 5979945.76 N 613568.71 E 581.93 $ 5380.08 W 5979957.56 N 613559.86 E 556.30 S 5397.37 W 5979982.91 N 613542.17 E 531.19 S 5413.62 W 5980007.77 N 613525,53 E 504.77 S 5430.31 W 5980033,91 N 613508.42 E 477.01 S 5447.45 W 5980061.40 N 613490.84 E 450.08 S 5463.71 W 5980088.06 N 613474.16 E 423.52 S 5479.86 W 5980114.37 N 613457.58 E 397.09 S 5496.11 W 5980140.54 N 613440.92 E 370.79 S 5512.27 W 5980166.58 N 613424.34 E 344.21 S 5528.66 W 5980192.89 N 613407.53 E 318.31 S 5544.72 W 5980218.53 N 613391.06 E 291.59 $ 5561.12 W 5980244.99 N 613374.24 E 265.03 S 5577.27 W 5980271.29 N 613357.67 E 239.43 $ 5592.90 W 5980296.64 N 613341.64 E 212.70 S 5608.71 W 5980323.11 N 613325.41 E 185.17 S 5624.44 W 5980350,39 N 613309.24 E 158.52 S 5639.51 W 5980376.80 N 613293.74 E 131.31 S 5654.79 W 5980403.77 N 613278.03 E 104.52 S 5669.95 W 5980430.31 N 613262,45 E 77.59 S 5685.25 W 5980456.99 N 613246.73 E 51.50 S 5701.08 W 5980482.82 N 613230.49 E 27.57 S 5717.66 W 5980506.50 N 613213.53 E 2.14 S 5736.16 W 5980531.62 N 613194.63 E Dogleg Rate (°llOOfi) 0.074 17.320 6.549 5.043 3.471 6.156 1,656 4.901 1.967 1.790 4.160 1.282 3.242 2.196 1.520 4,746 1.487 1.255 1,969 2.704 1,575 16.949 11.234 4.353 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 5102.91 5113.13 5124.18 5146.63 5167.96 5190.00 5212.77 5234.51 5256,06 5277.68 5299.18 5320.96 5342.28 5364.11 5385.65 5406.48 5427.73 5449.08 5469.60 5490.44 5511.07 5531.86 5553,00 5574.39 5597.98 Tie-on Survey Window Point Continued... 15 September, 2000- 22:30 - 2- DrillQuest 1,05.05 Sperry-Sun Drilling Services Survey Report for S-101 MWD Your Ref: API-500292296800 Surveyed: 1 September, 2000 North Slope Alaska Measured Depth Incl. Azlm. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (fi) (ft) (rt) 9929.90 91.780 324.380 6689.46 6753.87 9963.80 88.710 325.440 6689.32 6753.73 9995.43 85.500 325.110 6690.91 6755.32 10026.27 85.570 324.650 6693.31 6757.72 10057.29 86.990 325.280 6695.33 6759.74 10088.56 87.230 324.940 6696.90 6761.31 10119.55 87.230 324.740 6698.40 6762.81 10150.51 87.050 324.700 6699.95 6764.36 10180.11 87.170 324.940 6701.44 6765.85 10211.26 87.110 324.950 6702.99 6767.40 10243.08 86.980 324.090 6704.63 6769.04 10277.11 86.980 323.420 6706.43 6770.84 10307.82 86.860 322.900 6708.08 6772.49 10336.87 89.570 323.730 6708.98 6773.39 10368.68 90.680 324.940 6708.91 6773.32 10398.98 90.680 324.510 6708.55 6772.96 10430.30 92.090 324.280 6707.80 6772.21 10461.47 93.450 325.010 6706.29 6770.70 10491.76 93.880 325.200 6704.35 6768.76 10523.66 93.940 325.480 6702.18 6766.59 10555.53 94.000 324.060 6699.97 6764.38 10586.34 94.000 324.540 6697.82 6762.23 10616.45 94.070 324.580 6695.70 6760.11 10647.69 94.070 323.930 6693.49 6757.90 10678.80 94.250 324.400 6691.23 6755.64 Global Coordinates Dogleg Northings Eastings Rate (fi) (fi) (°1100ft) 21.31 N 5753.02 W 5980554.81 N 613177.40 E 49.05 N 5772.50 W 5980582.23 N 613157.48 E 75.01 N 5790.49 W 5980607.90 N 613139.08 E 100.16 N 5808.18 W 5980632.77 N 613120.99 E 125.50 N 5825.95 W 5980657.83 N 613102.82 E 151.12 N 5843.81 W 5980683.16 N 613084.55 E 176.43 N 5861.64 W 5980708.18 N 613066.33 E 201.67 N 5879.50 W 5980733.13 N 613048.07 E 225.83 N 5896.53 W 5980757.02 N 613030.66 E 251.30 N 5914.40 W 5980782.20 N 613012.39 E 277.18 N 5932.84 W 5980807.78 N 612993.53 E 304.58 N 5952.94 W 5980834.87 N 612973.01 E 329.12 N 5971.32 W 5980859.11 N 612954.23 E 352.41 N 5988.67 W 5980882.12 N 612936.52 E 378.25 N 6007.21 W 5980907.66 N 612917.57 E 402.98 N 6024.71 W 5980932.12 N 612899.68 E 428.44 N 6042.94 W 5980957.28 N 612881.05 E 453.83 N 6060.95 W 5980982.38 N 612862.64 E 478.62 N 6078.25 W 5981006.90 N 612844.95 E 504.80 N 6096.35 W 5981032.79 N 612826.44 E 530.77 N 6114.69 W 5981058.46 N 612807.69 E 555.73 N 6132.62 W 5981083.13 N 612789.36 E 580.20 N 6150.04 W 5981107.32 N 612771.56 E 605.49 N 6168.24 W 5981132.32 N 612752.95 E 630.65 N 6186.41 W 5981157.18 N 612734.39 E 3.480 9.581 10.202 1.504 5.006 1.330 0.645 0.596 0.906 0.195 2.730 1.966 1.735 9.756 5.162 1.419 4.561 4.951 1.551 0.896 4.449 1.554 0.268 2.075 1.614 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 5619.54 5644.60 5667.82 5690.56 5713.42 5736.44 5759.34 5782.27 5804.16 5827.15 5850.78 5876.36 5899.65 5921.65 5945.38 5967.85 5991.18 6014.29 6036.57 6059.94 6083.49 6106.43 6128.76 6152.04 6175.24 Continued... 15 September, 2000.22:30 -3- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-101 MWD Your Ref: AP1.500292296800 Surveyed: 1 September, 2000 North Slope Alaska Measured Depth (fi) Incl. Azlm. Sub-Sea Depth Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (fi) (ft) (ft) (ft) (ft) 10709.69 94.130 323. 880 6688.97 6753.38 10742.48 90.680 324.460 6687.60 6752.01 10770.91 90.310 323.870 6687.35 6751.76 10803.09 90.180 323.870 6687.21 6751.62 10836.66 90.370 323.690 6687.05 6751.46 10866.43 90.250 323.560 6686.89 6751.30 10898.42 90.180 322.550 6686.77 6751.1 8 10929.01 90.000 322.080 6686.72 6751.13 10961.17 92.030 322.840 6686.15 6750.56 10990.89 92.150 323.050 6685.07 6749.48 11023.31 91.970 323.070 6683.90 6748.31 11052.92 91.850 322.750 6682.92 6747.33 11084.58 91.660 323.070 6681.95 6748.36 11114.79 91.480 323.160 6681.12 6745.53 11145.70 91.350 322.460 6680.36 6744.77 11177.90 91.660 322.240 6679.51 6743.92 11209.16 91.660 322.580 6678.60 6743.01 11240.31 91.480 322.520 6677.75 6742.16 11271.25 90.120 323.160 6677.32 6741.73 11301.89 89.320 323.100 6677.47 6741.88 11332.88 89.140 323.440 6677.89 6742.30 11365.02 88.460 322.110 6678.56 6742.97 11395.60 87.780 320.750 6679.56 6743.97 11426.35 87.910 321.010 6680.72 6745.13 11457.08 88.280 322.420 6681.74 6746.15 655.62 N 6204.45 W 682.17 N 6223.63 W 705.22 N 6240.27 W 731.21 N 6259.25 W 758.29 N 6279.08 W 782.26 N 6296.74 W 807.83 N 6315.96 W 832.04 N 6334.66 W 857.53 N 6354.25 W 881.23 N 6372.15 W 907.13 N 6391.62 W 930.74 N 6409.47 W 955.98 N 6428.55 W 980.13 N 6446.68 W 1004.75 N 6465.36 W 1030.24 N 6485.02 W 1055.00 N 6504.08 W 1079.72 N 6523.01 W 1104.37 N 6541.70 W 1128.88 N 6560.09 W 1153.72 N 6578.62 W 1179.30 N 6598.05 W 1203.20 N 6617.11 W 1227.04 N 6636.50 W 1251.15 N 6655.53 W Dogleg Rate (°ll00ff) Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) 5981181.86 N 612715.95 E 1.723 6198.30 5981208.11 N 612696.36 E 10.669 6222.80 5981230.89 N 612679.35 E 2.450 6244.06 5981256.58 N 612659.97 E 0.404 6268.24 5981283.34 N 612639.70 E 0.780 6293.50 5981307.03 N 612621.67 E 0.594 6315.95 5981332.29 N 612602.04 E 3.165 6340.28 5981356.20 N 612582.96 E 1.645 6363.81 5981381.38 N 612562.96 E 6.740 6388.48 5981404.79 N 612544.69 E 0.813 6411.11 5981430.37 N 612524.81 E 0.559 6435.75 5981453.69 N 612506.59 E 1.154 6458.31 5981478.63 N 612487.11 E 1.175 6482.44 5981502.49 N 612468.60 E 0.666 6505.39 5981526.81 N 612449.54 E 2.303 6528.98 5981551.98 N 612429.47 E 1.180 6553.72 5981576.44 N 612410.02 E 1.087 6577.72 5981600.85 N 612390.70 E 0.609 6601.58 5981625.21 N 612371.62 E 4.858 6625.19 5981649.42 N 612352,85 E 2.618 6648.47 5981673.96 N 612333.93 E 1.241 6671.97 5981699.24 N 612314.08 E 4.647 6696.51 5981722.83 N 612294.65 E 4.970 6720.31 5981746.35 N 612274.89 E 0.945 6744.43 5981770.16 N 612255.48 E 4.741 6768.25 Comment Continued... 15 September, 2000.22:30 -4- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-101 MWD Your Ref: AP1-$00292296800 Surveyed: I September, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azlm. Depth Depth Northings Eaatings (~t) (h) (~t) (~t) (~t) Global Coordinates Northings Eastings (rt) (~t) 11488.15 89.570 321.680 6682.32 6746.73 1275.64 N 6674.63 W 5981794.34 N 612235.99 E 11520.03 89.510 321.540 6682.58 6746.99 1300.63 N 6694.43 W 5981819.01 N 612215.80 E 11550.84 89.020 321.610 6682.97 6747.38 1324.76 N 6713.57 W 5981842.84 N 612196.27 E 11583.20 87.910 321.330 6683.84 6748.25 1350.07 N 6733.72 W 5981867.82 N 612175.72 E 11613.51 87.720 320.720 6685.00 6749.41 1373.61 N 6752.77 W 5981891.07 N 612156.30 E 11646.25 87.600 320.540 6686.33 6750.74 1398.90 N 6773.52 W 11721.53 87.600 320.540 6689.49 6753.90 1456.97 N 6821.33 W 5981916.02 N 612135.15 E 5981973.33 N 612086.43 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to S-101. Northings and Eastings are relative to $-101. Dogleg Rate (°/lOOft) 4.786 0.478 1.607 3.538 2.107 0.660 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (fi) Comment 6792.23 6816.99 6840.94 6866.11 6889.84 6915.60 6974.90 Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from S-101 and calculated along an Azimuth of 282.580° (True). ~ased upon Minimum Curvature tyPe calculations, at a Measured Depth of 11721.53ft., The Bottom Hole Displacement is 6975.11Nt., in the Direction of 282.057° (True). Continued... 15 September, 2000.22:30 . $. DrillQuest 1.05.05 Sperry-Sun Drilling Services. Survey Report for $-101 MWD Your Ref: AP1.$00292296800 Surveyed: 1 September, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad ~ommente ~.~. Meeeured Depth (fi) 9189.57 9203.00 11721.53 Station Coordinatee TVD Northlnge Eeetinge (fi) (ft) 6813.16 604.55 s 5363.34 w 6812.18 593.87 s 5371.43 W 6753.90 1456.97 N 6821.33 W Comment Tie-on Survey Window Point Projected Survey Survey tool program From Measured Vertical Depth Depth (it) 0.00 0.00 612.23 611.74 To Meaeured Vertical Depth Depth (ft) (fi) 612.23 611.74 '11721.53 6753.90 Survey Tool Description AK-2 BP_CG MWD Magnetic 15 September, 2000 - 22:30 -6- DrillQuest 1.05.05 North Slope Alaska Alaska State Plane 4 PBU_ WOA S Pad S-101 PB1 Surveyed: 9 August, 2000 SURVEY REPORT 09/14/2000 13:48:00 PM Your Reft API.500292296870 Surface Coordinates: 5980624.83 N, 618930.0~tE (70° 21' 20.5864" N, Kelly Bushing: 64.41ft ~bove Mean Sea Level . 149° 02' 02.9225" W) Survey Ref: svy10048 Sperry-Sun Drilling Services Survey Report for S- 101 PB 1 Your Ref: AP1-~00292296870 Surveyed: 9 August, 2000 North Slope Alaska Measured Depth Incl. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -64.41 0.00 80.31 0.500 185.000 15.90 80.31 173.31 1.000 199.000 108.89 173.30 265.81 2.000 216.000 201.36 265.77 358.41 2.750 205.000 293.88 358.29 449.60 2.800 233.000 384.97 449.38 542.60 3.250 236.000 477.84 542.25 612.00 3.868 242.181 547.10 611.51 612.23 3.870 242.198 547.33 611.74 670.45 4.845 246.566 605.38 669.79 763.28 6.727 258.218 697.74 762.15 858.24 7.167 259.854 792.00 856.41 952.65 8.252 263.502 885.56 949.97 1045.86 10.244 263.121 977.55 1041.96 1139.59 11.406 264.083 1069.61 1134.02 1233.63 11.935 262.142 1161.71 1226.12 1323.88 14.012 263.059 1249.65 1314.06 1418.63 15.118 264.690 1341.35 1405.76 1511.99 17.404 262.498 1430.97 1495.38 1604.83 17.661 263.587 1519.50 1583.91 1700.77 19.205 262.934 1610.52 1674.93 1794.70 22.345 260.108 1698.33 1762.74 1886.42 27.564 257.442 1781.46 1845.87 1979.37 28.602 256.086 1863.47 1927.88 2073.47 31.456 255.075 1944.93 2009.34 0.00 N 0.00 E 0.35 S 0.03 W 1.52 S 0.33 W 3.59 S 1.54 W 6.91 S 3.43 W 10.23 S 6.13 W 13.07 $ 10.13 W 15.27 S 13.83 W 15.27 S 13.85 W 17.17 $ 17.84 W 19.84 S 26.76 W 22.02 $ 38.04 W 25.57 S 27.53 S E~2.94 W 29.81 S 101.82 W 32.41 S 121,91 W 34.94 S 145.60 W 37.89 S 171.57 W 41.28 S 199,33 W 44.84 S 229,46 W 49.81 S 262.39 W 57.43 S 300,30 W 67.45 S 342,89 W 79.19 S 388.49 W 5980624.83 N 618930.03E 5980624.48 N 618930.01E 5980623.30 N 618929.72E 5980621.22 N 618928.55 E 5980617.87 N 618926.71E 5980614.50 N 618924.06 E 5980611.60 N 618920.11E 5980609.35 N 618916.44E 5980609.34 N 618916.43E 5980607.38 N 618912.46E 5980604.57 N 618903.59 E 5980602.21N 618892.35 E 5980600.21N 618879.85 E 5980598.22 N 618865.00 E 5980595.99 N 618847.54 E 5980593.40 N 618828.70E 5980590.49 N 618808.65 E 5980587.58 N 618785.00 E 5980584.22 N 618759.08 E 5980580.40 N 618731.38 E 5980576.35 N 618701.32 E 5980570.86 N 618668.47 E 5980562.64 N 618630.68 E 5980551.94N 618588.25 E 5980539.48 N 618542.85 E Dogleg Rate (°/lOOft) 0.623 0.569 1.172 0.944 1.473 0.513 1.047 1.047 1.768 2.380 0.508 1.260 2.138 1.255 0.700 2.313 1.245 2.535 0.449 1.624 3.508 5.819 1.311 3.080 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment o.0o -0.05 -O.Ol 0.72 1.84 3.76 7.04 lO.18 lO.19 13.67 21.80 32.33 44.17 58.30 74.95 92.88 111.93 134.5o 159.20 185.56 214.18 245.24 280.59 319.97 361.91 Camera Based Gyro 80.31' -542.60' AK-6 BP_IFR-AK Continued... 09/14/2000 13:48:01 PM -2- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-101 PB1 Your Ref: API-500292296870 Surveyed: 9 August, 2000 North Slope Alaska Measured Depth (It) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2167.82 35.427 256.249 2023.64 2088.05 2260.34 37.494 258.602 2098.05 2162.46 2353.60 42.998 261.883 2169.22 2233.63 2445.19 45.804 264.201 2234.65 2299.06 2537.95 45.024 264.534 2299.77 2364.18 2631.38 44.625 265.084 2366.04 2430.45 2725.14 44.442 265.157 2432.87 2497.28 2818.26 44.965 264.052 2499.06 2563.47 2909.79 47.344 261.518 2562.46 2626.87 3004.28 48.949 259.085 2625.51 2689.92 3097.57 48.130 258.616 2687.28 2751.69 3191.80 47.171 258.256 2750.76 2815.17 3284.46 46.323 257.599 2814.25 2878.66 3377.32 45.690 260.917 2878.76 2943.17 3469.56 45.468 262.854 2943.32 3007.73 3562.95 45.509 263.447 3008.79 3073.20 3657.46 45.483 263.429 3075.04 3139.45 3751.28 45.315 264.457 3140.92 3205.33 3846.77 44.254 263.357 3208.69 3273.10 3942.67 44.314 260.193 3277.36 3341.77 4028.08 44.441 261.606 3338.40 3402.81 4120.66 44.314 259.001 3404.58 3468.99 4213.79 44.396 258.424 3471.17 3535.58 4307.13 44.178 258.939 3537.99 3602.40 4402.42 43.733 258.357 3606.59 3671.00 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates DOgleg Northings Eastings Rate (ft) (it) (°/lOOft) 92.04 S 438.86 W 5980525.83 N 618492.69 E 103.98 S 492.52 W 5980513.04 N 618439.23 E 114.09 S 551.87 W 5980501.99 N 618380.04 E 121.82 $ 615.47 W 5980493.26 N 618316.57 E 128.30 S 681.22 W 5980485.73 N 618250.94 E 134.26 S 746.81 W 5980478.73 N 618185.45 E 139.86 S 812.33 W 5980472.09 N 618120.03 E 146.02 S 877.54 W 5980464.90 N 618054.92 E 154.34 S 943.01 W 5980455.54 N 617989.59 E 166.21 $ 1012.37 W 5980442.57 N 617920.43 E 179.73 S 1080.96 W 5980427.96 N 617852.06 E 193.69 S 1149.19 W 5980412.92 N 617784.06 E 207.80 S 1215.18 W 5980397.77 N 617718.30 E 220.26 S 128~80 W 5980384.27 N 617652.89 E 229.56 S 134~.01 W 5980373.93 N 617587.83 E 237.50 S 14~2.13 W 5980364.94 N 617521.85 E 245.20 S 1479.09 W · 5980356.18 N 617455.01 E 252.25 $ 1545.52 W 5980348.08 N 617388.71 E 259.38 S 1612.41 W 5980339.88 N 617321.95 E 268.96 S 1678.66 W 5980329.25 N 617255.85 E 278.41 S 1737.64 W 5980318.87 N 617197.03 E 289.31 S 1801.45 W 5980306.96 N 617133.40 E 302.05 S 1865.30 W 5980293.20 N 617069.76 E 314.85 S 1929.21 W 5980279.40 N 617006.07 E 327.86 S 1994.05 W 5980265.35 N 616941.44 E 4.264 2.697 6.323 3.538 0.879 0.595 0.203 1.006 3.277 2.562 0.955 1.056 1.051 2.659 1.519 0.455 0.031 0.800 1.376 2.304 1.167 1.973 0.442 0.451 0.631 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 408.28 458.05 513.78 574.17 636.92 699.64 762.36 824.67 886.76 951.86 1015.87 1079.41 1140.75 1202.08 1263.70 1326.50 1390.18 1453.48 1517.20 1579.78 1635.28 1695.19 1754.73 1814.32 1874.77 Continued... 09/14/2000 13:48:01 PM - 3- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-101 PB1 Your Ref: API.500292296870 Surveyed: 9 August, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim, Sub-Sea Depth (fi) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (fi) (ft) (ft) (ft) (ft) 4495.78 44.022 259.177 3673.88 3738.29 4588.66 43.985 258.431 3740.69 3805.10 4681.50 44.284 258.622 3807.32 3871.73 4773.89 44.635 259,107 3873.27 3937.68 4868.19 44.791 259.191 3940.28 4004.69 4960.75 45.013 258,949 4005.84 4070.25 5055.32 44.277 258.651 4073.13 4137.54 5149.29 44.282 258.773 4140.40 4204.81 5241.78 44.184 261.240 4206.68 4271.09 5336.21 44.387 282.972 4274.28 4338.69 5429.79 44.962 263.210 4340.83 4405.24 5522.95 45.131 263.364 4406,65 4471.06 5615.51 45.168 263.180 4471.92 4536.33 5710.54 45.182 262.534 4538.92 4603.33 5805.17 44.381 260.887 4606.09 4670.50 5897.94 44.499 260.114 4672.32 4736.73 5991.16 45.056 260.013 4738.49 4802.90 6082.08 44.859 259.368 4802.83 4867.24 6183.72 41,894 258.561 4876.70 4941.11 6278.44 41.595 258.093 4947.38 5011.79 8370.44 41.712 258,084 5016.12 5080.53 6464.67 41.984 257.713 5086.31 5150.72 6556.07 42.493 257.727 5153.98 5218.39 6651.42 42.743 258.180 5224.14 5288.55 6745.73 42.750 257.370 5293.40 5357.81 340.47 S 2057.52 W 5980251.74 N 353.00 S 2120.82 W 5980238,21 N 365.85 S 2164.17 W 5980224.35 N 378.35 S 2247.66 W 5980210.84 N 390.84 $ 2312.82 W 5980197.32 N 403.23 $ 2376.98 W 5980183.91 N 416.14 S 2442.16 W 5980169.97 N 428.98 S 2506.50 W 5980156.11 N 440.17 $ 2570.03 W 5980143.91 N 449.23 S 2635.34 W 5980133.82 N 457.14 S 2700,65 W 5980124.87 N 464.85 S 2766.13 W 5980116.13 N 472.54 S 2831.30 W 5980107.41 N 480.92 S 289~17~ W 5980097.96 N 490.52 S 29t~.13 W 5980087.31 N 501.24 S 30~8.19 W 5980075.58 N 512.57 S - 3092.87 W 5980063,22 N 524.07 S 3156.07 W 5980050.72 N 537.41 S 3224.58 W 5980036.29 N 550.17 S 3286.34 W 5980022.55 N 562.79 S 3346.17 W 5980008.99 N 575.97 S 3407.64 W 5979994.83 N 589.04 S 3467.67 W 5979980.81 N 602;51 S 3530.81 W 5979966.34 N 616.07 $ 3593.38 W 5979951.79 N Dogleg Rate (°/~OOft) Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) 616878.17 E 0.683 1933.97 616815.09 E 0.559 1993.02 616751.94 E 0.352 2052.05 616688.66 E 0.529 2111.30 616623.70 E 0.177 2172.17 616559.76 E 0.303 2232.09 616494.78 E 0.809 2292.90 616430,65 E 0.091 2352.90 616367.31 E 1.864 2412.46 616302.16 E 1.299 2474.23 616236.98 E 0.640 2536.25 616171.63 E 0.216 2598.48 616106.59 E 0.146 2660.41 616039.86 E 0.482 2723.85 615974.06 E 1.490 2786.13 615910.18 E 0.597 2846.32 615845.69 E 0.602 2906.98 615782.68 E 0.546 2966.16 615714.39 E 2.968 3030.12 615652.84 E 0.456 3087.62 615593.22 E - 0.127 3143.26 615531.96 E 0.390 3200.38 615472.14 E 0.557 3256.13 615409,23 E 0.415 3314.82 615346.89 E 0.583 3372,93 Comment Continued.., 09/14/2000 13:48:02 PM - 4 - DriilQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-101 PB1 Your Ref: API-500292296870 Surveyed: 9 August, 2000 North Slope Alaska Measured Depth Incl. Azlm. Sub-See Depth (It) 6837.55 41.243 257.593 5361.64 6932.07 39.863 256.646 5433.46 7024.80 39.875 256.702 5504.63 7117.65 39.864 256.750 5575.89 7210.27 39.805 256.528 5647.01 7304.86 39.887 256.903 5719.64 7398.39 39.947 257.594 5791.37 7491.42 39.913 256.395 5862.71 7585.60 40.034 256.418 5934.88 7677.02 40.101 257.256 6004.85 7770.29 39.944 257.010 6076.27 7863.24 39.614 256.804 6147.71 7956.83 40.035 258.112 6219,59 8050.57 42.466 260.621 6290.08 8079.66 44.060 262.223 6311.25 8109.24 44.836 262,909 6332.36 8142.36 45.939 263.062 6355.62 8175.81 48,371 264.654 6378.37 8203.75 50.302 285.523 6396.57 8236.68 51.888 266.271 6417.25 8270.14 54.253 267.777 6437.36 8301.10 56.576 269.709 6454.93 8331.65 58.411 271.048 6471.35 8360.64 60.504 271.919 6486.08 8390.68 62.768 273.370 6500.35 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (It) (ft) (n) (It) (It) 5426.05 629.39 S 5497.87 643.08 S 5569.04 656.78 S 5640.30 670.45 S 5711.42 684.16 S 5764.05 698.08 S 5855.78 711.33 $ 5927.12 724.77 S 5999.29 738.99 S 6069.26 752.39 S 6140.68 765.74 S 6212.12 779.21 S 6264.00 792.23 S 6354.47 803.60 S 6375.66 806.57 S 6396.77 809.25 S 6420.03 812.12 S 6442.78 814.74 S 6460.98 816.55 S 6481.66 818.39 S 6501.77 819.77 S 6519.34 820.32 S 6535.76 820.15 S 6550.49 819.50 S 6564.76 818.28 S 3653.35 W 3713.25 W 3771.09 W 3829.03 W 3886.75 W 3945.73 W 4004.27 W 4062.45 W 4121.26 W 4178.55 W 4237.03 W 4294.96 W 4353.46 W 4477.85 W 4502.23 W 4523.35 W 4548.91 W 4575.61 W 4601.09 W 4626.86 W 4651.81 W 4678.22 W 5979937.52 N 615287.13 E 5979922.88 N 615227.45 E 5979908.26 N 615169.84 E 5979893.68 N 615112.13 E 5979879.06 N 615054.63 E 5979864.19 N 614995.88 E 5979850.02 N 614937.56 E 5979835.66 N 614879.60 E 5979820.51 N 614821.03 E 5979806.20 N 614763.95 E 5979791.92 N 614705.69 E 5979777.53 N 614647.99 E 5979763.59 N 614589.69 E 5979751.26 N 614529.15 E 5979747.97 N 614509.48 E 5979744.97 N 614488.99 E 5979741.72 N 614465.64 E 5979738.71 N 614441.30 E 5979736.57 N 614420.22 E 5979734.33 N 614394.69 E 5979732.52 N 614368.01 E 5979731.57 N 614342.54 E 5979731.33 N 614316.78 E 5979731.58 N 614291.81 E 5979732.39 N 614265.40 E Dogleg Rate (°/lOOft) 1.649 1.599 0,041 0.035 0.166 0.268 0.478 0.828 0.129 0.595 0.239 0.382 1.002 3.136 6.653 3.085 3.347 8.064 7.303 5.130 7.931 9.083 7.053 7.669 8.652 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (it) Comment 3428.56 3484.o4 3537.51 3591 .o8 3644.43 3698.96 3753.21 38o7.o6 386i.36 3914.37 3968.53 4022.13 4076.40 4133.20 4151.79 4171.26 4193.47 4216.69 4236.91 4261.45 4287.22 4311.97 4337.15 4361.65 4387.68 Continued... 09/14/2000 13:48:02 PM . $. DriilQuest 1.05.05 Sperry-Sun Drilling Services Survey RepOrt for S-101 PB1 Your Ref: AP1.$00292296870 Surveyed: 9 August, 2000 North Slope Alaska Measured Depth Incl. Sub-Sea Depth (it) / Vertical Local Coordinates Global Coordinates Depth Northings Eaetings Northings Eastings (ft) (ft) (it) (ft) (it) 8423.36 64.090 273.936 6514.97 6579.38 8453.41 64.720 274.878 6527.95 6592.36 8516.38 64.941 274.903 6554.73 6619.14 8609.51 65.215 274.888 6593.98 6658.39 8701.36 65.104 274.641 6632.56 6696.97 8794.56 64.383 274.649 6672.33 6736.74 8880.30 65.250 278.090 6708.82 6773.23 8906.51 68.903 278.584 6719.03 6783.44 8938.99 73.840 286.596 6729.41 6793.82 8972.20 74.418 293.891 6738.51 6802.92 9000.15 77.596 298.448 6745.27 6809.68 9031.81 82.478 304.220 6750.75 6815.16 9062.00 87.109 309.180 6753.49 6817.90 9096.27 90.371 315.175 6764.24 6818.65 9124.43 93.202 320.851 6753.36 6817.77 9158.57 94.619 323.520 6751.04 6815.45 9189.57 94.188 322.858 6748.66 6813.07 9218.09 97.462 322.683 6745.76 6810.17 9251.77 97.279 323.583 6741.44 6805.85 9283.16 96.909 322.752 6737.56 6801.97 9311.54 96.663 323.451 6734.21 6798.62 9345.98 96.228 323.014 6730.34 6794.75 9377.23 95.666 322.153 6727.11 6791.52 9404.37 98.457 322.205 6723.77 6788.18 9440.02 98.832 322.247 6718.41 6782.82 816.41S 4707.38W 5979733.79 N 614236.20 E 814.33S 4734.40W 5979735.44 N 614209.15 E 809.47S 4791.19W 5979739.40 N 614152.30 E 802.26 S 4875.34W 5979745.27 N 614068.04E 795.34S 4958.40W 5979750.87 N 613984.88 E 788.52S 5042.41W 5979756.36 N 613900.77E 779.90 S 5119.51W 5979763.75 N 613823.55 E 776.40 S 5143.39W 5979766.87 N 613799.62E 76~67 $ 5173.38W 5979773.13N 613769.52 E 758.62 S 5203.33W 5979783.70 N 613739.40 E 746.66S 5227.66W 5979795.27 N 613714.89 E 730.45S 5254.26W 5979811.06 N 613688.02E 712.48S 5278.35W 5979828.64 N 613663.65 E 689.49 S 530~173W 5979851.22 N 613637.92 E -- 668.58 S 532~55W 5979871.83 N 613618.77E 641.68 S 53~3.43W 5979898.40 N 613597.46 E 616.93 S 5361.95W 5979922.85 N 613578.55 E 594.35 S 5379.11W 5979945.16 N 613561.03 E 567.62 S 5399.15W 5979971.56 N 613540.57E 542.69 S 5417.82W 5979996.19 N 613521.50 E 520.16 S 5434.74W 5980018.46 N 613504.23 E 492.74S 5455.23W 5980045.54 N 613483.31E 468.06S 5474.11W 5980069.93 N 613464.04E 446.78 S 5490.63W 5980090.94 N 613447.19 E 418.92S 5512.22W 5980118.45 N 613425.16 E Dogleg Rate (°/lOOft) 4.332 3.520 0.353 0.295 0.272 0.774 3.770 14.045 27.873 21.199 19.480 23.664 22.424 19.910 22.514 8.835 2.543 11.496 2.705 2.879 2.595 1.785 3.278 10.285 1.058 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (it) Comment 4416.56 4443.38 4499.86 4583.56 4666.14 4749.62 4826.74 485o.81 4881.55 4913.18 4939.53 4969.03 4996.45 5026.23 5049.15 5075.39 5098.85 5120.52 5145.90 5169.56 5190.98 5216.94 5240.75 5261.50 5288.64 Continued... 09/14/2000 13:48:04 PM - 6 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-101 PB1 Your Ref: API.500292296870 Surveyed: 9 August, 2000 North Slope Alaska Meaaured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ti) (ft) (ft) (fi) (ft) Global Coordinates Dogleg Northings Eastings Rate (fl) (fi) (°/lOOft) 9468.23 98.581 321.779 6714.14 6778.55 396.95 S 5529.38 9498.78 98.150 321.584 6709.70 6774.11 373.23 S 5548.12 9528.55 97.343 321.936 6705.68 6770.09 350.06 S 5566.38 9559.72 96.910 322.139 6701.82 6766.23 325.68 $ 5585.40 9591.67 96.467 321.681 6698.10 6762.51 300.70 S 5604~98 9621.57 95.912 321.395 6694.87 6759.28 277.43 S 5623.47 9652.59 95.667 321.279 6691.74 6756.15 253.33 S 5642.75 9683.88 95.795 321.637 6688.62 6753.03 228.98 S 5662.15 9714.11 97.586 323.785 6685.10 6749.51 205.09 S 5680.34 9748.33 97.339 323.549 6680.65 6745.06 177.76 S 5700.44 9777.01 96.778 322.491 6677.13 6741.54 155.02 S 5717.56 9807.41 95.604 324.002 6673.85 6738.26 130.81 S 5738.64 9819.58 94.189 323.929 6672.81 6737.22 121.01 S 5742.78 9894.00 94.189 323.929 6667.37 6731.78 61.01 S 578~48 Ail data is in feet unless otherwise stated. Directions and coordinates are relative to ~"~,,'~Vertical depths are relative to S-101. Northings and Eastings are relative to S-101. W 5980140.15 N 613407.65 E W 5980163.56 N 613388.53 E W 5980186.44 N 613369.91 E W 5980210.52 N 613350.50 E W 5980235.18 N 613330.53 E W 5980258.16 N 613311.67 E W 5980281.95 N 613292.01 E W 5980305.99 N 613272.23 E W 5980329.58 N 613253.67 E W 5980356.59 N ~ 613233.13 E W 5980379.05 N 613215.65 E W 5980402.98 N 613197.19 E W 5980412.67 N 613189.90 E W 5980471.96 N 613145.25 E True North. 1.866 1.546 2.953 1.532 1.987 2.086 0.873 1.210 9.214 0.994 4.151 6.271 11.642 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 5310.18 5333.63 5356.50 5380.38 5404.93 5428.04 5452.11 5476.34 5499.30 5524.87 5546.53 5569.46 5578.55 5634.27 Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from S-101 and calculated along an Azimuth of 282.580° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9894.00ft., The Bottom Hole Displacement is 5786.80ft., in the Direction of 269.396° (True). Continued... 09/14/2000 13:48:04 PM - 7- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-101 PB1 Your Ref: AP1.$00292296870 Surveyed: 9 August, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad Comments Measured Depth (ft) 80.31 9894.00 Station Coordinates TVD Northinga Eastinge (fi) (fi) (fi) 80.31 0.35 S 0.03 w 6731.78 61.01 S 5786.48 W Comment Camera Based Gyro 80.31' - 542.60' Projected Survey Survey tool program From Meaeured Vertical Depth Depth (ft) (fi) 0.00 0.00 612.00 611.51 To Measured Vertical Depth Depth (ft) (fi) 612.00 611.51 9894.00 6731.78 Survey Tool Description AK-2 BP_CG AK-6 BP_IFR-AK DrillQuest 1.05.05 09/14/2000 13:48:05 PM - 8 - North Slope Alaska Alaska State Plane 4 PBU_ WOA S Pad S-101 PB1 MWD Surveyed: 25 August, 2000 SURVEY REPORT 09/i 4/2000 13:41:40 PM Your Ref: API-500292296870 Surface Coordinates: 5980624.83 N, 618930.03~E (70° 21' 20.5864" N, Kelly Bushing: 64.41fl ~ove Mean Sea Level ., 149° 02' 02.9225" W) ITl Survey Ref: svy10046 Sperry-Sun Drilling Services Survey Report for S-101 PB1 MWD Your Ref: API.500292296870 Surveyed: 25 August, 2000 North Slope Alaska Meaaured Depth (It) Incl. Azim. Sub-Sea Depth Vertical Local Coordinates Global Coordinates Depth Northinge Eastings Northings Eastings (ft) (ft) (ft) (fi) (fi) 0.00 0.000 0.000 -64.41 0.00 80.31 0.500 185.000 15.90 80.31 173.31 1.000 199.000 108.89 173.30 265.81 2.000 216.000 201.36 265.77 358.41 2.750 205.000 293.88 358.29 449.60 2.800 233.000 384.97 449.38 542.60 3.250 236.000 477.84 542.25 612.23 3.870 243.400 547.33 611.74 670.45 4.850 248.800 605.38 669.79 763.28 6.730 260.410 697.74 762.15 858.24 7.170 260.890 792.00 856.41 952.65 8.250 264.100 885.56 949.97 1045.86 10.240 263.280 977.55 1041.96' 1139.59 11.410 264.630 1069.61 1134.02 1233.63 11.940 262.080 1161.71 1226.12 1323.88 14.010 262.520 1249.65 1314.06 1418.63 15.120 264.650 1341.35 1405.76 1511.99 17.400 262.890 1430.97 1495.38 1604.83 17.660 264.240 1519.50 1583.91 1700.77 19.200 264.600 1610.52 1674.93 1794.70 22.340 261.610 1698.33 1762.74 1886.42 27.560 259.500 1781.47 1845.88 1979.37 28.600 257.490 1863.48 1927.89 2073.47 31.460 255.640 1944.94 2009.35 2167.82 35.430 258.120 2023.65 2088.06 0.00 N 0.00 E 0.35 S 0.03 W 1.52 S 0.33 W 3.59 S 1.64 W 6.91 S 3.43 W 10.23 $ 6.13 W 13.07 S 10.13 W 15.23 S 13.87 W 17.00 S 17.92 W 19.33 S 26.95 W 21.19 $ 38.28 W 22.82 S 50.84 W 24.48 S 65.72 W 26.32 S 8~.23 W '28.53 S 10~2.12 W 31.24 S 122.20 W 33.89 S 145.88 W 36.75 S 171.86 W 39.88 S 199.64 W 42.83 $ 229.83 W 46.88 $ 262.88 W 53.30 S 301.01 W 62.04 S 343.88 W 73.01 S 389.66 W 84.75 S 440.30 W 5980624.83 N 618930.03 E 5980624.48 N 618930.01 E 5980623.30 N 618929.72 E 5980621.22 N 618928.55 E 5980617.87 N 618926.71 E 5980614.50 N 618924.06 E 5980611.60 N 618920.11 E 5980609.38 N 618916.40 E 5980607.55 N 618912.38 E 5980605.08 N 618903.39 E 5980603.03 N 618892.09 E 5980601.21 N 618879.56 E 5980599.31 N 618864.71 E 5980597.19 N 618847.23 E 5980594.68 N 618828.37 E 5980591.65 N 618808.34 E 5980588.63 N 618784.71 E 5980585.36 N 618758.78 E 5980581.79 N 618731.05 E 5980578.36 N 618700.91 E 5980573.78 N 618667.93 E 5980566.76 N 618629.90 E 5980557.34 N 618587.18 E 5980545.64 N 618541.58 E 5980533.10 N 618491.13 E Dogleg Rate (°/lOOfl) 0.623 0.569 1.172 0.944 1.473 0.513 1.107 1.823 2.376 0.467 1.231 2.140 1.277 0.786 2.296 1.301 2.498 0.520 1.610 3.527 5.773 1.512 3.194 4.449 . Alaska State Plane 4 PBU_WOA S Pad Vertical Section (it) Comment 0.00 -0.05 -0.01 0.72 1.84 3.76 7.04 10.22 13.79 22.09 32.75 44.65 58.81 75.50 93.46 112.46 135.00 159.73 186.16 214.98 246.35 282.18 322.11 364.41 411.27 Camera Based Gyro's 80.31' - 542.60 MWD Magnetic Continued... 09/14/2000 13:41:42 PM - 2 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-101 PB1 MWD Your Ref: APi-$00292296870 Surveyed: 25 August, 2000 North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (~t) 2260.34 37.490 258.880 2098.06 2353.60 43.000 260.010 2169.22 2445.19 45.800 263.640 2234.66 2537.95 45.020 261.820 2299.78 2631.38 44.620 265.190 2366.07 2725.14 44.440 265.650 2432.91 2818.26 44.970. 264.080 2499,09 2909.79 47.340 261.680 2562.50 3004.28 48.950 259.260 2625.55 3097.57 48.130 259.300 2687.31 3191.80 47.170 258.610 2750.79 3284.46 46.320 257.640 2814.29 3377.32 45.690 260.840 2878.80 3469.56 45.470 262.780 2943.36 3562.95 45.510 263.610 3008.83 3657.46 45.480 262.980 3075.08 3751.28 45.320 263.740 3140.95 3846.77 44.250 263.090 3208.73 3942.67 44.310 260.040 3277.39 4028.08 44.440 260.070 3338.44 4120.66 44.310 259.040 3404.62 4213.79 44.400 258.740 3471.21 4307.13 44.180 259.190 3538.02 4402.42 43.730 258.240 3608.62 4495.78 44.020 259.520 3673.92 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 2162.47 95.70 S 494.17 W 5980521.29 N 618437.44 E 2233.63 106.70 S 553.39 W 5980509.36 N 618378.41 E 2299.07 115.76 S 616.80 W 5980499.29 N 618315.15 E 2364.19 124.11 S 682.32 W 5980489.90 N 618249.77 E 2430.48 131.57 $ 747.73 W 5980481.41 N 618184.48 E 2497.32 136.82 S 813.28 W 5980475.12 N 618119.03 E 2563.50 142.70 S 878.51 W 5980468.20 N 618053.89 E 2626.91 150.92 S 944.00 W 5980458.94 N 617988.55 E 2689.96 162.59 S 1013.39 W 5980446.17 N 617919.35 E 2751.72 175.60 S 1082.08 W 5980432.08 N 617850.87 E 2815.20 188.94 S 1150.43 W 5980417.65 N 617782.74 E 2878.70 202.82 S 1216.47 W 5980402.72 N 617716.93 E 2943.21 215.30 S 1282.08 W 5980389.21 N 617651.53 E 3007.77 224.68 S 1347,~28 W 5980378.79 N 617586.48 E 3073.24 232.57 S 141~.41 W 5980369.85 N 617520.49 E 3139.49 240.44 S 1480.35 W 5980360.91 N 617453.68 E 3205.36 248.17 S 1546.71 W 5980352.14 N 617387.46 E 3273.14 255.88 $ 1613.53 W 5980343.37 N 617320.77 E 3341.80 265.70 S 1679.74 W 5980332.50 N 617254.72 E 3402.85 276.01 S 1738.58 W 5980321.25 N 617196.05 E 3469.03 287.75 S 1802.25 W 5980308.50 N 617132.58 E 3535.62 300.30 S 1866.14 W 5980294.94 N 617068.90 E 3602.43 312.77 S 1930.11 W 5980281.45 N 617005.13 E 3671.03 325.71 S 1994.97 W 5980267.49 N 616940.48 E 3738.33 338.19 S 2058.46 W 5980254.00 N 616877.20 E Dogleg Rate (°/lOOft) 2.279 5.960 4.126 1.631 2.578 0.394 1.336 3.192 2.558 0.880 1.154 1.193 2.570 1.521 0.635 0.476. 0.601 1.219 2.221 0.154 0.791 0.245 0.411 0.838 1.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 461.47 516.86 576.78 638,91 701.13 763.95 826.34 888.46 953.65 1017.86 lO81.66 1143.09 1204.41 1266.00 1328.83 1392.45 1455.52 1519.06 1581.55 1636.72 1696.31 1755.93 1815.65 1876.13 1935.38 Continued... 09/14/2000 13:41:43 PM - 3 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-101 PB1 MWD Your Ref: AP1-$00292296870 Surveyed: 25 August, 2000 North Slope Alaska Meaaured Depth Incl. Azlm. Sub-Sea Depth (fi) Vertical Local Coordinates Global Coordinates Depth Northings Fastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 4588.66 43.980 258.430 3740.73 3805.14 4681.50 44.280 259.330 3807.37 3871.78 4773.89 44.640 258.850 3873.31 3937.72 4868.19 44.790 259.200 3940.33 4004.74 4960.75 45.010 258.410 4005.89 4070.30 5055.32 44.280 259.190 4073.17 4137.58 5149.29 44.280 258.750 4140.45 4204.86 5241.78 44.180 261.460 4206.73 4271.14 5336.21 44.390 262.850 4274.33 4338.74 5429.79 44.960 263.570 4340.88 4405.29 5522.95 45.130 263.280 4406.70 4471.11 5615.51 45.170 264.690 4471.98 4536.39 5710.54 45.180 263.440 4538.97 4603.38 5805.17 44.380 261:100 4606.15 4670.56 5897.94 44.500 260.220 4672.38 4736.79 5991.16 45.060 259.500 4738.55 4802.96 6082.08 44.860 259.990 4802.89 4867.30 6183.72 41.890 258.610 4876.76 4941.17 6278.44 41.590 258.420 4947.44 5011.85 6370.44 41.710 258.100 5016.18 5080.59 6464.67 41.980 258.530 5086.38 5150.79 6556.07 42.490 257.820 5154.05 5218.46 6651.42 42.740 258.090 5224.22 5288.63 6745.73 42.750 257.790 5293.46 5357.89 6837.55 41.240 257.460 5361.72 5426.13 350.53 S 2121.79 W 5980240.66 N 616814.08 E 363.00 S 2185.21 W 5980227.19 N 616750.85 E 375.24 $ 2248.76 W 5980213.93 N 616687.52 E 387.87 S 2313.89 W 5980200.27 N 616622.59 E 400.56 S 2377.98 W 5980186.57 N 616558.71 E 413.47 S 2443.17 W 5980172.62 N 616493.73 E 426.02 S 2507.56 W 5980159.05 N 616429.55 E 437.11 S 2571.11 W 5980146.96 N 616366.19 E 446.11 S 2636.42 W 5980136.93 N 616301.02 E 453.88 S 2701.75 W 5980128.11 N 616235.82 E 461.43 S 2767.24 W 5980119.52 N 616170.46 E 468.31 S 2832.50 W 5980111.61 N 616105.32 E 475.28 S 2899.54 W 5980103.58 N 616038.40 E 484.23 S 296528 W 5980093.58 N 615972.51 E 494.77 $ 302~ff67 W 5980082.02 N 615908.60 E 506.34 S 3094.31 W 5980069.43 N 615844.15 E 517.77 S 3157.53 W 5980056.99 N 615781.12 E 530.71 S 3226.11 W 5980042.97 N 615712.75 E 543.26 S 3287.91 W 5980029.44 N 615651.16 E 555.70 S 3347.77 W 5980016.05 N 615591.51 E 568.44 S 3409.33 W 5980002.34 N 615530.16 E 581.03 S 3469.46 W 5979988.80 N 615470.23 E 594.50 $ 3532.60 W 5979974.32 N 615407.32 E 607.87 S 3595.19 W 5979959.96 N 615344.94 E 621.04 S 3655.20 W 5979945.84 N 615285.15 E Dogleg Rate (°/lOOfl) 0.816 0.748 0.533 0.306 0,648 0.965 0.327 2.047 1.052 0.815 0.286 1.081 0.933 1.936 0.677 0.810 0.440 3.067 0.344 0.265 0.418 0.764 0.325 0.216 1.662 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 1994.50 2053.69 2113.o4 2173,86 2233.65 2294.46 2354.57 2414.18 2475.96 2538.03 26oo.31 2662.50 2726.41 2788.92 2849.17 2909.74 2968.95 3033.o7 3090.65 3146.36 3203.67 3259.62 3318.3o 3376,49 3432.19 Continued... 09/14/2000 13:41:43 PM .4 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-101 PB1 MWD Your Ref: AP1-$00292296870 Surveyed: 25 August, 2000 North Slope Alaska Measured Depth (tt) Incl. Azim. Sub-Sea Depth (fi) Vertical Local Coordinates Global Coordinates Depth Northings Eestings Northings Eastings (~t) (~t) (~t) (ft) (~t) 6932.07 39.860 257.060 5433.54 5497.95 7024.80 39.870 256.980 5504.71 5569.12 7117.65 39.860 256.630 5575.98 5640.39 7210.27 39.810 256.970 5647.10 5711.51 7304.86 39.890 256.310 5719.72 5784.13 7398.39 39.950 257.220 5791.46 5855.87 7491.42 39.910 255.980 5862.80 5927.21 7585.60 40.030 256.380 5934.97 5999.38 7677.02 40.100 257.160 6004.94 6069.35 7770.29 39.940 257.640 6076.37 6140.78 7863.24 39.610 257.150 6147.80 6212.21 7956.83 40.030 258.130 6219.69 6264.10 8050.57 42.470 260.290 6290.16 6354.57 8079.66 44.060 261.600 6311.35 6375.76 8109.24 44.840 262.180 6332.46 6396.87 8142.36 45.940 263.290 6355.72 6420.13 8175.81 48.370 264.430 6378.47 6442.88 8203.75 50.300 265.570 6396.67 6461.08 8236.68 51.890 266.700 6417.35 6481.76 8270.14 54.250 267.880 6437.46 6501.87 8301.10 56.580 269.810 6455.03 6519.44 8331.65 58.410 270.810 6471.45 6535.86 8360.64 60.500 272.930 6486.18 6550.59 8390.68 62.770 274°080 6500.45 6564.86 8423.36 64.090 274.140 6515.07 6579.48 634.58 S 3715.13 W 5979931.35 N 615225.44 E 647.93 S 3773.05 W 5979917.08 N 615167.74 E 661.52 S 3831.00 W 5979902.57 N 615110.02 E 675.07 S 3888.76 W 5979888.11 N 615052.48 E 689.07 $ 3947.73 W 5979873.17 N 614993.74 E 702.81 S 4006.15 W 5979858.50 N 614935.54 E 716.65 S 4064.24 W 5979843.75 N 614877.68 E 731.10 S 4122.99 W 5979828.36 N 614819.17 E 744.57 S 4180.27 W 5979813.99 N 614762.11 E 757.65 S 4238.80 W 5979799.98 N 614703.79 E 770.63 S 4296.83 W 5979786.08 N 614645.97 E 783.48 $ 4355.38 W 5979772.33 N 614587.64 E 795.00 S 4416.08 W 5979759.83 N 614527.12 E 798.13 S 4435~T7 W 5979756.38 N 614507.49 E 801.05 $ ~4456~28 W 5979753.13 N 614487.03 E 804.03 S 4479.67 W 5979749.78 N 614463.69 E 806.65 S 4504.05 W 5979748.78 N 614439.36 E 808.49 S 4525.16 W 5979744.60 N 614418.28 E 810.22 S 4550.73 W 5979742.47 N 614392.74 E 811.48 S 4577.44 W 5979740.78 N 614366.05 E 811.99 S 4602.92 W 5979739.87 N 614340.58 E 811.64 S 4628.68 W 5979739.60 N 614314.82 E 811.02 S 4653.63 W 5979740.03 N 614289.86 E 809.41 S 4680.01 W 5979741.23 N 614263.46 E 807.31 S 4709.17 W 5979742.86 N 614234.27 E Dogleg Rate (°/lOOft) 1.486 0.056 0.242 0.241 0.455 0.628 0.857 0.301 0.554 0.373 0.490 0.807 3.014 6.277 2.973 4.089 7.682 7.569 5.518 7.595 9.109 6.596 9.572 8.273 4.043 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 3487.73 3541.35 3594.95 3648.37 3702.87 3756.90 381o.58 3864.77 3917.74 3972.02 4025.83 408o.18 4136.91 4155.45 4174.82 4197.o0 4220.23 4240.43 4265.01 4290.81 4315.57 4340.74 4365,27 4391.37 4420,28 Continued... 09/14/2000 13:41:44 PM - 5 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-101 PB1 MWD Your Ref: AP1-$00292296870 Surveyed: 25 August, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Fastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 8453.41 64.720 273.880 6528.05 6592.46 8516.38 64.940 274.990 6554.83 6619.24 8609.51 65.220 275.370 6594.07 6658.48 8701.36 65.100 275.230 6632.66 6697.07 8794.56 64.380 276.100 6672.43 6736.84 8880.30 65.250 278.090 6708.92 6773.33 8906.51 68.900 278.700 6719.13 6783.54 8938.99 73.840 286.860 6729.51 6793.92 8972.20 74.420 294.100 6738.61 6803.02 9000.15 77.600 298.460 6745.37 6809.78 9031.81 82. 480 304.140 6750.85 6815.26 9062.00 87.110 309.040 6753.58 6817.99 9096.27 90.370 315.260 6754.34 6818.75 9124.43 93.200 320.890 6753.46 6817.87 9158.57 94.620 323.560 6751.13 6815.54 9189.57 94.190 322.870 6748.75 6813.16 9218.09 97.460 322.750 6745.86 6810.27 9251.77 97.280 323.600 6741.54 6805.95 9283.16 96.910 322.720 6737.66 6802.07 9311.54 98.660 323.420 6734.31 6798.72 9345.98 96.230 322.990 6730.44 6794.85 9377.23 95.670 322.120 6727.20 6791.61 9404.37 98.460 322.180 6723.86 6788.27 9440.02 98.830 322.270 6718.51 6782.92 9468.23 98.580 321.720 6714.24 6778.65 805.42 S 801.01 S 793.38 S 785.68 S 777.37 S 767.78 S 764.25 S 757.42 S 746.25 S 734.24 S 718.04 S 700.13 S 677.15 S 656.22 S 629.30 S 604.5-5 S 581.95 S 555.21 S 530.28 $ 507.75 S 480,35 S 455.67 S 434.41 S 406.55 S 384.58 S 4736.20 W 5979744.33 N 614207.21 E 4793.02 W 5979747.83 N 614150.33 E 4877.13 W 5979754.12 N 614066.11 E 4960.13 W 5979760.50 N 613983.00 E 5044.01 W 5979767.49 N 613899.00 E 5120.99 W 5979775.85 N 613821.87 E 5144.87 W 5979779.00 N 613797.94 E 5174.84 W 5979785.35 N 613767.87 E 5204.74 W 5979796.04 N 613737.79 E 5229.05 W 5979807.67 N 613713.30 E 5255.67 W 5979823.44 N 613686.43 E 5279.79 W 5979840.97 N 613662.02 E 5305.17 W 5979863.54 N 613636.28 E 5323~97 W 5979864.17 N 613617.15 E 534~.83 W 5979910.76 N 613595.86 E 5363.34 W 5979935.21 N 613576.96 E 5380.49 W 5979957.54 N 613559.46 E 5400.51 W 5979983.95 N 613539.02 E 5419.19 W 5980008.58 N 613519.95 E 5436.12 W 5980030.84 N 613502.66 E 5456.62 W 5980057.91 N 613481.73 E 5475.51 W 5980082.29 N 613462.44 E 5492.04 W 5980103.29 N 613445.58 E 5513.63 W 5980130.80 N 613423.55 E 5530.80 W 5980152.50 N 613406.04 E Dogleg Rate (°llOOft) 2.237 1.633 0.477 0.190 1.144 2.333 14.090 28.240 21.041 18.934 23.444 22.278 20.486 22.366 8.842 2.617 11.473 2.559 3.021 2.603 1.760 3.298 10.282 1.067 2.121 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 4447.08 4503.49 4587.25 4669.93 4753.60 4830.83 4854.90 4885.64 4917.25 4943.59 4973.10 5000.55 5030.33 5053.23 5079.46 5102.91 5124.57 5149.93 5173.59 5195.02 5221.00 5244.81 5265.57 5292.71 5314.26 Continued... 09/14/2000 13:41:45 PM -6- DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-101 PB1 MWD Your Ref: API.500292296870 Surveyed: 25 August, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azlm. Depth Depth Northings Eastings (tt) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (fi) 9498.78 98.150 321.520 6709.79 6774.20 360.88 S 5549.56 W 5980175.89 N 9528.55 97.340 321.820 6705.78 6770.19 337.74 $ 5567.86 W 5980198.74 N 9559.72 96.910 321.880 6701.91 6766.32 313.42 S 5586.96 W 5980222.75 N 9591.67 96.470 321.390 6698.19 6762.60 288.54 S 5606.66 W 5980247.32 N 9621.57 95.910 321.230 6694.97 6759.38 265.34 $ 5625.24 W 5980270.22 N 9652.59 95.670 321.140 6691.84 6756.25 241.29 S 5644.58 W 5980293.96 N 9683.88 95.790 321.640 6688.71 6753.12 216.96 S 5664.01 W 5980317.97 N 9714.11 97.590 323.620 6685.19 6749.60 193.11 S 5682.23 W 5980341.54 N 9748.33 97.340 323.620 6680.75 6745.16 165.79 S 5702.36 W 5980368.53 N 9777.01 96.780 322.590 6677.22 6741.63 143.03 $ 5719.45 W 5980391.02 N 9807.41 95.600 324.120 6673.94 6738.35 118.78 S 5737.48 W 5980414.98 N 9819.58 94.190 324.130 6672.90 6737.31 108.95 S 5744.59 W 5980424.69 N 9894.00 94.190 324.130 6667.47 6731.88 48.81 S 5788.08 W 5980484.14 N All data is in feet unless otherwise stated. Directions and coordinates are relativ to True North. ~ertical depths are relative to S-101. Northings and Eastings are relative to S-101. 613386.9o E 613368.24 E 613348.75 E 613328.66 E 613309.71 E 613289.99 E 613270.18 E 613251.58 E 613231.02 E 613213.57 E 613195.15 E 613187.89 E 613143.45 E Dogleg Rate (°/lOOft) 1.549 2.898 1.393 2.053 1.947 0.826 1.636 8.819 0.731 4.064 6.333 11.586 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) Comment 5337.73 5360.63 5384.57 54o9.21 5432.40 5456.52 5480.78 55o3.76 5529.35 5550.99 5573.87 5582.95 5638~49 Projected Survey The Dogleg Severity is in Degrees per 100ft. Vertical Section is from S-101 and calculated along an Azimuth of 282.580° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9894.00ft., The Bottom Hole Displacement is 5788.29ft., in the Direction of 269.517° (True). Continued... 09/14/2000 13:41:45 PM - 7 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for S-101 PB1 MWD Your Ref: API.500292296870 Surveyed: 25 August, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad ~.~,,,:omments Measured Depth (ft) 80.31 9894.00 Station Coordinates TVD Northings Fastings (fi) (ft) 80.31 0.35 S 0.03 W 6731.88 48.81 S 5788.08 W Comment Camera Based Gym's 80.31' - 542.60 Projected Survey Survey tool program From Measured Vertl©al Depth Depth (fi) (fi) 0.00 0.00 612.23 611.74 TO Meaaured Vertical Depth Depth (ft) (ft) 612.23 611.74 9894.00 6731.88 Survey Tool Description AK-2 BP_CG MWD Magnetic DrillQuest 1.05.05 09/14/2000 13:41:48 PM - 8 - WELL LOG TRANSMITTAL To~ State of Alaska Alaska Oil and Gas Conservation Comm. Atm.- Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs S-101 PB1, AK-MM-00132 December 29, 2000 1 LDWG formatted Disc with verification listing. API#' 50-029-22968-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF TRANSMITTAL LETrER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin ~ 6900 Arctic Blvd. AnchOrage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: lot To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 December 12, 2000 MWD Formation Evaluation Logs · S-101, AK-MM-00132 S-101: ~" x 5" MD Resistivity & Gamma Ray Logs · 50-029-22968-00 ~" x 5" TVD Resistivity & Gamma Ray Logs · 50-029-22968-00 /2" x 5" MD Neutron & Density Logs: 50-029-22968-00 / ~'2" x 5" TVD Neutron & Density Logs' 50-029-22968-00 Blueline Rolled Sepia Blueline Rolled Sepia ~1' Blueline ~'1 Rolled Sepia Blueline Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY TRANSNfllWAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-teclmical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 OF Date: OI:tlLLI ffi G SEI:tl/I C E S T~ Sta~of-Ataska Alaska Oil and Gas Conservation Comm. A~.: Loft Taylor 3001 Porcupine Dr. Anehorage~..Mask~.99.501 2ooo RE: MWD Formation Evaluation Logs S-101, AK-MM-00132 1 LDWG formatted Disc with verification listing. API/~:50-02%2~68-00 LETTER TO THE ATTENTION OF: ~ Attn: Jim Galvin Anchorage, Alaska 99518 RECEIVED 2000 Petro-Technical Data Center, MB3-3 90,~-K Beme~Btvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company 9/18/00 Sckklmkerger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: $herrle NO. 520 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) Well Job # Log Description Date Blueline SePia Color CD Prints S-101 20377 SCMT 000905 1 J-23 -/~ ¢:~ *'~.~e-I 20302 CH EDIT RST 000710 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnlcal Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 RECEIVED Date Delivered: Naska 0il & Gas Cons. Commission An~hnrnnR Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATrN: 'SherriL~) Received ~ ~ MEMORANDUM TO: Dan Seamount Commissioner THRU: Blair Wondzell P.I. Supervisor FROM: John Crisp~~ d..~.. Petroleum I~pector State of Alaska Alaska Oil and Gas Conservation Commission DATE: 8/22/2000 SUBJECT: Blowout Preventer Test Nabors 9ES BPX S Pad PBU S-101 200-115 Prudhoe Bay Unit NON- CONFIDENTIAL Operator Rep.: Gavin Kidd Contractor Rep.: Rodney Klepsic Op. phone: 659-4831 Rig phone: 659-4806 Op. E-Mail: Rig E-Mail: Test Pressures Rams: 3500 MISC. INSPECTIONS: P/F Location Gen.: Good Housekeeping: Good PTD On Location Yes Standing Order: Yes BOP STACK: Quantity Size P/F Annular Preventer 1 13 5/8" P Pipe Rams 1 2 7/8x5" P Lower Pipe Rams 1 2 7/8x5" P Blind Rams 1 13 5/8" P Choke Ln. Valves 1 3 1/8" P HeR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P Check Valve P/F Sign: Yes Rig cond: Good Hazard: Yes . Annular: 3500 Choke: 3500 TEST DATA FLOOR VALVES: Quantity P/F Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity P/F No. Valves 14 P Man. Chokes 1 Functioned Hyd. Chokes 1 Functoned MUD SYSTEM: Visual Alarm Trip Tank Yes Yes Pit Level Indicators Yes Yes Flow Indicator Yes Yes Meth Gas Detector Tested Tested H2S Gas Detector Tested Tested ACCU M ULATOR SYSTEM: Time/Psi P/F System Pressure 3050 After Closure 1500 ~ 200 psi Attained 27 sec. Full Pressure 3 min. 37 sec. Blind Covers (All Stations): Yes N2 Bottles (avg): 6 btls. 2000 ave. Test's Details I traveled to BP's Prudhoe Bay Field S Pad to witness the weekly BOP test on well S-101. No failures were witnessed. The Rig & Location were clean & well kept. BPX policy of 5 minute low pressure test & 10 minute high pressure test was followed. Total Test Time: $ h.rs. umber of Failures: 0_. cc: Attatchments: O Sheet by L.G. 3/18/00 Vl ifpqtf.xls 8/28/00 ~urface casing upgrade, S-101 Subject: Surface casing upgrade, S-101 ~L~- \ \ ~- Date: Fd, 11 Aug 2000 13:11:23 -0500 From: "Smith, Phil G (FAIR)" <SmithPGl@bp.~3m> To: '"Tom_Maunder@ad min. state, ak. us'" <Tom_Maunder@admin. state, ak. us> CC: "Bunch, Anthony S" <bunchas@bp.com>, "Stone, Dan M (ARCO)" <StoneDM~bp.com>, "Crane, Lowell R (ARCO)" <CraneLR@bp.oom>, "Montgomery, Rick (ASCl)" <MontgoGR@bp.com> Tom, As discuss in our phone conversation today, we are changing the plan for the surface casing on S-101. Due to the unmanageable length ofthe K-55 grade 10-3/4" casing, we will run L-80 grade instead. The weight and connection will remain the same at 45.5#/~t BTC, respectively. PhiIRegards' r..~\~ ~-~ ~-~ -~.e ~\~ \ ~rcb 1 of 1 8/11/00 11:17 AM ALASIIA OIL AND GAS CONSERVATION CO~ISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Stone Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhioe Bay Unit S- 101 BP Exploration (Alaska) Inc. Permit No: 200-115 Sur Loc: 4421'NSL, 4498'WEL, Sec. 35, T12N, R12E, UM Btmhole Loc. 305'NSL, 469'WEL, Sec. 28, T12N, R12E, UM Dear Mr. Stone: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, anie . seamount, Jr. ' Commissioner BY ORDER OF THE COMMISSION DATED this '~ ~ day of August, 2000 dlf/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. P. 1/1 S-101 revised permit Subject: S-101 revised permit Date: Wed, 2 Aug 2000 23:14:52 +0100 From: "Smith, Phil G (FAIR)" <SmithPGl@BP.(~m> To: '"Tom Maunder'" <tom_maunder@admin.state. ak. us> Here's the revised permit. Dan has approved the changes to add a port collar for freeze protection contingency and 100 bbls lead cement fully cement the open hole. Let me know if you need anything else. Thanks, Phil > <<S-101 Permit to Drill .doc>> Name: S-101 Permit to Drill .doc ~S-101 Permit to Drill .doc Type: Microsoft Word Document (application/msword) Encoding: base64 1 of 1 8/2/00 2:57 PM RECEIVED IWell Name: IS-101 Drill and Complete Plan Summary I Type of Well (service I producer I injector)' I Producer Surface Location' Target Location' Kuparuk Bottom Hole Location: X = 618,930.03 Y = 5,980,624.83 4421' FSL 4498' FEL S35 T12N R12E Umiat X = 613,550.00 Y = 5,980,015.00 3894' FSL 4608' FEL S34, T12N, R12E Umiat X = 612,381.00 Y = 5,981,688.00 305' FSL 469' FEL S28, T12N, R12E Umiat I AFE Number: 13A0066 I I Estimated Start Date: 18-5-00 I I MD: I~ 1,362'1 ITvD: 16757' I Rig: I Nabors9ES I Operating days to complete: 127.5 I BF/MS: 135.8' I I.KB' 164.3' I Well Design (conventional, slimhole, etc.)' I Horizontal Slimhole with Production Liner I Obiective: I Kuparuk Formation Mud Program: 13-1/2" Surface Hole (0-3892'): Fresh Water Surface Hole Mud Interval Density Viscosity YP PV Gel-10 Fluid (ppg) (seconds) sec Loss Initial 8.5-9.1 300 75 15-20 25 NC Interval TD 9.1-9.7 100-75 25 20-30 12 NC 9-7~8" Intermediate Hole (3892' -8632'): LSND Interval Density Viscosity YP PV pH APl HTHP (ppg) (seconds) Filtrate Filtrate Surface 10.5 42-53 10-25 10-15 9.0-9.5 6cc <9 shoe to 7" to to by HRZ csg point 11.2 <5 6-1/8" Production Hole (8632' - 11,371') LSND + 6% KCl Interval Density Viscosity YP PV pH APl HTHP (ppg) (seconds) Filtrate Filtrate Production 10.4 40-55 20-27 11-21 9.0-9.5 <6 <10 Hole ., Directional: S-101 Permit to Drill Page 1 KOP: 1500' Maximum Hole Angle: Close Approach Wells: 100° at 9100' MD - production hole None Logging Program: Surface Intermediate Hole Production Hole Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR / Res / Neu / Den / PWD Open Hole: None Cased Hole: None Drilling: MWD / GR / Res / Neu / Den Open Hole: None Cased Hole: None Formation Markers: Formation Tops MD TVDss Comments Base Permafrost 2012 1875 SV3 / T5 3171 2749 Ugnu top (UG4A) 4187 3498 8.93 ppg EMW (pore pressure = 1625) Ugnu. (UG1) 5758 4656 8.80 ppg EMW (pore pressure = 2130) West Sak (WS2) 6073 4888 8.50 ppg EMW (pore pressure = 2160) West Sak (WS1) 6268 5032 8.64 ppg EMW (pore pressure = 2260) Base West Sak 6713 5360 H RZ top 8430 6576 HRZ Base 8595 6686 Kuparuk C4B 8604 6692 Top Target 9.87 EMW (pore pressure = 3435) Kuparuk C4A 8617 6701 Kuparuk C3B 8638 6715 Kuparuk C3A 8707 6757 Base Target Interval Kuparuk C2 6792 Not Penetrated Kuparuk C1 6802 Not Penetrated Kuparuk B, LCU 6812 Not Penetrated ...... Kuparuk A 6887 Not Penetrated Miluveach 6947 Not Penetrated TD 11362 6691 TD Horizontal ,-. S-101 Permit to Drill Page 2 ECEtVED LUG 0'~ '-v,. ' AlasKa Oil & Gas Co~, ~n Casinq/Tubing Proqram: A.c,0 . Hole Csgl Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD bkb 30" 20" 91.5# H-40 WLD 80' GL 109/109 13-1/2" 10_3/4" 45.5# K-55 BTC 3870' GL 3898'/3351' - 9-7~8" 7" 26# L-80 BTC-M 8586' GL 8614'/6765' 6-1/8" 4-1/2" 12.6# L-80 Slotted -2897' 8465'~6657' 11,362'/6757' Tubing 3-1/2" 9.3# 13-Cr Fox -8437' GL 8465'/6657' Cement Calculations: The following cement calculation are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. Cement volumes will be as follows: Lead - as noted for 1st stage. Tail - as noted below for 1st stage. Casing Basis' Size 110 %" Surface - 1s' Stage I Lead: Based on 2000' of annulus in the permafrost @ 250% excess and 1400' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface Total Cement Volume: Tail: Based on 500' MD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At ,,,3400' MD/2924' TVDss). Lead 570 bbl / 3200 ft~ / 721 sks of Dowell ARTICSET Lite 3 at 10.7 ppg and 4.44 cf/sk. Tail 50 bbl / 281 ft~ / 242 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk. Casing Size 17'' Intermediate - 1s~ Stage I Basis: ILead: to 10 %" surface casing shoe (above the Ugnu Formation) and 30% excess Lead TOC: 10 %" shoe at 3898' MD Tail: Based on TOC 500' above top of Kuparuk River formation and 50% excess + shoe Tail TOC: 8114' MD, 6363' ss TVD ITotal Cement Volume: I Lead Tail 248 bbls / 1450 ftc/520 sks of Dowell Extended blend at 11.5 ppg and 2.79 cf/sk. 38 bbls / 213 ftc/184 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk. Casing Size 14-1/2" Production - lS' Stage Basis: Lead: NA Lead TOC: NA Tail: N/^ I Total Cement Volume: r LeadTail IN°neNone Well Control: S-101 Permit to Drill Page 3 Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 3500 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Maximum anticipated BHP: · Maximum surface pressure: 3435 psi @ 6700' TVDss - Kuparuk Target Top 2765 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi#t) · Planned BOP test pressure: 3500 psi · Planned completion fluid: 10.3 ppg KCI/NaCI / NaBr Brine / 6.8 ppg Diesel Drilling Hazards/Contingencies: RECEIVED HYDROGEN SULFIDE - H2S Alaska0it&6asC0ns. C0rmissi0~ · S-Pad is not designated as an H2S site, however Standard Operating I:~l~es for H2S precautions should be followed at all times. The highest level Of H2S recently measured on S-pad has been 60 ppm (S,37, 12/2/98) DRILLING CLOSE APPROACH: Close approach issues are not expected at this time or will be mitigated in the final well plan. SURFACE HOLE SECTION: · Directional control was an issue in the S-100 surface hole. Response to sliding in the permafrost was hampered through the gravel intervals, presumably the washed-out sections. Doglegs should be kept below 12.5° for casing running. · The surface hole interval on S-Pad has been relatively problem free on most wells to date. Only one well (S-22, 1990) is recorded with lost circulation problems. S-22 experienced lost circulation while drilling and cementing both. · Some tight hole has been noted while running casing, in particular with 13-3/8" casing in 16" hole. · A fault has been identified in the lower several hundred feet of the permafrost. This fault has been encountered in virtually all S-pad wells with no directly attributed incidents reported. · Heavy clays are reported in the 2000-3000' TVD area of S-pad. · Produced water injection has over-pressured the SV3/Cretaceous zone. Recent well S- 40 required 9.3 ppg mud to drill this interval. S-101 Permit to Drill Page 4 INTERMEDIATE HOLE SECTION: · A major north-south oriented fault occurs approximately 1050' east of the BHS point (_+7200' MD on the wellplan). It appears to have approximately 160' of displacement. Due to relatively poor quality seismic data, this fault (like other faults in this area) is not sharply imaged. It could occur within a zone up to 800' wide, and may be made up of one or more fault strands. This fault presents a fluid loss hazard. · Numerous faults of varying orientations and displacements occur east of the above major north-south fault. These faults have a complex pattern and are not well imaged seismically. They occur in the northwest quadrant of Drillsite S, and many of these faults have been crossed en route to Sag River-lvishak targets. These faults potentially pose hazards for fluid loss, gas cut mud, borehole ledges, or tight formation. · Gas cut mud occurred in a relatively nearby well (S-03) at 5713' TVD. Mud weight was increased from 10.1 ppg to 10.3 ppg to handle the problem. S-100 experienced traces of oil at the top of the Ugnu. For this reason the 7" casing will be cemented to the 10 %" surface casing shoe. · A relatively high angle through the HRZ in this well will require a higher mud weight and attentive drilling practices to ensure wellbore stability. PRODUCTION SECTION: · A small north-south oriented fault occurs approximately 1000' beyond the BHS point (toward the EHS point). It appears to have approximately 20' of displacement. It is not well imaged due to the quality and resolution of the seismic data, It may present a moderate geosteering hazard. · The tip of a small north-south oriented fault occurs approximately 325' west of the horizontal section TD (EHS), and is approximately 400' northwest of the EHS point along the well trajectory. This fault could have 10' to 25' of displacement. The well should TD before crossing this fault. Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. S-101 Permit to Drill Page 5 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor has already been set for this well. 1. Weld an FMC landing ring for the FMC Big Bore Wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and / or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig 1. 2. 3. , 5. 6. 7. . 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. Estimated Spud Date: Operations: MIRU Nabors 9ES. Nipple up and function test 16" diverter system. PU 5" DP as required and stand back in derrick. MU 13-1/2" drilling assembly and drill surface hole to approximately 3898' MD / 3351' TVD. The actual surface hole TD will be +/-125' TVD below the SV1 sand. Run and cement the 10 3/, /4,45.5# surface casing back to surface. ND diverter system and NU casing / tubing head. NU BOPE and test to 3500 psi. MU 9 7/8" drilling assembly and RIH to float collar. Test the 10 %" casing to 2800 psi for 30 minutes. Drill out shoe joints and displace well to LSND drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform a LOT. Drill per directional plan to top of Kuparuk and TD intermediate section at 8614" MD (6765' TVD). POOH, lay down 5" DP. Run 7" 26#/ft intermediate casing to TD and cement to above the Ugnu formation t° the surface casing shoe, set on emergency slips. A TAM port collar will be run at _+2100' 'FVD for freeze protection if required. RIH w/6-1/8" drilling assembly on 4" DP. Test casing to 350'0 psi for 30 minutes. Drill out 7" shoe and change mud over to 10.3 ppg LSND. Drill 20' new hole and perform FIT to 2.0 ppg over the mud weight. Drill ahead to planned TD at approximately 11,362' MD / 6757' TVDbkb. POOH. MAD pass with Neu/Den/Res LWD as required. Spot liner running pill in open hole. Run 4 %" slotted production liner. Displace 4-1/2" liner and 7" casing to clean 10.3 ppg brine. Run 3-1/2", 9.3# 13-Cr completion string. See attached completion schematic for details. Set production packer and test tubing and annulus to 3500 psi. Install two-way check. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Pull two-way check and shear the RP valve in the top GLM. Freeze protect the well to ,,-2000' TVDss. Install BPV. Secure the well and rig down / move off 9ES. 8/6/2000 Phil G. Smith Shared Services Drilling 564-4897 smithpgl@BP.com (July 21-30 contact Allen Sherritt 564-5204) ECEIVED AUG 02 S-101 Permit to Drill Page 6 --wd: PBU S Pad Shallow Hydrocarbons] Subject: [Fwd: PBU S Pad Shallow Hydrocarbons] Date: Tue, 01 Aug 2000 15:51:55 -0800 From: Tom Maunder <tom_maunder@admin.s~ate.ak. us> To: Phil Smith <smithpgl@bp.com> Phil, Enclosed is Bob Crandall's note regarding shallow hydrocarbons around S pad at about 3500' tvd ss. Based on your directional plan, the equivalent measured depth of about 4200' md is significantly above the 5700' md proposed top of cement for your 7". As we discussed, you should make plans to bring the cement sufficiently high to cover these zones per our regulations. I appreciate what you have indicated that the 4200' md is only 300' below your surface casing shoe. The odds that you will get cement up into the annulus are high. Please have a look at your options for achieving isolation and get back to us with your plan. Thanks, look forward to hearing from you. Tom Maunder Subject: PBU S Pad Shallow Hydrocarbons Date: Tue, 01 Aug 2000 15:12:00 -0800 From: Robert Crandall <Bob_Crandall@admin.state.ak. us> Organization: DOA-^OGCC To: "Seamount, Dan" <dan_seamount@admin.state.ak. us>, "Maunder, Thomas" <tom_maunder@admin.state.ak. us>, "Davies, Steve" <steve_davies@admin.state.ak. us>, "Wondzell, Blair" <blair__wondzell@admin.state.ak. us> Tom: I've looked at one of the early wells off S-Pad for evidence of shallow hydrocarbons. I used the S-1 well drilled in the early eighties and located in the immediate vidnity of the S-101 proposed location. The first indication of significant hydrocarbons in the S-01 well is at 3,605 md (est -3505 SS). Stratigraphically this is in what we call the Sagavanirktok Fm. which is above the Ugnu Fm. (Schrader Bluff equiv.) The zone at (-3505) should be covered with cement. RPC Tom Maunder <tom maunder~admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 2 8/1/00 3:54 PM S-101i Ri.qsite Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE High formation pressures are present both in and sometimes above the Kuparuk reservoir zone. Expected formation pressure below the permafrost is 9.0 ppg EMW. Mud weights in excess of 10.4 ppg can be expected. The surface hole on S-100i was drilled with 9.6 pgg mud weight without problem. Hydrates have occasionally been encountered at S pad. No other shallow gas has been reported. S-100i did not encounter any shallow gas problems. Lost circulation is a high possibility across a large fault between 6500' and 7500' MD. BE prepared With LCM and adequate surface volume. S-100i did not encounter loss circulation while crossing the faults in the intermediate section. Pipe sticking tendency is possible if the HRZ shale gives problems. S-100i HRZ conditions where normal, back reaming at connections and good hole cleaning practices contributed to the good hole.conditions. The 7" intermediate casing went to bottom without any difficulty. The Schrader interval on S-100i contained hydrocarbons. Triple combo LWD tools were used to mad pass the interval. S-101 is planned to run RFT's in Cement will need to be the Schrader interval if hydrocarbons a.re present. brought minimum 500 feet above Schrader. ~/ S pad is not a designated H2S pad. ~,, ............... -~'~(a 0ii ~ Gas C0rts. CONSULT THE S PAD DATA SHEET AND THE WELL PLAN FoR'AD.DIe'er. INFORMATION Version 2.0 Aurora S-1001 Hazards and ContingencieS Page ! of 1 STATE OF ALASKA _ ~ ALASKA( _ AND GAS CONSERVATION COMI~'~ .~,ON PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill J lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 64.3' Prudhoe Bay Field / Aurora 3. Address 6. Property Designation Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028258 4. Location of well at surface ~7. Unit or Property Name 11. Type Bond (See 2O AAC 25.O25) 4421' NSL, 4498' WEL, SEC. 35, T12N, R12E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 3894' NSL, 4608' WEL, SEC. 34, T12N, R12E, UM S-101 Number 2S100302630-277 At total depth~ ~N 9. Approximate spud date 305' NSL, 469' WEL, SE , R12E, UM 08/05/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028259, 4810' MDI No Close Approach 2560 11362' MD / 6757' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 500' Maximum Hole Angle 100 ° Maximum surface 2765 psig, At total depth (TVD) 6700' / 3435 psig 18. Casing Program Specifications Setting Depth Size Top BOttOm Quantitv of Cement Hole Casino Weioht Grade Couplinq Lenqth MD TVD MD TVD (include staqe data) 30" 20" 91.5# H-40 WLD 80' Surface Surface 109' 109' _>60 sx Arctic Set (Approx.) 13-1/2" 10-3/4" 45.5# K-55 BTC 3870' Surface Surface 3898' 3351' 721 sx AS II1~ 242 Class 'G' 9-7/8" 7" 26# L-80 BTC-M 8586' Surface Surface 8614' 6765' ~ sx Class 'G'~ 184 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 Slotted 2897' 6465' 6657' 11362' 6757;/" Llncemented Slotted Liner / 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate Production Liner ORIGINAL JUL 2 6 2000 Perforation depth: measured ~aSk~, 0~'~ & G~$ CG~. true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] 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 Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Ston~ ~..._....~,.~, ~c:~:~:=~ Title Senior Drilling Engineer Date '1(~/~ Permit Number APl Number Approval.Date See cover letter c::'oO--- ,/,2"..~'" 50- (::~--~P- -2.. <~_ ~'¢ ,~' I,i~l(~O for other requirements Conditions of Approval: Samples Required I-! Yes J~ No Mud Lo~Rbqui~ed r'i Yes ~ No Hydrogen Sulfide Measures ~Yes ~ No Directional Survey Required ~ Yes [] No Required Working Pressure for BOPE I-I 2K; [] 3K; [] 4K; .~ 5K; [] 10K; [] 15K by order of Approved By ORIGINAL SIGNED BY Commissioner the commission Date Form 10-401 Rev. ~2-~Y~'r ueamount I In Triplicate TREE: 4-1/16 ' - 5M CIW Chrome WELLHEAD: 13 5/8" - 5M FMC SH S- 01 Proposed Completi°n" ' Cellar Elevation = 35.8' Nabors 9ES Floor = 64.3' 3-1/2" 'X' Landing Nipple with 2.813" seal bore. I 2100' I 10-3/4', 45.5 #/ft, K-55, BTC I 3-1/2" Camco Gas Lift Mandrels with handling pups installed. GAS LIFT MANDRELS MD Size Valve Type TBD TBD TBD TBD RP Shear DV DV DV 3-1/2" 9.2# 13Cr-80, Fox Tubing RECEIVED JUL 26 200O AJaska 0i, i & Gas CoDs. Commission A~chorage 3-1/2" 'X' Landing Nipple with 2.813" seal bore. 7" x 4-1/2' Baker 'S-3' Production Packer with crossover pups to 3-1/2" 3-1/2" 'XN' Landing Nipple with 2.813" seal bore and 2.75" No-Go ID. 3-1/2" WireLine Entry Guide spaced-out into 4-1/2" liner tie-back sleeve. 7", 26 #/ft, L80, BTC-Mod I8465' I BAKER 5" x 7" Liner Tie Back Sleeve 'HMC' Hydraulic Liner Hanger 4,1/2" 12.6 #/ft, L-80, IBT Slot'd I 11,362' I Date Rev By Comments 12/15/99 WSI Proposed Completion 7/18/00 PGS Revised Proposed Completion AURORA WELL: S-101 AP! NO: 50-029-????? BP Alaska Drilling & Wells ii~3~l'~r-lBI.r~ North Slope/('- ~ka Alaska State Plane 4 PB('" .WOAs.~0~SI DrillQuest' O m 1800 - 2700 - 3600 Dir O 1.000~110Off: 500.0Oft MD, 500.00ff TVD Rate O 2.000°/10Oft: 650.00ft MD, 649.98ft TVD in Dir Rate O 2.250°/100ff: 800.0Oft MD, 799.76ft TVD 1950.00ft TVD Dir: 2300.21ft MD, 2172.53ft TVD 10 3/4' Casing - 3898.34 MD, 3350.80 'I'VD 0.00 0.0000.910 0.00 0.00 N 0.00 E 0.00 500.000.0000.910 500.00 0.00 N 0.00 E 0.00 0.0~0 650.001.500261.0~0649.98 0.31 S I.~1 W 1.85 1.000 800.004.500261.000799.76 1.54S 9.69W 9.27 2.000 19~4.38 30.699 261.000I ~00.00 56.13 S 354.40 W339.002.250 2O22-53 ~0.699 261.0001950.00 ~0.T/S 383.72 W367.040.000 2300.2] 42-500 261.0002172.53 ~6.63 S 546.95 W52.3.10 4.250 73~9.84 42.54~ 261.0005925.00 624.53 S 394.3.12 W 3771.78 7985.22 48.000 261.0006~.4.00 690.65 S 4.~0-5g W 4171.11 0.924 8171.2.3 48.000 261.0~0646[.46 712~.7 S 4497.11 W 4~OI.70 0,000 ~618.58 48.000 261.0006767.8O 764 ~-8 S4825.47 W 4615.79 0.0~0 ~645.45 48.000 261.0006785.~0 767.41 S 4~45.21 W 46.34.65 0.000 S660.48 48.00O 261.0006795.S4 769.15 S 4856.22 W 4645.21 0.000 SS40.85 99.OO0 264.9396847.88 7g9.79 S 5030.~0 W 4gi 3.2.3 27.O00 8995.99 99.000 .304.910 6824.07 75.3.41 S5167.11 W 49.$4.02 27,000 9082.81 102.720 314.82268O7.67 698.87 S $2.32.49 W 5027.97 12.000 9183.27 102.720 314.8226785.56 629.795 5301.99 W 5108.54 0.000 9321.39 90.365 325.9666769.80 52434 S 53S9.03 W 5212.78 12-000 11362.38 c~0..3&5 325.9666756.80 1167.01 N6531.3.3 W 6634.77 0.000 B Perm - 1940.80 TVD SV3 - 2814.80 TVD UG4A - 3563.80 TVD 45OO 54OO ....................................................... UG1 - 4721.80 TVD ................................................. WS2 - 4953.80 TVD WS1 . 509Z80 TVD B West Sak - 5425.80 TVD 0 o II '~ 6300 in Dir @ 0.924°/100ft: 7389.84ft MD, 5925.00ft TVD Dir: 7985.22ft MD, 6344.00ft TVD 7" Casing - 8613.64 MD, 6764.49 TVD ! Ill!Il!Il! 1 ! !Il! I ! !ll!t I Il!! ! I !lll!! !llll l!! III l! !Il! I I Ill llllll! !l ll!l ! I !ll!! !Ill! ! I !!ll! !!!ll! ! i Il l! !]llll ! ! !l!! l! Ill!! ! !ll! ! ! i I I I I l 0 900 1800 2700 3600 4500 Scale: linch - 900ft Vertical Section Section Azimuth: 280.131° (True North) Dir @ 27.000°/100ff: 8660.48ff OTVD 9 B_3 -~_O .uu ...... B5 5 I ~ 0 z N~e~' ~'~' l'z~~A ~ .... .4 1/2" Liner- 11362.38 MD, 6756.80 ~D ~ ........... /....z.~..~..~ .......... ~ .................... ~ ........ ~,~.~ c,~ . ~.~ ~ [::: ~:::: ::::: ' '~34 ~ ~ ........................................................... ~-~ ~ 7 ~ & ~ o/. 7000 t ........................................................................................................... ~ ..... ,- 10¢2.~o~ I 5000 Scale: I inch = 500ft 5500 6000 Vertical Section 650O Section Azimuth: 280.131° (True North) North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad I DrillQuesf S-101 Scale: linch = 800ft Eastings -6400 -5600 -4800 -4000 -3200 I I I I I -2400 -1600 -800 0 I I I I 11362.38ffMD, 6756.80ffTVD 11362.38 MD, 6756.80TVD $-101 T2 . 6756.80 TVD 167.01 N, 6531.33 W S-lO1 Geo polygon S. IOI 524.34 S, 5389.03 W I Dir: 9321.39ft MD, 6769.80ft TVD Dir @ 12.000°/100ft: 9183.27ft MD, 6785.56ft TVD End Dir. 9082.81ft MD, 6807.67ft TVD Decrease in Dir Rate @ 12.000°/100ft: 8995.99ft MD, 6824.07ft TVD 8613.64MD, 6764.49TVD Begin Dir @ 0.924°/100ft: 7389.84ft MD, 5925.00ft 'rVD End Dir: 7985.22ft MD, 6344.00ff TVD Begin Dir @ 27.000°/100ft: 8660.48ft MD, 6795.83ft TVD I -6400 Scale: I inch = 800ft I -5600 I I I I -4800 -4000 -3200 -2400 Eastings Begin Dir @ 1.000°/10Oft: 500.0Oft MD, 500.00fi TVD Increase in DirRate @ 2.000°/100ft: 650.0Oft MD, 649.98ft TVD Increase in Dtr Rate @ 2.250°/100ft: 800.00ft MD, 799.76ft TVD End Dir: 1964.38ft MD, 1900.00ft TVD Begin Dir @ 4.250°/100ft: 2022.53ft MD, 1950.00ft TVD End Dir: 2300.21ff MD, 2172.53ft TVD 10~4" Casing- 3898.34MD, 3350.80T VD I I I -1600 -800 0 160~ 8O0 · Reference is True North RECE VED JUL 26 2000 Alaska 0~ & Gas Cons. Commission Sper~/-Sun Drilling Sef /ices Proposal Data - S-101 - S-101 Wp06 RECEIVED JUL 2 6 Alask~ 0¢ & 6~s Co~s, Co~'~mission .Anchorage 21 July, 2000 - 12:27 - I - DrillQuest RECEIVED JUL 26 2OOO A~aska 0[4 & Gas ~' Allch0rage Sperry-Sun Drilling Services Proposal Report for S-101 Wp06 Revised: 18 July, 2000 North Slope Alaska Measured Depth Incl. Azim. (ft) 0.00 0.000 0.000 100.00 0.000 0.000 200.00 0.000 0.000 300.00 0.000 0.000 400.00 0.000 0.000 500.00 0.000 0.000 600.00 1.000 261.000 650.00 1.500 261.000 700.00 2.500 261.000 800.00 4.500 261.000 Sub-Sea Depth -65.80 34.20 134.20 234.20 334.20 434.20 534.19 584.18 Vertical Depth 0.00 100.00 200.00 300.00 400.00 500.00 599.99 649.98 Local Coordinates Northings Eastings (it) (It) 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.14 S 0.86 W 0.31 S 1.94 W 634.15 699.95 0.58 S 3.66W 733.96 799.76 1.54 S 9.69W 900.00 6.750 261.000 833.47 899.27 1000.00 9.000 261.000 932.52 998.32 1100.00 11.250 261.000 1030.96 1096.76 1200.00 13.500 261.000 1128.63 1194.43 1300.00 15.750 261.000 1225.38 1291.18 1400.00 18.000 261.000 1321.07 1386.87 1500.00 20.250 261.000 1415.55 1481.35 1600.00 22.500 261.000 1508.66 1574.46 1700.00 24.750 261.000 1600.27 1666.07 1800.00 27.000 261.000 1690.24 1756.04 1900.00 29.250 261.000 1778.43 1844.23 1964.38 30.699 261.000 1834.20 1900.00 2000.00 30.699 261.000 1864.83 1930.63 2011.83 30.699 261.000 1875.00 1940.80 2022.53 30.699 261.000 1884.20 1950.00 3.07 S 19.37W 5.21S 32.90W 7.96 S 50.27W 11.31 S 71.43W 15.26 S 96.37W 19.80 S 125.04W 24.93 S 157.40W 30.63 S 193.39W 36.90 S 232.97W 43.73 S 276.07W 51.10 S 322.63W 56.13 S 354.40W 58.98 S 372.36W 59.92 S 378.32W 60.77 S 383.72W Global Coordinates Northings Eastings (it) (it) 5980624.83 N 618930.03E 5980624.83 N 618930.03 E 5980624.83 N 618930.03 E 5980624.83 N 618930.03 E 5980624.83 N 618930.03 E 5980624.83 N 618930.03 E 5980624.68 N 618929.17 E 5980624.49 N 618928.10 E Dogleg Rate (°/lOOit) o.ooo 0.000 0.000 0.000 0.000 1.000 1.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.82 1.85 5980624.19 N 618926,38 E 2.000 3.50 5980623.14 N 618920,36 E 2.000 9.27 5980621.45 N 618910.71E 2.250 18.53 5980619.10 N 618897,21E 2.250 31.47 5980616.07N 618879.90 E 2.250 48.08 5980612.38 N 618858.79 E 2.250 68.33 5980608.04 N 618833.92E 2.250 92.18 5980603.04 N 618805.32 E 2.250 119.60 5980597.41N 618773.05 E 2.250 150.56 5980591.13 N 618737.15 E 2.250 184.99 5980584.24 N 618697.67 E 2.250 222.85 5980576.73 N 618654.69 E 2.250 264.08 5980568.62 N 618608.25 E 2.250 308.61 5980563.08 N 618576.57 E 2.250 339.00 5980559.95 N 618558.66 E 0.000 356.18 5980558.91N 618552.71 E 0.000 361.88 5980557.97 N 618547.33 E 0.000 367.04 Comment BeQin Dir @ 1.000°/100ft: 500'.00ft MD, 500.00ft TVD Increase in Dir Rate @ 2.000°/100ft: 650.00ft MD, 649.98ft TVD Increase in Dir Rate @ 2.250°/100ft: 800.00ft MD, 799.76ft TVD End Oir: 1964.38ft MD, 1900.00ft TVD B Perm Be~in Dir@ 4.250°/100ft: 2022.53ft MD, 1950.00ft TVD Continued... 21 July, 2000 - 12:26 - 1 - DrillQuest 1.05.05a RECEIVED JUL 26 2000 A~aska 0i~ & Ges Co,~s. Commission Anchorage North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (~) (~) 2100.00 33.991 261.000 1949.64 2200,00 38.241 261,000 2030.40 2300.00 42.491 261.000 2106.58 2300,21 42.500 261.000 2106,73 2400.00 42,500 261.000 2180,31 2500.00 42.500 261.000 2254,03 2600,00 42.500 261,000 2327.76 2700.00 42.500 261,000 2401.49 2800.00 42.500 261.000 2475.22 2900.00 42,500 261.000 2548.94 3000.00 42.500 261.000 2622.67 3100.00 42.500 261.000 2696,40 3171.34 42.500 261.000 2749.00 3200,00 42.500 261,000 2770.13 3300.00 42.500 261,000 2843.86 3400,00 42.500 261.000 2917.58 3500,00 42.500 261.000 2991.31 3600.00 42.500 261,000 3065.04 3700.00 42,500 261.000 3138,77 3800.00 42,500 261.000 3212.49 3898.34 42.500 261.000 3285.00 3900.00 42.500 261.000 3286.22 4000.00 42.500 261.000 3359.95 4100,00 42.500 261.000 3433.68 4187.24 42.500 261.000 3498.00 Sperry-Sun Drilling Services Proposal Report for S-101 Wp06 Revised: 18 July, 2000 Ve~ical Local Coordinates Global Coordinates Depth Nothings Eastings Nothings Eastings (~) (~) (~) (~) (~) 2015.44 67,26 S 424.65W 5980550.84 N 618506.50 E 2096.20 76.48 S 482.85W 5980540.70 N 618448.45 E 2172.38 86.61S 546.81W 5980529,55 N 618384.67 E 2172.53 86.63 S 546.95W 5980529,53 N 618384.53 E 2246,11 97,17 S 613.53W 5980517.93 N 618318.12 E 2319.83 107.74 S 680.26W 5980506.30 N 618251.57 E 2393.56 118.31S 746.99W 5980494.67 N 618185.01E 2467.29 128.88 S 813.72W 5980483.05 N 618118.46E 2541.02 139.45 S 880.44W 5980471,42 N 618051,91 E 2614.74 150.02 S 947,17W 5980459.79 N 617985.36 E 2688.47 160.59 S 1013.90W 5980448.17 N 617918.81 E 2762.20 171,15 S 1080.62W 5980436.54 N 617852.26 E 2814.80 178.69 S 1128.23W 5980428,25 N 617804.78 E 2835.93 181.72 S 1147.35W 5980424.92 N 617785.71E 2909.66 192.29 S 1214.08W 5980413.29 N 617719.16 E 2983.38 202.86 S 1280,81W 5980401,66 N 617652,61E 3057.11 213.43 S 1347.53W 5980390.04 N 617586.05 E 3130.84 224.00 S 1414.26W 5980378.41 N 617519.50 E 3204.57 234.57 S 1480,99W 5980366,78 N 617452,95 E 3278,29 245.13 S 1547.72W 5980355.16 N 617386.40 E 3350.80 255,53 S 1613.34W 5980343,72 N 617320,95 E 3352.02 255.70 S 1614.44W 5980343.53 N 617319.85 E 3425.75 266.27 S 1681.17W 5980331.90 N 617253.30 E 3499.48 276.84 S 1747.90W 5980320.28 N 617186.75 E 3563.80 286.06 S 1806,11W 5980310.13 N 617128,69 E Dogleg Rate (°/lOOft) 4.250 4,250 4,250 4,250 0.000 0.000 0.000 0.000 0.000 0.000 0,000 0.000 0.000 0,000 0.000 0.000 0.000 0.000 0,000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 PBU_WOA S Pad Ve~ical Section (~) 406.20 461.87 523.05 523.18 586.87 650.70 714.53 778.36 842.19 906.01 969.84 1033.67 1079.21 1097.50 1161.33 1225.15 1288.98 1352.81 1416.64 1480.46 1543.23 1544.29 1608.12 1671.95 1727.63 Comment End Dir: 2300.21ft MD, 2172.53ft TVD SV3 10 3/4" Casing UG4A Continued... 21 July, 2000 - 12:26 - 2 - DrillQuest 1.05.05a RECEIVED JUL 26 2000 Anchorage Sperry-Sun Drilling Services Proposal Report for S-101 Wp06 Revised: 18 July, 2000 North Slope Alaska Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth (~) (~) (~) 4200.00 42.500 261.000 3507.41 3573.21 4300.00 42.500 261.000 3581.13 3646.93 4400.00 42.500 261.000 3654.86 3720.66 4500.00 42.500 261.000 3728.59 3794.39 4600.00 42.500 261.000 3802.32 3868.12 4700.00 42.500 261.000 3876.04 3941.84 4800.00 42.500 261.000 3949.77 4015.57 4900.00 42.500 261.000 4023.50 4089.30 5000.00 42.500 261.000 4097.23 4163.03 5100.00 42.500 261.000 4170.95 4236.75 5200.00 42.500 261.000 4244.68 4310.48 5300.00 42.500 261.000 4318.41 4384.21 5400.00 42.500 261.000 4392.14 4457.94 5500.00 42.500 261.000 4465.87 4531.67 5600.00 42.500 261.000 4539.59 4605.39 5700.00 42.500 261.000 4613.32 4679.12 5757.89 42.500 261.000 4656.00 4721.80 5800.00 42.500 261.000 4687.05 4752.85 5900.00 42.500 261.000 4760.78 4826.58 6000.00 42.500 261.000 4834.50 4900.30 6072.56 42.500 261.000 4888.00 4953.80 6100.00 42.500 261.000 4908.23 4974.03 6200.00 42.500 261.000 4981.96 5047.76 6267.87 42.500 261.000 5032.00 5097.80 6300.00 42.500 261.000 5055.69 5121.49 Local Coordinates Global Coordinates Nothings Eastings Nothings Eastings (~) 287.41 S 1814.62W 5980308.65 N 617120.20 E 297.98 $ 1881.35W 5980297.02 N 617053.65 E 308.55 S 1948.08W 5980285.40 N 616987.09 E 319.11S 2014.81W 5980273.77 N 616920.54 E 329.68 S 2081.53W 5980262.14 N 616853.99 E 340.25 S 2148.26W 5980250.52 N 616787.44 E 350.82 S 2214.99W 5980238.89 N 616720.89 E 361.39 S 2281.72W 5980227.26 N 616654.34 E 371.96 S 2348.44W 5980215.64 N 616587.79 E 382.53 S 2415.17W 5980204.01 N 616521.24 E 393.09 S 2481.90W 5980192.38 N 616454.69 E 403.66 S 2548.62W 5980180.76 N 616388.14 E 414.23 S 2615.35W 5980169.13 N 616321.58 E 424.80 S 2682.08W 5980157.50 N 616255.03 E 435.37 S 2748.81W 5980145.88 N 616188.48 E 445.94 S 2815.53W 5980134.25 N 616121.93 E 452.05 S 2854.16W 5980127.52 N 616083.41E 456.51 $ 2882.26W 5980122.62 N 616055.38 E 467.07 S 2948.99W 5980111.00 N 615988.83 E 477.64 S 3015.72W 5980099.37 N 615922.28 E 485.31S 3064.13W 5980090.94 N 615873.99 E 488.21 S 3082.44W 5980087.74 N 615855.73 E 498.78 S 3149.17W 5980076.12 N 615789.18 E 505.95 $ 3194.46W 5980068.23 N 615744.01 E 509.35 S 3215.90W 5980064.49 N 615722.62 E Dogleg Rate (~lOOff) o.0oo o.ooo o.ooo 0.0oo o.ooo o.ooo o.o0o o.0o0 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 PBU_WOA S Pad Ve~ical Section (fi) 1735.78 1799.60 1863.43 1927.26 1991.09 2054.92 2118.74 2182.57 2246.40 2310.23 2374.05 2437.88 2501.71 2565.54 2629.37 2693.19 2730.14 2757.02 2820.85 2884.68 2930.99 2948.51 3012.33 3055.65 3076.16 Comment UG1 WS2 WSl Continued... 21 July, 2000 - 12:26 - 3 - DrillQuest 1.05.05a R .CEIVED Sperry-Sun Drilling Services Proposal Report for S-101 Wp06 Revised: 18 July, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (~) (~) 6400.00 42.500 261.000 5129.42 6500.00 42.500 261.000 5203.14 6600.00 42.500 261.000 5276.87 6700.00 42.500 261.000 5350.60 6712.75 42.500 261.000 5360.00 6800.00 42.500 261.000 5424.33 6900.00 42.500 261.000 5498.05 7000.00 42.500 261.000 5571.78 7100.00 42.500 261.000 5645.51 7200.00 42.500 261.000 5719.24 7300.00 42.500 261.000 5792.96 7389.84 42.500 261.000 5859.20 7400.00 42.594 261.000 5866.69 7500.00 43.518 261.000 5939.76 7600.00 44.441 261.000 6011.71 7700.00 45.365 261.000 6082.54 7800.00 46.289 261.000 6152.22 7900.00 47.213 261.000 6220.74 7985.22 48.000 261.000 6278.20 8000.00 48.000 261.000 6288.09 8100.00 48.000 261.000 6355.00 8171.23 48.000 261.000 6402.66 8200.00 48.000 261.000 6421.91 8300.00 48.000 261.000 6488.83 8400.00 48.000 261.000 6555.74 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 5195.22 519.92 S 3282.62 W 5980052.86 N 615656.07 E 5268.94 530.49 S 3349.35 W 5980041.24 N 615589.52 E 5342.67 541.05 S 3416.08 W 5980029.61 N 615522.97 E 5416.40 551.62 S 3482.81 W 5980017.99 N 615456.42 E 5425.80 552.97 S 3491.31 W 5980016.50 N 615447.93 E 5490.13 562.19 S 3549.53 W 5980006.36 N 615389.87 E 5563.85 572.76 S 3616.26 W 5979994.73 N 615323.32 E 5637.58 583.33 S 3682.99 W 5979983.11 N 615256.77 E 5711.31 593.90 S 3749.71 W 5979971.48 N 615190.22 E 5785.04 604.47 S 3816.44 W 5979959.85 N 615123.67 E 5858.76 615.03 S 3883.17 W 5979948.23 N 615057.11 E 5925.00 624.53 S 3943.12 W 5979937.78 N 614997.33 E 5932.49 625.60 S 3949.90 W 5979936.60 N 614990.56 E 6005.56 636.28 S 4017.33 W 5979924.85 N 614923.31 E 6077.51 647.15 S 4085.92 W 5979912.90 N 614854.90 E 6148.34 658.19 S 4155.64 W 5979900.75 N 614785.36 E 6218.02 669.41 S 4226.48 W 5979888.41 N 614714.71 E 6286.54 680.80 S 4298.42 W 5979875.87 N 614642.96 E 6344.00 690.65 S 4360.58 W 5979865.04 N 614580.96 E 6353.89 692.37 S 4371.43 W 5979863.15 N 614570.14 E 6420.80 703.99 S 4444.83 W 5979850.36 N 614496.94 E 6468.46 712.27 S 4497.11 W 5979841.25 N 614444.80 E 6487.71 715.62 S 4518.23 W 5979837.57 N 614423.73 E 6554.63 727.24 S 4591.63 W 5979824.78 N 614350.53 E 6621.54 738.87 S 4665.03 W 5979811.99 N 614277.32 E Dogleg Rate (°/100~) o.000 0.oo0 0.0o0 0.o00 o.o00 o.o00 0.000 0.000 0.00o 0.000 0.000 0.000 0.924 0.924 0.924 0.924 0.924 0.924 0.924 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 PBU_WOA S Pad Vertical Section (~) 3139.99 3203.82 3267.64 3331.47 3339.61 3395.30 3459.13 3522.96 3586.78 3650.61 3714.44 3771.78 3778.27 3842.77 3908.38 3975.07 4042.83 4111.65 4171.11 4181.48 4251.69 4301.70 4321.90 4392.11 4462.33 Comment B West Sak Be~in Dir@ 0.924°/100ft: 7389.84ft MD, 5925.00ft TVD End Dir: 7985.22ft MD, 6344.00ft TVD Continued... 21 July, 2000 - 12:26 - 4 - DrillQuest 1.05.05a North Slope Alaska Sperry-Sun Drilling Services Proposal Report for S-101 Wp06 Revised: 18 July, 2000 Measured Sub-Sea Ve~ical Local Coordinates Depth Incl. Azim. Depth Depth Nothings Eastings (~) (~) (~) (~) (~) 8430.28 48.000 261.000 6576.00 6641.80 742.39 $ 4687.25W 8500.00 48.000 261.000 6622.65 6688.45 750.49 S 4738.43W 8594.67 48.000 261.000 6686.00 6751.80 761.50 S 4807.92W 8600.00 48.000 261.000 6689.57 6755.37 762.12 S 4811.83W 8603.64 48.000 261.000 6692.00 6757.80 762.54 S 4814.50W 8613.64 48.000 261.000 6698.69 6764.49 763.70 S 4821.84W 8617.09 48.000 261.000 6701.00 6766.80 764.11S 4824.37W 8618.58 48.000 261,000 6702.00 6767.80 764.28 S 4825.47W 8638.01 48.000 261.000 6715.00 6780.80 766.54 S 4839.73W 8645.48 48.000 261.000 6720.00 6785.80 767.41 S 4845.21W 8660.48 48.000 261.000 6730.04 6795.84 769.15 S 4856.22W 8700.00 58.634 262.083 6753.61 6819.41 773.78 S 4887.52W 8706.69 60.435 262.240 6757.00 6822.80 774.57 S 4893.24W 8800.00 85.570 264.062 6784.06 6849.86 785.03 S 4981.13W 8849.85 99.000 264.939 6782.08 6847.88 789.79 $ 5030.60W 8900.00 99.510 278.651 6773.98 6839.78 788.25 S 5079.95W 8995.99 99.000 304.910 6758.27 6824.07 753.41 S 5167.11W 9000.00 99.179 305.363 6757.64 9082.81 102.720 314.822 6741.87 9100.00 102.720 314.822 6738.09 9183.27 102.720 314.822 6719.76 9200.00 101.239 316.209 6716.28 9300.00 92.291 324.269 6704.50 9321.39 90.365 325.966 6704.00 9400.00 90.365 325.966 6703.50 Global Coordinates Northings Eastings (ft) (ft) 5979808.12 N 614255.15 E 5979799.21 N 614204.11 E 5979787.10 N 614134.81 E 5979786.42 N 614130.91 E 5979785.95 N 614128.24 E 5979784.67 N 614120.92 E 5979784.23 N 614118.40 E 5979784.04 N 614117.30 E 5979781.56 N 614103.08 E 5979780.60 N 614097.61 E 5979778.68 N 614086.63 E 5979773.55 N 614055.41 E 5979772.67 N 614049.71 E 5979760.82 N 613961.99 E 5979755.27 N 613912.61 E 5979756.03 N 613863.24 E 5979789.48 N 613775.54 E 6823.44 751.13 S 5170.35W 5979791.71N 613772.26 E 6807.67 698.87 S 5232.49W 5979842.98 N 613709.30 E 6803.89 687.05 S 5244.38W 5979854.61 N 613697.22 E 6785.56 629.79 S 5301.99W 5979910.94 N 613638.71 E 6782.08 618.12 S 5313.46W 5979922.44 N 613627.05 E 6770.30 541.88 S 5376.81W 5979997.66 N 613562.51 E 6769.80 524.34 S 5389.03W 5980015.00 N 613550.00 E 6769.30 459.20 S 5433.03W 5980079.44 N 613504.98 E Dogleg Rate (°~00~) 0.000 o.o00 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 27.000 27.000 27.000 27.000 27.000 27.000 12.000 12.000 0.000 0.000 12.000 12.000 12.000 0.000 Alaska State Plane 4 PBU_WOA S Pad Ve~ical Section (~) 4483.58 4532.54 4599.00 4602.75 4605.30 4612.32 4614.74 4615.79 4629.43 4634.68 4645.21 4675.21 4680.70 4765.38 4813.23 4862.09 4954.02 4957.61 5027.97 5041.76 5108.54 5121.89 5197.65 5212.78 5267.55 Comment THRZ BHRZ Kup C4B 7" Casing Kup C4A Kup C3B Beain Dir @ 27.000°/100ft: 8660.48ft MD, 6795.83ft TVD Kup C3A Decrease in Dir Rate @ -~ 12.000°/100ft: 8995.99ft MD. 6824.07ft TVD End Dir: 9082.81ft MD, 6807.67ft TVD Beain Dir@ 12.000°/100ft: 918'3.27ft MD, 6785.56ft TVD End Dir: 9321.39ft MD 6769.80ft TVD ' Target - S-101 T1, Geological Continued... 21 July, 2000 - 12:26 - 5- DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S-101 Wp06 Revised: 18 July, 2000 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (~) (~) (~) 9500.00 90.365 325.966 6702.86 6768.66 9600.00 90.365 325.966 6702.23 6768.03 9700.00 90.365 325.966 6701.59 6767.39 9800.00 90.365 325.966 6700.95 6766.75 9900.00 90.365 325.966 6700.31 6766.11 10000.00 90.365 325.966 6699.68 6765.48 10100.00 90.365 325.966 6699.04 6764.84 10200.00 90.365 325.966 6698.40 6764.20 10300.00 90.365 325.966 6697.77 6763.57 10400.00 90.365 325.966 6697.13 6762.93 10500.00 90.365 325.966 6696.49 6762.29 10600.00 90.365 325.966 6695.86 6761.66 10700.00 90.365 325.966 6695.22 6761.02 10800.00 90.365 325.966 6694.58 6760.38 10900.00 90.365 325.966 6693.95 6759.75 11000.00 90.365 325.966 6693.31 6759.11 11100.00 90.365 325.966 6692.67 6758.47 11200.00 90.365 325.966 6692.03 6757.83 11300.00 90.365 325.966 6691.40 6757.20 11362.38 90.365 325.966 6691.00 6756.80 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (~) (~) (~) (~) 376.33 S 5489.00W 5980161.41N 613447.70 E 293.46 S 5544.96W 5980243.38 N 613390.42 E 210.59 S 5600.93W 5980325.35 N 613333.15 E 127.72 S 5656.90W 5980407.32 N 613275.87 E 44.85 S 5712.87W 5980489.29 N 613218.60 E 38.02 N 5768.83W 5980571.26 N 613161.32 E 120.88 N 5824.80W 5980653.23 N 613104.04E 203.75 N 5880.77W 5980735.20 N 613046.77E 286.62 N 5936.74W 5980817.17 N 612989.49 E 369.49 N 5992.70W 5980899.14 N 612932.22 E 452.36 N 6048.67W 5980981.11N 612874.94 E 535.23 N 6104.64W 5981063.08 N 612817.66 E 618.10 N 6160.61W 5981145.04 N 612760.39 E 700.97 N 6216.57W 5981227.01 N 612703.11 E 783.83 N 6272.54W 5981308.98 N 612645.84 E Alaska State Plane 4 PBU_WOA S Pad 866.70 N 6328.51W 5981390.95 N 612588.56 E 949.57 N 6384.48W 5981472.92 N 612531.28 E 1032.44 N 6440.44W 5981554.89 N 612474.01 E 1115.31N 6496.41W 5981636.86 N 612416.73 E 1167.01N 6531.33W 5981688.00 N 612381.00E Dogleg Rate (°~00~) 0.000 o.000 o.o00 0.000 0.000 o.000 0.000 0.000 0.00o o.000 0.000 0.000 0.000 0.000 0.000 0.000 0.00o o.000 0.000 0.000 Vertical Section (ft) 5337.22 5406.89 5476.56 5546.23 5615.90 5685.57 5755.25 5824.92 5894.59 5964.26 6033.93 6103.60 6173.27 6242.95 6312.62 6382.29 6451.96 6521.63 6591.30 6634.77 Comment Total Depth: 11362.38ft MD, 6756.80ft TVD 4 1/2" Liner Target- S-101 T2, Geological JUL 2 £UuU 0;~ & 6ss Cons. Commission Ari~omgo Continued... 21 July, 2000 - 12:26 - 6 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S-101 Wp06 Revised: 18 July, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to S-101. Northings and Eastings are relative to S-101. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from S-101 and calculated along an Azimuth of 280.131° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11362.38ft., The Bottom Hole Displacement is 6634.77ft., in the Direction of 280.131 o (True). Comments Measured Depth (ft) 500.00 650.00 800.00 1964.38 2022.53 2300.21 7389.84 7985.22 8603.64 8617.09 8638.01 8660.48 8706.69 8995.99 9082.81 Station Coordinates TVD Nothings Eastings (~) (~) (~) 500.00 0.00 N 0.00 E 649.98 0.31S 1.94W 799.76 1.54 S 9.69W 1900.00 56.13 S 354.40W 1950.00 60.77 $ 383.72W 2172.53 5925.00 6344.00 6757.80 6766.80 86.63 S 546.95W 624.53 S 3943.12W 690.65 S 4360.58W 762.54 S 4814.50W 764.11S 4824.37W 6780.80 6795.83 6822.80 6824.07 6807.67 766.54 S 4839.73W 769.15 S 4856.22W 774.57 S 4893.24W 753.41S 5167.11W 698.87 S 5232.49W Comment Begin Dir @ 1.000°/100ft: 500.00ft MD, 500.00ft TVD Increase in Dir Rate @ 2.000°/100ft: 650.00ft MD, 649.98ft TVD Increase in Dir Rate @ 2.250°/100ft: 800.00ft MD, 799.76ft TVD End Dir: 1964.38ft MD, 1900.00ft TVD Begin Dir @ 4.250°/100ft: 2022.53ft MD, 1950.00ft TVD End Dir: 2300.21ft MD, 2172.53ft TVD Begin Dir @ 0.924°/100ft: 7389.84ft MD, 5925.00ft TVD End Dir: 7985.22ft MD, 6344.00ft TVD Kup C4B Kup C4A Kup C3B Begin Dir @ 27.000°/100ft: 8660.48ft MD, 6795.83ft TVD Kup C3A Decrease in Dir Rate @ 12.000°/100ft: 8995.99ft MD, 6824.07ft TVD End Dir: g082.81ft MD, 6807.67ft TVD RECEIVED Continued... 21 July, 2000 - 12:26 - 7- DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S-101 Wp06 Revised: 18 July, 2000 North Slope Alaska Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comments (Continued) 9183.27 6785.56 9321.39 6769.80 11362.38 6756.80 629.79 s 524.34 s 1167.01N 5301.99W 5389.03W 6531.33W Comment Begin Dir @ 12.000°/100ft· 9183.27ft MD, 6785.56ft TVD End Dir: 9321.39ft MD, 6769.80ft TVD Total Depth · 11362.38ft MD, 6756.80ft TVD Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northings Eastings Formation Name (ft) (ft) (ft) (ft) (ft) 2011.83 1940.80 1875.00 59.92 $ 378.32 W B Perm 3171.34 2814.80 2749.00 178.69 S 1128.23 W SV3 4187.24 3563.80 3498.00 286.06 S 1806.11 W UG4A 5757.89 4721.80 4656.00 452.05 S 2854.16 W UG1 6072.56 4953.80 4888.00 485.31 S 3064.13 W WS2 6267.87 5097.80 5032.00 505.95 S 3194.46 W WS1 6712.75 5425.80 5360.00 552.97 S 3491.31 W B West Sak 8430.28 6641.80 6576.00 742.39 S 4687.25 W THRZ 8594.67 6751.80 6686.00 761.50 S 4807.92 W BHRZ Alaska State Plane 4 PBU_WOA S Pad RECEIVED Continued... 21 July, 2000 - 12:26 - 8 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for S-101 Wp06 Revised: 18 July, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA S Pad Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Surface> <Surface> <Surface> <Surface> To Measured Vertical Depth Depth (ft) (ft) Casing Detail 3898.34 3350.80 10 3/4" Casing 8613.64 6764.49 7" Casing 11362.38 6756.80 4 1/2" Liner Targets associated with this wellpath Target Name S-101 Geo Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Boundary Point #1 #2 #3 #4 Mean Sea Level/Global Coordinates #1 #2 #3 #4 RECEIVED jUL 26 2000 Alaska O;i & Gas ConG. Cof~mission Arlchom§e Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 65.80 0.00 1579.38 N 6614.79 W 5982099.00 N 612291.00 E 70° 21' 36.0920" N 149° 05' 16.3453" W 65.80 1579.38 N 6614.79 W 65.80 1214.24 N 6734.60 W 65.80 1049.16 $ 5278.35 W 65.80 654.84 $ 4792.03 W 0.00 5982099.00 N 612291.00 E 0.00 5981732.00N 612177.00 E 0.00 5979492.00N 613669.00 E 0.00 5979894.00N 614149.00 E Target Target Shape Type Polygon Geological Continued... 21 July, 2000 - 12:26 - 9 - DrillQuest 1,05.05a Sperry-Sun Drilling Services Proposal Report for S-101 Wp06 Revised: 18 July, 2000 North Slope Alaska Target Name Targets associated with this wellpath (Continued) S-lOl T1 S-101 T2 Geographical Coordinates #1 #2 #3 #4 Mean Sea Level/Global Coordinates: Geographical Coordinates: Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 6769.80 6704.00 6756.8O 6691.00 70° 21' 36.0920" N 149° 05' 16.3453" W 70° 21' 32.4995" N 149° 05' 19.8392" W 70° 21' 10.2488" N 149° 04' 37.2124" W 70° 21' 14.1305" N 149° 04' 23.0043" W 524.34 S 5389.03 W 5980015.00 N 613550.00 E 70° 21' 15.4100" N 149° 04' 40.4588" W 1167.01 N 6531.33 W 5981688.00 N 612381.00 E 70° 21' 32.0367" N 149° 05' 13.8943" W Alaska State Plane 4 PBU_WOA S Pad Target Target Shape Type Point Geological Point Geological RECEIVED JUL 2 6 LtJ,u~ AJaska O;i & 6as C-'or~s. Anchorage 21 July, 2000 - 12:26 - 10 - DrillQuest 1.05,05a l DATE / CHECK NO. H 1 70954 I°6/~'~'°° ] 1001701754 VENOOR AL~ ~SKAST:[ 4 OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET ,&~900 CKO&2c~OOD 100. O0 100. O0 HANOLING~ INST: PH TERRI HUBBLE :~iRST':~I~,TI~:.BAN I~::~F ASkEAND ';';:'::'::: ":': :']: ~'i~iUATE b~ :: iii:.:"::i :':" .' !.:¥::":::. NAYi~N.~:'~TY:~.ANK '.":: :.?':.~: C.E~ND, QHIO :~"'::.~ ::~;:: :"::;;.;::s~9.'::':" ::::: 412 'AY WELL PERMIT CHECKLIST COMPANY _~/c~ WELL NAME,~ ~'-/~PROGRAM: exp dev X" reddl serv ~ wellbore sag ann. disposal para req ~ FIELD & POOL , TCL SS /-,--7" ADMINISTRATION ENGINEERING 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and.number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed .... ......... If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to '~L.~ Dsig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. GEOLOGY 30. 31. 32. 34. GEOL AREA ~?~'J UNIT# , ,/,/~',5"o ON/OFF SHORE ~N - N N N Permit can .be issued wlo hydrogen sulfide measures ..... Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones .......... '. ~.. Seabed condition survey (if.off-shore) ............. · Contact name/phone for weekly progress reports [exploratory o~Y~' Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... y N ~kPPR DATE (B) will not contaminate freshwater; or cause drilling waste .... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N N N GEOLOGY: ENGINEERING: UICIAnnular .11 H ,~ ~,~t;~ % TEE4~~/a. -0c.5 COMMISSION: Comments/Instructions: I§ c:~nsoffice\wordian\diana\checklist (rev. 02117100) .. Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file. under APPENDIX, No special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Dec 28 13:23:36 2000 Reel Header Service name ............. LISTPE Date ..................... 00/12/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/12/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: S-101 PB1 500292296870 BP Exploration (Alaska), Inc. Sperry Sun 28-DEC-00 MWD RUN 1 MWD RUN 2 MWD RUN 3 AK-MM-00132 AK-MM-00132 AK-MM-00132 M. HANIK R. KRELL R. KRELL S. LEWIS G. KIDD G. KIDD JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: MWD RUN 4 AK-MM-00132 RA/~DY KRELL GAVIN KIDD 35 12N 12E FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 4421 4498 .00 64.41 35.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.500 20.000 110.0 9.875 10.750 4016.0 6.125 7.000 8880.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 3. MWD RUN 2 IS DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY .PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO-DENSITY (SLD). 4. MWD RUNS 3-4 ARE DIRECTIONAL WITH DGR, EWR4, COMPEN- SATED THERMAL NEUTRON POROSITY (CTN), AND SLD. FINAL WELLBORE S-101 KICKS OFF FROM THIS WELLBORE AT 9203'MD, 6812'TVD. 5. MWD RUNS 1-4 REPRESENT WELL S-101 PB1 WITH API#: 50-029-22968-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9894'MD, 6733'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVIT (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 9.875" - 6.125" MUD WEIGHT: 10.3 - 11.2 PPG MUD SALINITY: 300-160,000 PPM CHLORIDES FORMATION WATER SALINITY: 23000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP NCNT DRHO FCNT NPHI FET RPD RPM RPS .5000 START DEPTH 449.5 503 5 3868 5 4006 0 4006 0 4006 0 4006 0 4006 0 4006 0 4006 0 STOP DEPTH 9843.5 9894 0 9785 0 9800 5 9785 5 9785 0 9850 5 9850 5 9850.5 9850.5 RPX 4006.0 RHOB 4007.0 PEF 4007.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: 9850.5 9800.5 9800.5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 449.5 4025.0 2 4025.0 8881.0 3 8881.0 9139.0 4 9139.0 9894.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data SPecification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 Name Service Unit Min Max Mean Nsam DEPT FT 449.5 9894 5171.75 18890 ROP MWD FT/H 0 335.99 91.3503 18782 GR MWD API 10.24 429.92 81.9517 18789 First Reading 449.5 503.5 449.5 Last Reading 9894 9894 9843.5 RPX MWD OHMM 0.06 2000 RPS MWD OHMM 0.07 1699.62 RPM MWD OHMM 0.06 2000 RPD MWD OHMM 0.2 2000 FET MWD HOUR 0.33 74.18 NPHI MWD PU-S 6.46 75.11 FCNT MWD CNTS 129 2044.4 NCNT MWD CNTS 2008 43958 RHOB MWD G/CM 1.25 3.08 DRHO MWD G/CM -0.783 0.54 PEF MWD BARN 1.76 18.43 6.76757 11588 7.64425 11588 10.3907 11588 13.0902 11588 1.94699 11588 34.6679 11559 568.093 11560 6336.33 11834 2.2971 11494 0.0663834 11496 6.63416 11494 4006 4006 4006 4006 4006 4006 4006 3868.5 4007 4006 4007 9850.5 9850.5 9850.5 9850.5 9850.5 9785 9785.5 9785 9800.5 9800.5 9800.5 First Reading For Entire File .......... 449.5 Last Reading For Entire File ........... 9894 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 R_AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 449.5 3970.5 ROP 503.5 4025.0 $ LOG HEADER DATA DATE LOGGED: 13-AUG-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 5.46 Memory 4025.0 .5 49.0 TOOL NUMBER PB01500CG8 PB01500CG8 13.500 110.0 Spud Mud 9.50 200.0 9.2 7O0 5.8 1.600 1.310 3.500 4.000 Name Service Order Units Size Nsam Rep Code Offset Channel 70.0 87.0 70.0 7O.O DEPT FT 4 1 68 ROP MWD010 FT/H 4 1 68 GR MWD010 API 4 1 68 Name Service Unit Min' Max DEPT FT 449.5 4025 ROP MWD010 FT/H 0.54 223.58 GR MWD010 API 26.28 133.64 Mean Nsam 2237.25 7152 83.8286 7044 72.5142 7043 First Reading 449.5 503.5 449.5 Last Reading 4025 4025 3970.5 First Reading For Entire File .......... 449.5 Last Reading For Entire File ........... 4025 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NCNT GR FCNT NPHI FET RPD RPM RPS 3868 5 3971 0 4006 0 4006 0 4006 0 4006 0 4006 0 4006 0 STOP DEPTH 8826.0 8846 0 8826 0 8826 0 8818 5 8818 5 8818 5 8818 5 RPX 4006.0 DRHO 4006.0 RHOB 4007.0 PEF 4007.0 ROP 4025.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8818.5 8835.5 8835.5 8835.5 8880.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: 20-AUG-00 Insite 65.41 Memory 8880.0 39.8 65.2 TOOL NUMBER PB01604HRNLGV6 PB01604HRNLGV6 PB01604HRNLGV6 PB01604HRNLGV6 9.875 4016.0 LSND 11.20 45.0 8.8 600 3.2 3.700 1.911 2.600 2.700 68.0 138.0 68.0 68.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR NPHI MWD020 PU-S FCNT MWD020 CNTS NCNT MWD020 CNTS RHOB MWD020 G/CM DRHO MWD020 G/CM PEF MWD020 BARN Min 3868.5 0 10.24 0 85 0 84 0 82 0 97 0 33 11 15 289 2008 1.25 -0.783 4.43 Max Mean Nsam 8880.5 6374.5 10025 335.99 107.49 9711 429.92 88.9732 9751 2000 6.46556 9626 1640.04 6.67856 9626 2000 7.85533 9626 2000 11.8847 9626 61 1.69076 9626 75.11 36.7956 9641 1188 577.633 9641 3512 2628.47 9916 3.02 2.28352 9658 0.443 0.0727419 9660 18.43 7.48551 9658 First Reading 3868.5 4025.5 3971 4006 4006 4006 4006 4006 4006 4006 3868.5 4007 4006 4007 Last Reading 8880.5 8880.5 8846 8818.5 8818.5 8818.5 8818.5 8818.5 8826 8826 8826 8835.5 8835.5 8835.5 First Reading For Entire File .......... 3868.5 Last Reading For Entire File ........... 8880.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. 3 .5000 BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT GR FET RPX RPS RPM RPD ROP RHOB PEF DRHO $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 8826.5 8826 5 8826 5 8846 5 887O 0 8870 0 8870 0 8870.0 8870.0 8881.5 8883.0 8883.0 8883.0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) STOP DEPTH 9029 5 9029 5 9029 5 9088 5 9095 5 9095 5 9095 5 9095 5 9095 5 9138 5 9045 0 9045 0 9045 0 24-AUG-00 Insite 65.44 Memory 9139.0 65.3 87.1 VENDOR TOOL CODE DGR EWR4 CTN SLD $ TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERM3kL NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP=ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ..... ........ Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER PB01618HAGRV4 PB01618HAGRV4 PB01618PIAGRV4 PB01618HAGRV4 6.125 8880.0 Baradrill -N 10.40 49.0 8.7 146000 3.8 .020 .010 .030 .060 64.0 142.0 64.0 64.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 I 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 NCNT MWD030 CNTS 4 1 68 40 RHOB MWD030 G/CM 4 1 68 44 DRHO MWD030 G/CM 4 1 68 48 PEF MWD030 BARN 4 1 68 52 10 11 12 13 14 Name Service Unit Min Max Mean DEPT FT 8826.5 9138.5 8982.5 ROP MWD030 FT/H 6.58 115.43 37.7859 GR MWD030 API 42.52 106.78 78.1587 RPX MWD030 OHMM 0.06 21.03 7.61199 RPS MWD030 OHMM 0.07 1699.62 15.8853 RPM MWD030 OHMM 0.06 2000 57.4287 RPD MWD030 OHMM 0.2 1887.16 44.4292 FET MWD030 HOUR 1.09 74.18 5.62765 NPHI MWD030 PU-S 6.46 38.7 24.1533 FCNT MWD030 CNTS 129 1894 483.872 NCNT MWD030 CNTS 14765 43958 24771.1 RHOB MWD030 G/CM 2.24 3.08 2.36668 DRHO MWD030 G/CM -0.132 0.54 -0.00378154 PEF MWD030 B~_RN 1.86 12.2 2.23849 Nsam 625 515 485 452 452 452 452 452 407 407 407 325 325 325 First Reading 8826.5 8881.5 8846.5 8870 8870 8870 8870 8870 8826.5 8826.5 8826.5 8883 8883 8883 Last Reading 9138.5 9138.5 9088.5 9095.5 9095 5 9095 5 9095 5 9095 5 9029 5 9029 5 9029 5 9045 9045 9045 First Reading For Entire File .......... 8826.5 Last Reading For Entire File ........... 9138.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 R_AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NPHI FCNT NCNT PEF RHOB DRHO GR RPM RPS RPD FET RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 9030.5 9030.5 9030.5 9045.5 9045.5 9045.5 9089 0 9096 0 9096 0 9096 0 9096 0 9096 0 9139 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9785 0 9785 5 9785 0 9800 5 9800 5 9800 5 9843 5 9850 5 9850 5 9850.5 9850.5 9850.5 9894.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 25-AUG-00 Insite 65.44 Memory 9894.0 92.2 98.8 TOOL NUMBER PB01618HAGRV4 PB01618HAGRV4 PB01618RAGRV4 PB01618HAGRV4 6.125 8880.0 Baradril-N 10.40 49.0 8.6 143000 3.7 .020 .010 .030 67.0 133.5 67.0 MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 .100 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 0HMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 64.0 Name Service Unit DEPT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HOUR NPHI MWD040 PU-S FCNT MWD040 CNTS NCNT MWD040 CNTS RHOB MWD040 G/CM Min 9030.5 1.99 46.27 2.11 2.64 2.97 3.2 0.89 7.28 375 21706 2.2 Max 9894 76.6 152.64 20 13 30 75 31 51 22 29 14 81 30 61 2044.4 43233.7 2.645 Mean Nsam 9462.25 1728 40.9731 1511 81.846, 1510 8.44005 1510 11.3335 1510 12.4727 1510 11.394 1510 2.47867 1510 23.9245 1510 529.888 1511 25703.2 1510 2.36895 1511 First Reading 9030.5 9139 9089 9096 9096 9096 9096 9096 9030.5 9030.5 9030.5 9045.5 Last Reading 9894 9894 9843 5 9850 5 9850 5 9850 5 9850 5 9850 5 9785 9785.5 9785 9800.5 DRHO MWD040 G/CM -0.031 0.189 PEF MWD040 BARN 1.76 3.68 0.0408246 1511 2.13789 1511 9045.5 9800.5 9045.5 9800.5 First Reading For Entire File .......... 9030.5 Last Reading For Entire File ........... 9894 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/12/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/12/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/12/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Services Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mon Oct 02 14:35:49 2000 Reel Header Service name ............. LISTPE Date ..................... 00/10/02 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/10/02 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: #. JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: RECEIVED OCT 05 s- 1 o i Anohom~e 500292296800 BP Exploration (Alaska), Inc. Sperry Sun 02-OCT-00 MWD RUN 1 MWD RUN 2 MWD RUN 3 AK-MM-00132 AK-MM-00132 .AK-MM-00132 M. HANIK R. KRELL R. KRELL S. LEWIS G. KIDD G. KIDD JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MM-00132 R. KRELL G. KIDD MWD RUN 5 MWD RUN 6 AK-MM-00132 AK-MM-00132 R. KRELL M. HANIK G. KIDD S. LEWIS JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: MAD RUN 6 AK-MM-00132 M. HANIK S. LEWIS MAD RUN 6 AK-MM-00132 M. HANIK S. LEWIS 35 TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 12N 12E 4421 4498 .00 64.41 35.80 REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.500 20.000 110.0 9.875 10.750 4016.0 6.125 7.000 8880.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 3. MWD RUN 2 IS DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO-DENSITY (SLD). 4. MWD RUNS 3-6 ARE DIRECTIONAL WITH DGR, EWR4, COMPEN- SATED THERMAL NEUTRON POROSITY (CTN), AND SLD. RUN 5 IS THE OPEN-HOLE SIDETRACK FROM WELL S-101 PB1 WHICH OCCURS AT 9203'MD, 6812'TVD. 5. A MEASUREMENT AFTER DRILLING (MAD) PASS ACQUIRED EWR4 DATA IN THE INTERVALS 8785'MD, 6733'TVD TO 9901'MD, 6755'TVD AND 9747'MD, 6762'TVD TO 11676'MD, 6752'TVD. THE SHALLOWER PASS OCCURRED WHILE RUNNING IN THE HOLE FOR MWD RUN 6, THE DEEPER LOGGED OUT OF THE HOLE FOLLOWING THE TD OF RUN 6. THE MERGED MAD DATA IS PRESENTED AS A TAIL TO THIS LOG. 6. MWD DATA IS PDC PER THE PHONE CONVERSATION BETWEEN R KALISH OF SPERRY-SUN DRILLING SERVICES AND J COPEN OF BP EXPLORATION (ALASKA), INC. ON 09/18/00. 7. MWD RUNS 1-6 REPRESENT WELL S-101 WITH API%: 50-029-22968-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF l1721'MD, 6754'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVIT (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX~ FIXED HOLE SIZE). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE.. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 =' SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 9.875" - 6.125" MUD WEIGHT: 10.3 - 11.2 PPG MUD SALINITY: 300-160,000 PPM CHLORIDES FORMATION WATER SALINITY: 23000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH SGRC 449.5 11670.5 SROP 503.5 11721.5 SNNA 3868.5 11611.5 SFXE 4006.0 11677.5 SEXP 4006.0 11677.5 SESP 4006.0 11677.5 SEMP 4006.0 11677.5 SEDP 4006.0 11677.5 SNFA 4006.0 11611.5 SCO2 4006.0 11627.5 SPSF 4006.0 11611.5 SNP2 4007.0 11627.5 SBD2 4007.0 11627.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH .......... BIT RUN NO MERGE TOP MERGE BASE 1 449.5 4025.0 · 2 4025.0 9045.0 3 9045.0 9139.0 4 9139.0 9203.0 5 9203.0 9948.0 6 9948.0 11724.5 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction .................. Down Optical log depth units. .......... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD PU-S 4 1 68 FCNT MWD CNTS 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 NCNT MWD CNTS 4 1 68 RHOB MWD G/cM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 449.5 11721.5 ROP MWD FT/H 0 446.36 GR MWD API 10.24 429.92 RPX MWD OHMM 0.06 2000 RPS MWD OHMM 0.07 1699.62 RPM MWD OHMM 0.06 2000 RPD MWD OHMM 0.2 2000 FET MWD HOUR 0.33 84.78 NPHI MWD PU-S 6.46 75.11 FCNT MWD CNTS 129 1894 NCNT MWD CNTS 2008 43958 RHOB MWD G/CM 1.25 3.08 DRHO MWD G/CM -0.783 0.5'4 PEF MWD BARN 1.39 18.43 Mean Nsam 6085.5 22545 89.3664 22413 80.7277 22443 8.1869 15242 10.1741 15242 12.5665 15242' 14.0498 15242 1.8933 15242 32.1387 15212 557.629 15212 10888.7 15487 2.31008 15148 0.0597854 15150 5.59282 15148 First Reading 449.5 503.5 449.5 4006 4006 4006 4006 4006 4006. 4006 3868.5 4007 4006 4007 Last Reading 11721.5 11721.5 11670.5 11677.5 11677.5 11677.5 11677.5 11677.5 11611.5 11611.5 11611.5 11627.5 11627.5 11627.5 First Reading For Entire File .......... 449.5 Last Reading For Entire File .......... .11721.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... !.0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ............ STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 8781.0 11673.5 RPD RPM RPS RPX FET RAT $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: 8787.5 11679.5 8787.5 11679.5 8787.5 11679.5 8787.5 11679.5 8787.5 11679.5 8831.5 11724.5 MAD RUN NO. MAD PASS NO. MERGE TOP 6 1 8832.0 6 2 9794.0 MERGED MAD PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ............ ' ........... Datum Specification Block sub-type...0 MERGE BASE 9947.0 11725.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RAT MAD FT/H 4 1 68 GR MAD API 4 1 68 RPX MAD OHMM 4 1 68 RPS MAD OHMM 4 1 68 RPM MAD OHMM 4 1 68 RPD MAD OHMM 4 1 68 FET MAD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 8781 11724.5 RAT MAD FT/H 3 1186 GR MAD API 29.01 176.78 RPX MAD OHMM 0.09 2000 RPS MAD OHMM 0.06 2000 RPM MAD OHMM 0.14 2000 RPD MAD OHMM 0.06 2000 FET MAD HOUR 3.72 232 Mean 10252.8 390.232 78.8714 8.0653 27. 197 14.3311 20.0893 56.3094 Nsam .5888 5787 5786 5785 5785 5785 5785 5785 First Reading 8781 8831.5 8781 8787.5 8787.5 8787.5 8787.5 8787.5 Last Reading 11724.5 11724.5 11673.5 11679.5 11679.5 11679.5 11679.5 11679.5 First Reading For Entire File .......... 8781 Last Reading For Entire File.. .......... 11724.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH · STOP DEPTH GR 449.5 3970.5 ROP 503.5 4025.0 LOG HEADER DATA DATE LOGGED: 13-AUG-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORy OR REAL-TIME): MEMORY TD DRILLER (FT): 4025.0 · TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .5 MAXIMUM ANGLE: 49.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): TOOL NUMBER PB01500CG8 13.500 110.0 Spud Mud 9.50 200.0 9.2 700 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ...................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 5.8 1.600 1.310 3.500 4.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API .4 1 68 8 3 70.0 87.0 70.0 70.0 Name Service Unit Min Max Mean. Nsam DEPT FT 449.5 4025 2237.25 7152 ROP MWD010 FT/H 0.54 223.58 83.8286 7044 GR MWD010 API 26.28 133.64 72..5142 7043 First Reading 449.5 503..5 449.5 Last Reading 4025 4025 3970.5 First Reading For Entire File .......... 449.5 Last Reading For Entire File ........... 4025 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 3868.5 8826.0 GR 3971.0 8846.0 DRHO 4006.0 8835.5 FET 4006.0 8818.5 RPX 4006.0 8818.5 RPS 4006.0 8818.5 RPS 4006.0 8818.5 RPD 4006.0 8818.5 NPHI 4006.0 8826.0 FCNT 4006.0 8826.0 RHOB 4007.0 8835.5 PEF 4007.0 9045.0 ROP 4025.5 8880.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR EWR4 CNP SLD $ DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS 20-AUG-00 Insite 65.41 MEMORY 8880.0 39.8 65.2 TOOL NUMBER PB01604HRNLGV6 PB01604HRNLGV6 PB01604HRNLGV6 PB01604HRNLGV6 9.875 4016.0 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record 'Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 LSND 11.20 45.0 8.8 600 3.2 3.700 1.911 2.600 2.700 68.0 138.0 68.0 68.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HOUR 4 1 68 NPHI MWD020 PU-S 4 1 68 FCNT MWD020 CNTS 4 1 68 NCNT MWD020 CNTS 4 1 68 RHOB MWD020 G/CM 4 1 68 DRHO MWD020 G/CM 4 1 68 PEF MWD020 BARN 4 t 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 3868.5 9045 ROP MWD020 FT/H 0 335.99 GR MWD020 API 10.24 429.92 RPX MWD020 OHMM 0.85 2000 RPS MWD020 OHMM 0.84 1640.04 RPM MWD020 OHMM 0.82 2000 Mean Nsam 6456.75 10354 107.49 9711 88.9732 9751 6.46556 9626 6. 67856 9626 7.85533 9626 First Reading 3868.5 4025.5 3971 4006 4006 4006 Last Reading 9045 8880.5 8846 8818.5 8818.5 8818.5 RPD MWD020 OHMM FET MWD020 HOUR NPHI MWD020 PU-S FCNT MWD020 CNTS NCNT MWD020 CNTS RHOB MWD020 G/CM DRHO MWD020 G/CM PEF MWD020 BARN 0.97 2000 0.33 61 11.15 75.11 289 1188 2008 3512 1.25 3.02 -0.783 0.443 1.86 18.43 11.8847 1.69076 36.7956 577.633 2628.47 2.28352 0.0727419 7.31471 9626 9626 9641 9641 9916 9658 9660 9983 4006 4006 4006 4006 3868.5 4007 4006 4007 8818.5 8818.5 8826 8826 8826 8835.5 8835.5 9045 First Reading For Entire File .......... 3868.5 Last Reading For Entire File ........... 9045 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER:" 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PEF 8788.5 9045.0 NPHI 8826.5 9029.5 FCNT 8826.5 9029.5 NCNT 8826.5 9029.5 GR 8846.5 9088.5 RPS 8870.0 9095.5 RPM 8870.0 9095.5 RPD 8870.0 9095.5 FET 8870.0 9095.5 RPX 8870.0 9095.5 ROP 8881.5 9138.5 RHOB 8883.0 9045.0 DRHO 8883.0 9045.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type'. ................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 24-AUG-00 Insite 65.44 MEMORY 9139.0 65.3 87.1 TOOL NUMBER PB01618HAGRV4 PB01618HAGRV4 PB01618HAGRV4 PB01618HAGRV4 6.250 8880.0 Baradrill-N 10.40 49.0 8.7 146000 3.8 .020 .010 .030 .060 64.0 142.0 64.0 64.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HOUR 4 1 68 NPHI MWD030 PU-S 4 1 68 FCNT MWD030 CNTS 4 1 68 NCNT MWD030 CNTS 4 1 68 RHOB MWD030 G/CM 4 1 68 DRHO MWD030 G/CM 4 1 68 PEF MWD030 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 8788.5 9138.5 ROP MWD030 FT/H 6.58 115.43 GR MWD030 API 42.52 106.78 RPX· MWD030 OHMM 0.06 21.03 RPS MWD030 OHMM 0.07 1699.62 RPM MWD030 OHMM 0.06 2000 RPD MWD030 OHMM 0.2 1887.16 FET MWD030 HOUR 1.09 74.18 NPHI MWD030 PU-S 6.46 38.7 FCNT MWD030 CNTS 129 1894 NCNT MWD030 CNTS 14765 43958 RHOB MWD030 G/CM 2.24 3.08 DRHO MWD030 G/CM -0.132 PEF MWD030 BARN 1.86· Mean Nsam 8963.5 701 37.7859 515 78.15~87 485 7.61199 452 15.8853 452 57.4287 452 44.4292 452 5.62765 452 24.1533 407 483.872 407 24771.1 407 2.36668 325 325 423 0.54 -0.00378154 17.54' 5.11745 First Reading 8788.5 8881.5 8846.5 8870 887O 8870 8870 8870 8826.5 8826.5 8826.5 8883 8883 8788.5 Last Reading 9138.5 9138.5 9088.5 9095.5 9095.5 9095.5 9095.5 9095.5 9029.5 9029.5 9029.5 9045 9045 9045 First Reading For Entire File .......... 8788.5 Last Reading For Entire File ........... 9138.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1,0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 9030.5 9203.0 FCNT 9030.5 9203.0 NPHI 9030.5 9203.0 DRHO 9045.5 9203.0 PEF 9045.5 9203.0 RHOB 9045.5 9203.0 GR 9089.0 9203.0 RPX 9096.0 9203.0 RPS 9096.0 9203.0 RPM 9096.0 9203.0 RPD 9096.0 9203.0 FET 9096.0 9203.0 ROP 9139.0 9203.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DGR CTN SLD $ DUAL GAMMA RAY DUAL GAMMA RAY COMP THERMAL NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 25-AUG'00 Insite 65.44 MEMORY 9203.0 90.4 94.6 TOOL NUMBER PB01618HAGRV4 PB01618HAGRV4 PB01618HAGRV4 PB01618HAGRV4 6.250 8880.0 Baradrill-N 10.40 45.0 8.8 150000 2.9 MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 .020 .011 .030 .100 67.0 133.5 67.0 64.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 · CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 Name Service Unit DEPT FT ROP MWD040 FT/H GR MWD040 API RPX MWD040 OHMM RPS MWD040 OHMM RPM MWD040 OHMM RPD MWD040 OHMM FET MWD040 HOUR NPHI MWD040 PU-S FCNT MWD040 CNTS NCNT MWD040 CNTS RHOB MWD040 G/CM DRHO MWD040 G/CM Min Max Mean Nsam 9030.5 9203 9116.75 346 1.99 61.21 42.7755 129 68.06 85.07 76.4643 229 3.97 12.28 7.41214 215 6.77 13.95 10.0013 215 8.78 13.53 10.8764 215 8.31 11.19 9.54353 215 1.06 14.81 6.94098 215 20.34 28.62 25.7617 346 375 605 458.055 346 21706 27509 24504 346 212 2.49 2.34668 316 -0.026 0.168 0.0356519 316 First Reading 9030.5 9139 9089 9096 9096 9096 9096 9096 9030.5 9030.5 9030.5 9045.5 9045.5 Last Reading 9203 9203 9203 9203 9203 9203 9203 9203 9203 9203 9203 9203 9203 PEF MWD040 BARN 1.77 3.68 2.23044 316 9045.5 9203 First Reading For Entire File .......... 9030.5 Last Reading For Entire File ........... 9203 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 9203.5 9838.5 FET 9203.5 9904.0 ROP 9203.5 9947.5 GR 9203.5 9897.0 RPX 9203.5 9904.0 RPS 9203.5 9904.0 RPM 9203.5 9904.'0 RPD 9203.5 9904.0 FCNT 9203.5 9838.5 RHOB 9203.5 9854.0 DRHO 9203.5 9854.0 PEF 9203.5 9854.0 NPHI 9203.5 9838.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): 29-AUG-00 Insite 65.44 MEMORY 9946.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 90.4 97.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ TOOL NUMBER PB01618HAGRV4 PB01618HAGRV4 PB01618HAGRV4 PB01618HAGRV4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.250 8880.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPER3~TURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Baradrill-N 10.40 45.0 8.4 148000 46.0 .020 .011 .030 .100 67.0 133.5 67.0 64.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 RPD MWD050 OHMM 4 1 68 FET MWD050 HOUR 4 1 68 NPHI MWD050 PU-S 4 1 68 FCNT MWD050 CNTS 4 1 68 NCNT MWD050 CNTS 4 1 68 RHOB MWD050 G/CM 4 1 68 DRHO MWD050 G/CM 4 1 68 PEF MWD050 BARN 4 1 68 20 24 28 32 36 4O 44 48 52 6 7 8 9 10 11 12 13 14 Name Service Unit Min Max DEPT FT 9203.5 9947.5 ROP MWD050 FT/H 0 138.67 GR MWD050 API 57.55 111.13 RPX MWD050 OHMM 1.22 23.81 RPS MWD050 OHMM 1.77 24.32 RPM MWD050 OHMM 3.24 21.43 RPD MWD050 OHMM 3.82 22.48 FET MWD050 HOUR 0.53 84.78 NPHI MWD050 PU-S 15.07 31.82 FCNT MWD050 CNTS 341 883 NCNT MWD050 CNTS 19706 32907 RHOB MWD050 G/CM 2.3 2.94 DRHO MWD050 G/CM -0.049 0.432 PEF MWD050 BARN 1.67 6.24 Mean 9575.5 55.5135 86.0033 8.70135 10.7878 11.5259 10.8111 1.51636 24.0305 523.266 25905.1 2.39293 0.0493518 2.20309 Nsam 1489 1489 1388' 1402 1402 1402 1402 1402 1271 1271 1271 1302 1302 1302 First Reading 9203.5 9203.5 9203.5 9203.5 9203.5 9203.5 9203.5 9203.5 9203.5 9203.5 9203.5 9203.5 9203.5 9203.5 Last Reading 9947.5 9947.5 9897 9904 9904 9904 9904 9904 9838.5 9838.5 9838.5 9854 9854 9854 First Reading For Entire File .......... 9203.5 Last Reading For Entire File ........... 9947.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... VersiOn Number ........... 1.0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NPHI 9839.0 FCNT 9839.0 NCNT 9839.0 RHOB 9854.5 DRHO 9854.5 PEF 9854.5 GR 9897.5 RPM 9904.5 RPS 9904.'5 RPD 9904.5 FET 9904.5 RPX 9904.5 ROP 9948.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11611.5 11611.5 11611.5 11627.5 11627.5 11627.5 11670.5 11677.5 11677.5 11677.5 11677.5 11677.5 11721.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 ' CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM$ AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: Oi-SEP-O0 Insite' 65.44 MEMORY 11721.0 85.5 94.3 TOOL NUMBER PB01629FHA4 PB01629FHA4 PB01629FHA4 PB01629FHA4 6.250 8880.0 Baradrill-N 10.40 49.0 8.5 155000 3.7 .020 .010 .060 .030 72.0 149.0 74.0 74.0 MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset DEPT FT 4 1 68 0 ROP MWD060 FT/H 4 1 68 4 GR MWD060 API 4 1 68 8 RPX MWD060 OHMM 4 1 68 12 RPS MWD060 OHMM 4 1 68 16 RPM MWD060 OHMM 4 1 68 20 RPD MWD060 OHMM 4 1 68 24 FET MWD060 HOUR 4 1 68 28 NPHI MWD060 PU-S 4 1 68 32 FCNT MWD060 CNTS 4 1 68 36 NCNT MWD060 CNTS 4 1 68 40 RHOB MWD060 G/CM 4 1 68 44 DRHO MWD060 G/CM 4 1 68 48 PEF MWD060 BARN 4 1 68 52 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Name Service Unit Min Max Mean DEPT FT 9839 11721.5 10780.3 ROP MWD060 FT/H 0 446.36 74.0523 GR MWD060 API 48.18 110.55 72.9308 RPX MWD060 OHMM 4.6 62.14 12.7752 RPS MWD060 OHMM 5.26 149.91 18.7008 RPM MWD060 OHMM 5.94 141.79 20.1487 RPD MWD060 OHMM 7.29 81.91 17.6073 FET MWD060 HOUR 0.54 31.92 1.81014 NPHI MWD060 PU-S 9.82 37.21 23.9248 FCNT MWD060 CNTS 263 1494 533.732 NCNT MWD060 CNTS 19908 39716 25678.7 RHOB MWD060 G/CM 2.08 2.95 2.34352 DRHO MWD060 G/CM -0.14 0.308 0.0363036 PEF MWD060 BARN 1.39 7.54 2.2904 Nsam 3766 3524 .3547 3547 3547 3547 3547 3547 3546 3546 3546 3547 3547 3547 First Reading 9839 9948 9897'.5 9904.5 9904.5 9904.5 9904.5 9904.5 9839 9839 9839 9854.5 9854.5 9854.5 Last Reading 11721.5 11721.5 11670.5 11677.5 11677.5 11677.5 11677.5 11677.5 11611.5 11611.5 11611.5 11627.5 11627.5 11627.5 First Reading For Entire File .......... 9839 Last Reading For Entire File ........... 11721.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 6 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8781.0 9898.5 RPM 8787 . 5 9904.5 RPD 8787.5 9904.5 FET 8787 . 5 9904.5 RPS 8787.5 9904.5 RPX 8787.5 9904.5 RAT 8831.5 9946.5 $ LOG HEADER DATA · DATE LOGGED: 01-SEP-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 65.44 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 11721.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.5 MAXIMUM ANGLE: 94.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01629FHA4 EWR4 ELECTROMAG. RESIS. 4 PB01629FHA4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.250 8880.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record .............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Baradrill-N 10.40 49.0 8.5 155000 3.7 .020 .010 .060 .030 72.0 149.0 74.0 74.0 Name'Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD061 FT/H 4 1 68 4 2 GR MAD061 APi 4 1 68 8 3 RPX MAD061 OHMM 4 1 68 12 4 RPS MAD061 OHMM 4 1 68 16 5 RPM MAD061 OHMM 4 1 68 20 6 RPD MAD061 OHMM 4 1 68 24 7 FET MAD061 HOUR 4 1 68 28 8 Name Service Unit DEPT FT RAT MAD061 FT/H GR MAD061 API RPX MAD061 OHMM RPS MAD061 OHMM RPM MAD061 OHMM Min Max Mean Nsam 8781 9946.5 9363.75 2332 3 3783 864.671 2231 29.01 176.78 86.6349 2236 0.09 2000 13.0941 2235 0.06 2000 55.6725 2235 0.14 2000 11.7368 2235 First Reading 8781 8831.5 8781 8787.5 8787.5 8787.5 Last Reading 9946.5 9946.5 9898.5 9904.5 9904.5 9904.5 RPD MAD061 OHMM FET MAD061 HOUR 0.06 2000 31.04 232 24.9883 2235 87.956 2235 8787.5 8787.5 9904.5 9904.5 First Reading For Entire File .......... 8781 Last Reading For Entire File ........... 9946.5 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 6 MAD PASS NUMBER: 2 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9743.0 1167.3.5 FET 9750.0 11679.5 RPD 9750.0 11679.5 RPM 9750.0 11679.5 RPS 9750.0 11679.5 RPX 9750.0 11679.5 RAT 9793.5 11724 . 5 $ LOG HEADER DATA DATE LOGGED: 0I-SEP-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 65.44 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 11721.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 85.5 94.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER PB01629FHA4 PB01629FHA4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.250 8880.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record .Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down' Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............ ~Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block Sub-type...0 Baradrill-N 10.40 49.0 8.5 155000 3.7 .020 .010 .060 .030 72.0 149.0 74.0 74.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD062 FT/H 4 1 68 4 2 GR MAD062 API 4 1 68 8 3 RPX MAD062 OHMM 4 1 68 12 4 RPS MAD062 OHMM 4 1 68 16 5 RPM MAD062 OHMM 4 1 68 20 6 RPD MAD062 OHMM 4 1 68 24 7 FET MAD062 HOUR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 9743 11724.5 RAT MAD062 FT/H 6 369 GR MAD062 API 43.99 113.99 RPX MAD062 OHMM 1.07 32.66 RPS MAD062 OHMM 1.44 66.53 RPM MAD062 OHMM 1.89 113.94 RPD MAD062 OHMM 2.93 97.85 FET MAD062 HOUR 3.72 93.47 Mean 10733.8 216.311 75.0857 4.87925 9.08785 15.4923 16.5351 36.1627 First Last Nsam Reading Reading 3964 9743 11724.5 3863 9793.5 11724.5 3862 9743 11673.5 3860 9750 11679.5 3860 9750 11679.5 3860 9750 11679.5 3860 9750 11679.5 3860 9750 11679.5 First Reading For Entire File ........... 9743 Last Reading For Entire File ........... 11724.5 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/10/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/10/02. Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ...................... 00/10/02 Origin .......... . ......... STS ReetName ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
