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Home My WebLink About203-111Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:203-111 6.50-029-22225-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 12268 12181 8962 3656, 8785, 8842 Unknown none 3656, 8125, 8174 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 28 - 108 28 - 108 1530 520 Surface 3484 13-3/8" 27 - 3511 27 - 3511 5020 2260 Production 4048 9-5/8" 26 - 4074 26 - 4074 6870 4760 Liner 5340 7" 3645 - 8985 3645 - 8300 7240 5410 Perforation Depth: Measured depth: 9928 - 12120 feet True vertical depth:8900 - 8960 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13CR80 25 - 8842 25 - 8174 3656, 8785, 8842 3656, 8125, 8174Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP, 4-1/2" Baker S-3, 4-1/2" Baker ZX Liner 3433 4-1/2" 8835 - 12268 8168 - 8967 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 538029341 2023941 0 41011 310 432 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Ryan Thompson Ryan.Thompson@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 654-5280 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8966 Sundry Number or N/A if C.O. Exempt: n/a No SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Re-install Liner Patch Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028306 PBU 15-23A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 12:52 pm, Jul 15, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.07.15 11:31:38 -08'00' Bo York SFD 7/16/2021 MGR30JUL2021 DSR-7/15/21 RBDMS HEW 7/20/2021 ACTIVITYDATE SUMMARY 6/19/2021 ***WELL S/I ON ARRIVAL***(pprof). PULLED 32' 45 FLO-GUARD PATCH @ 9,079' MD. ALL ELEMENTS ON TOP PACKER MISSING. ***JOB CONTINUED ON 6/20/21 WSR*** 6/20/2021 ***JOB CONTINUED FROM 6/19/21 WSR***(pprof). RAN 4-1/2" BRUSH, 3.70" 4-PRING WIRE GRAB TO 9,200' SLM (no recovery). RAN 32' 45 KB PKR/PATCH DRIFT TO 9,200' SLM (no issues). ***WELL LEFT S/I ON DEPARTURE, JOB COMPLETE*** 6/23/2021 ***WELL S/I ON ARRIVAL, DSO NOTIFIED***(45 kb patch set) SET BAKER 45KB PATCH @ 9078' - 9103' (ELMENT TO ELEMENT). TOP OF PATCH @ 9077'. OAL = 30.73' / MIN ID= 2.45" / ~ 500 lbs CCL TO UPPER MID-ELEMENT OFFSET: 8.9'. CCL STOP DEPTH: 9069.1'. CORRELATED TO READ MULTI-FINGER CALIPER LOG DATED 23-JAN-2021. ***WELL LEFT S/I AND TURNED OVER TO DSO*** Daily Report of Well Operations PBU 15-23A Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:203-111 6.50-029-22225-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 12268 12181 8962 none none 3656, 8125, 8174 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 28 - 108 28 - 108 1530 520 Surface 3484 13-3/8" 27 - 3511 27 - 3511 5020 2260 Production 4048 9-5/8" 26 - 4074 26 - 4074 6870 4760 Liner 5340 7" 3645 - 8985 3645 - 8300 7240 5410 Perforation Depth: Measured depth: 9928 - 12120 feet True vertical depth:8900 - 8960 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13CR80 25 - 8842 25 - 8174 3656, 8785, 8842 3656, 8125, 8174Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP, 4-1/2" Baker S-3, 4-1/2" Baker ZX Liner 3433 4-1/2" 8835 - 12268 8168 - 8967 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 556033306 2226105 0 42829 422 405 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Ryan Thompson Ryan.Thompson@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 654-5280 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8966 Sundry Number or N/A if C.O. Exempt: n/a no SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028306 PBU 15-23A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 55 Liner patch 3656, 8785, 8842 By Samantha Carlisle at 10:45 am, Mar 01, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.02.25 15:09:47 -09'00' Bo York DSR-3/1/21 RBDMS HEW 3/1/2021 MGR01MAR2021 ACTIVITYDATE SUMMARY 1/22/2021 ***WELL S/I ON ARRIVAL*** DRIFT TO DEVIATION AT 9,924' SLM W/ 3.00" SAMPLE BAILER (No sample or issues). DRIFT TO DEVIATION AT 9,894' SLM W/ DUMMY 45KB x 30' PATCH (No issues). THUNDERBIRD LOADED TUBING W/ 225 BBLS OF CRUDE. RAN 4-1/2" D&D HOLE FINDER TO 9,875' SLM / ~9,900' MD (Begin testing). NO INCREASE IN PRESSURE UNTIL SET AT 8,900' SLM (Gained 250 psi but did not hold). SET AT 8,850' & AGAIN AT 8,700' SLM W/ SAME RESULTS (Element intact but has wear on sealing edge). ***LDFN, WELL S/I & SECURED, CONTINUED ON 1/22/21 WSR*** 1/22/2021 T/I/O=2400/0/200 Temp= S/I (TFS Unit 1 Assist Slickline with DND Hole Finder) Pumped 225 bbls of 0* F Crude down TBG to load and secure. Slickline ran DND hole finder and Pressured TBG to 1500 psi per run. 1/23/2021 ***CONTINUED FROM 1/22/21 WSR*** RAN READ 40 ARM CALIPER FROM 9,930' SLM TO 8,500' SLM (Good data). CALIPER SHOWED HOLE @ ~9096' MD. ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** 2/11/2021 Assist ELine - Pumped 3 bbls 60/40 meth and 125 bbls crude down Tbg for load. Eline in control of well per LRS departure. IA,OA=OTG 2/11/2021 ...Well shut in on arrival... (HES EL - Patch Set) MIRU E-LINE ...Continued on 12-Feb-21... 2/12/2021 ...Continued from 11-Feb-21 WSR... (HES EL - Patch liner for GSO) SET PATCH FROM 9,081' - 9,106' ELEMENT TO ELEMENT. (top of patch at 9,079') ***Job Complete.*** Well shut in on departure. Daily Report of Well Operations PBU 15-23A ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q3 - iLL Well History File Identifier Organizing (done) o Two-sided 111111111 11111111/1 o Rescan Needed 1/11111111/11" 111I R~AN r Color Items: o Greyscale Items: DIGITAL DATA ~kettes, NO~ o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: BY: (Maria ") Date: 1:J.. ~ ðÒ 151 mp 1111111111111111111 mp Project Proofing BY: ÇMar~ Date: (~ 1 oç :J X 30 =1 too + a '1 = TOTAL PAGES ~ 7 -, ~ ~count does not include cover, ~7Ft)ifJ Date: I :ì--~, CO:::;? 151 Y V \ r- III IIIIIII 151 Scanning Preparation BY: ~ Maria) Production Scanning Stage 1 Page Count from Scanned File: <3' ~ (Count does include ccyli sheet) Page Count Matches Number in ScannOng F¡>reparation: V YES ~ Date:tJ..~. OS- NO BY: Isl MP Stage 1 BY: If NO in stage 1, page(s) discrepancies were found: YES NO Maria Date: Isl II1IIII1II111 I· Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: Isl Comments about this file: Quality Checked 111111111111111111I 10/6/2005 Well History File Cover Page.doc • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder a~ Alaska Oil and Gas Conservation Commission a~ ~ ~' 333 West 7t" Avenue Anchorage, Alaska 99501 f ~f f ~~ Subject: Corrosion Inhibitor Treatments of GPB DS 15 i Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 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, API and PTD numbers, 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. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator s • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 naro• n~m~wn C Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-018 2042570 50029206960200 NA Sealed NA 15-026 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-048 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-06A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-OSC 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-118 2041460 50029206530200 NA Sealed NA 15-128 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12(2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-25B 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-26B 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10!8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009 15-296 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-31 B 2050860 50029222850200 NA 1.2 NA 3.4 11111 /2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-33B 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009 15-366 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-378 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-41B 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-426 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-456 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11/9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9!2009 15-488 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-49B 2090640 50029226510200 NA 7.3 NA 51.0 11/8!2009 • • --,., MICROFILMED 03/01/2008 DO NOT PLACE R ~,.~ F4~.~ yCY""` . ~' ~,i ANY NEW MATERIAL UNDER THIS PAGE F:~I.aserFiche\C~rPgs_Inserts~Microfilm_Marker.doc e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COmIll. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 1~1 \4-- RE: MWD Formation Evaluation Logs 15-23A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 15-23A: LAS Data & Digital Log Images: 50-029-22225-01 9'03 '-111 1 CD Rom ~C2®t4î ~ ~Yð'1 Dff ;), f? ~ '^--~ DATA SUBMITTAL COMPLIANCE REPORT 8/1/2005 Permit to Drill 2031110 Well Name/No. PRUDHOE BAY UNIT 15-23A Operator BP EXPLORATION (ALASKA) INC A~: ~o2~;:fs~i~ ) MD 12268 ;"" TVD 8967",.- Completion Date 7/28/2003'- Completion Status 1-01L Current Status 1-01L UIC N -- --- ------ --- ---~ - ----------- REQUIRED INFORMATION Mud Log No Samples No Directional S~ey ~ --~------------ ----- ---------- DATA INFORMATION Types Electric or Other Logs Run: DIR, GR, ABI, DEN, NEU, CBL Well Log Information: Log/ Electr Data Digital Dataset ~_e~/Frrnt _Number ED D (data taken from Logs Portion of Master Well Data Maint) Name Directional Survey Log Log Scale Media Run No Final Interval OH I Start Stop CH Received 3908 12268 Open 8/29/2003 -,' Comments MWD, PDF & PTT data file. PDF file will not open. : Rpt Directional Survey Final 3908 12268 Open 8/29/2003 MWD ! Rpt Directional Survey 3908 12268 Open ¡~D Directional Survey 3908 12268 Open PDF & PTT data files. ¥ 11982 LIS Verification 1-3 4070 12268 Open 9/16/2003 !Æ1S D tM ~L \ 11982 I nd uction/Resistivity 1-3 4070 12218 Open 9/16/2003 MWD-MPT, GR, EWR4, I CNP, SLD, ROP i ~D D ~L'~ 11982 Neutron 1-3 4070 12218 Open 9/16/2003 MWD-MPT, GR, EWR4, I CNP, SLD, ROP I 'iD D ~ \.") 11982 Density 1-3 4070 12218 Open 9/16/2003 MWD-MPT, GR, EWR4, V_n CNP, SLD, ROP Cement Evaluation 5 Blu 8835 9900 Case 11/24/2003 Slim Cement Mapping Tool - Cement Bond Log -- ----- ---- Well Cores/Samples Info rrnation: Sample Interval Set Name Start Stop Sent Received Number Comments Permit to Drill 2031110 MD 12268 TVD 8967 ADDITIONAL INFORMATION Well Cored? v'ß Chips Received? Y / N Analysis Received? - ~ n~ ~ .------ -- -----~- -- -- -------.- Comments: -_._-~- Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 8/1/2005 Well Name/No. PRUDHOE BAY UNIT 15-23A Operator BP EXPLORATION (ALASKA) INC Completion Date 7/28/2003 Completion Status 1-01L Current Status 1-01L UIC N Daily History Received? QJ ~N Formation Tops /'- r () Date: API No. 50-029-22225-01-00 -_./ ~ ~~tI h'1~ & ~ \ STATE OF ALASKA .") ALASKA 61L AND GAS CONSERVATION cotv...,SSION REPORT OF SUNDRY WELL OPERATIO~\~ ~1. Operations Peliormed: '(!! -<.t,.:,. Abandon 0 Repair WellO PluQ PerforationsD Stimulate 0 EEB 2 ~th~~ª Alter Casing 0 Pull TubingD Perforate New PaolO WaiverD Time ËxtensionD Change Approved ProgramO Operation ShutdownD Perforate ŒJ ~;1~e~r¡~,u~p~ndéd:WelltJ 2. Operator 4. Current Well Class: 5. Permit tOiDrfll'Ntimber: Name: BP Exploration (Alaska), Inc. Development ŒJ ExploratoryD 203-1110 3. Address: P.O. Box 196612 6. API Numb! Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-22225-01-00 7. KB Elevation (1t): 9. Well Name and Number: 60.90 15-23A 8. Property Designation: 10. Field/Pool(s): ADL-028306 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 12268 feet true vertical 8966.5 feet Effective Depth measured 12181 feet true vertical 8961.5 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H..40 28 108 28.0 108.0 1530 520 LINER 5340 7" 26# L-80 3645 - 8985 3644.7 - 8300.1 7240 5410 LINER 3433 4-1/2" 12.6# L-80 8835 - 12268 8168.0 - 8966.5 8430 7500 PRODUCTION 4048 9-5/8" 47# L·80 26 - 4074 26.0 - 4073.7 6870 4760 SURFACE 3484 13-3/8" 68# L-80 27 - 3511 27.0 - 3510.8 4930 2270 Measured depth: 9928 - 9953,9970 -10020, 10090 - 10140, 10330 - 10460, 10510 -10560,10610 -10690,10950 ·11030 11100 - 11260, 11370 -11770, 11820 -11870,11900 - 11950, 12030 -12120 True vertical depth: 8900.01 - 8905.83,8909.36 - 8917.71,8924.5 - 8926.18,8934.43·8941.3,8942·8941.74,8941.57 - 8942.06 8948.79 - 8950.65, 8954.28 - 8962.97,8964.31 - 8962.92,8962.4 - 8961.72,8961.32.. 8960.7,8960.08 - 8959.89 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 25 8842 Packers & SSSV (type & measured depth): 7" Baker ZXP Top Packer 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer @ @ @ 3656 8842 8785 - 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Averaqe Production or lojection Data Gas-Met Water-Bbl Casing Pressure 4.1 24 1200 5 194 1297 RBDMS 8Ft FIB 2 8 2005 13 Prior to well operation: Subsequent to operation: Oil-Bb! 335 1689 Tubing Pressure 282 335 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ ! 15. Well Class after proposed work: Exploratory 0 16. Well Status after proposed work: OìlŒJ GasD DevelopmentOO ServiceD Contact Printed Name Garry Catron Garry Catron J~. C ...J-- J....~i ç~ ~JJV KV\..j WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Production Technical Assistant Signature Phone 564-4657 Date 2/23/05 ~, I', " §\ ~ Form 10-404 Revised 4/2004 -\ ) ) 15-23A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 01/22/05 Perforation 100901-1014016 SPF 01/23/05 Perforation 99701-10020' 6 SPF, 99281-995316 SPF FLUIDS PUMPED BBLS 172 60/40 Methonal / Water 172 TOTAL Page 1 TREE = ¡ , FMC ~ELLHEA'D = MCEVOY ÄCTüÄT6R~ OTIS KB.'ECË\/ ;" - 57' ~'B'F'~"'ELEV"';""" .""'" ....... . '3:;i~'4ï 'Kop"';« ·········4ëii4ï ·MaxÄïïgië;;;······ 91"@"'1164f '5ãilim"MD·;'''······o ··.."·"·9782y ...................................................".... Datum TVD = 8800' SS 113-3/8" CSG, 68#, L-80, ID = 12.415" l-i 3518' ~ Minimum ID = 3.725" @ 8829' 4·1/2" HES XN NIPPLE I HES EZSV l-i 4100' '¡ 15-23A ~ J L 8' ~ I 19-5/8" CSG, 47#, L-80, ID = 8.681" l-i 8720' µ I I it.. I ~ II II .. 17" LNR, 29#, L-SO, .0371 bpf, ID = 6.184" l-i 10600' ¡-- .. 14-112" LNR, 12.6#, L-80, .0152 bpI, ID = 3.958" H 11273" ~ I m H 11500' ~ PERFORA TION SUMMARY REF LOG: ANGLE AT TOP PERF: 96 @ 9928' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 27/8" 6 9928 - 9953 0 01/22/05 27/8" 6 9970 - 10020 0 01/22/05 27/8" 6 10090-10140 0 01/22/05 2-1/2" 4 10330 - 10460 0 07/27/03 2-1/2" 4 10510 - 10560 0 07/27/03 2-1/2" 4 10610 - 10690 0 07/27/03' 2-1/2" 4 10950 - 11030 0 07/27/03 2-1/2" 4 11100 - 11260 0 07/27/03 2-1/2" 4 11370-11770 0 07/27/03 2-1/2" 4 11820-11870 0 07/27/03 2-1/2" 4 11900 - 11950 0 07/27/03 2-1/2" 4 12030 - 12120 0 07/27/03 DATE 12/25/91 07/29/03 09/12/03 12/25/03 02/04/04 07/27/04 REV BY COMMENTS ORIGINAL COM PLETION DAC/KK RIG SIDETRACK (15-23A) CMO/TLP DATUM MD & PERF ANGLE TJPITLP WAIVER SAFETY NOTE CMO/TLP PERF ANGLE CORRECTION JLJITLP GLV C/O SA \NOTES: 4-1/2" CHROMETBG. WAIVER CA~ lED 02/02/04 2213' l-i 4-1/2" HES X NIP, ID = 3.813" I ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LA TCH PORT DATE 4 3200 3139 1 KBG-2 DOME BK 16 09/02/03 3 5870 5809 35 KBG-2 DOME BK 16 09/02/03 2 7997 7936 31 KBG-2 DOME BK 16 09/02/03 1 8696 8635 31 CAMeO SO BK 20 07/27/04 3656' 1-1 9-5/8" X 7" BKR ZXP LNR TOP PKR, ID = 6.276" I MILLOUT WINDOW 4074' - 4090' 8764' l-i 4-1/2" HES X NIP, ID = 3.813" I 8785' l-i 7" x 4-1/2" BKR S-3 PKR, ID = 3.875" 1 8809' 1-i4-1/2" HES X NIP, ID = 3.813" I 8829' 1-i4-1/2" HES XN NIP, ID = 3.725" 1 8842' 1-i4-1/2" WLEG, ID = 3.958" 1 1 8843' 1- 7" X 4-1/2" BKR I ZXP PKR, ID = 4. 4-1/2" TBG, 12.6#, 13-CR, -1 .0152 bpf, ID = 3.958" I 7" CSG, 26#, L-80, ID = 6.276" l-i 1 PBTD l-i 12182' 1 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 12268' DA TE REV BY COMMENTS 12/02/04 JLW/TLP WAIVER CANCELED 01/22/05 JLG/PJC ADPERFS PRUDHOE BA Y UNIT WELL: 15-23A PERMIT No: 2031110 API No: 50-029-22225-01 SEC 22, T11 N, R14E, 3641.4' FEL & 2937.84' FNL BP Exploration (Alaska) -~ \ ) STATE OF ALASKA ) ,R,' E'·" ALASKA ÓIL AND GAS CONSERVATION COI"...,.SSIONa Cel\/r' REPORT OF SUNDRY WELL OPERATI()N97 2004- 1. Operations Performed: JH~';~:~ D" 0 ~_ AbandonD Repair WellD PluQ PerforationsD Stimulate lXi' "",, , Of II.:J!i:ifh&iãk, ."'I..'n".. Alter Casing 0 Pull TubingO Perforate New Pool 0 WaiverD Time E:tt1MfJîðlrije Change Approved ProgramD Operation Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 4. Current Well Class: Development [!] ExploratoryD 5. Permit to Drill Number: 203-1110 6. API Number 50-029-22225-01-00 60.90 8. Property Designation: ADl-028306 11. Present Well Condition Summary: Stratigraphic 0 ServiceD 9. Well Name and Number: 15-23A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Total Depth measured 12268 feet true vertical 8966.5 feet Effective Depth measured 12181 feet true vertical 8961.5 feet Plugs (measured) Junk (measured) None None Casing Conductor Liner Liner Production Surface length 80 5340 3433 4048 3484 Size 20" 94# H-40 7" 26# l-80 4-1/2" 12.6# l-80 9-5/8" 47# l-80 13-3/8" 68# l-80 MD TVD Burst Collapse 28 108 28.0 108.0 1530 520 3645 - 8985 3644.7 - 8300.1 7240 5410 8835 - 12268 8168.0 - 8966.5 8430 7500 26 - 4074 26.0 - 4073.7 6870 4760 27 - 3511 27.0 - 3510.8 4930 2270 Perforation deDth: Measured depth: 10330 -10460,10510 -10560,10610 -10690,10950 -11030,11100 -11260,11370 -11770,11820 -11870 11900 -11950,12030 -12120 True vertical depth: 8934.43 - 8941.3,8942 - 8941.74,8941.57 - 8942.06,8948.79 - 8950.65,8954.28 - 8962.97,8964.31 - 8962.92 8962.4 - 8961.72,8961.32 - 8960.7,8960.08 - 8959.89 Tubing (size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 25 8842 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer 7" Baker ZXP liner Top Packer @ 8785 @ 8842 @ 3656 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10330 - 12120 Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: Oil-Bbl 544 401 195 Bbls 10% HCl, 123 Bbls NH4CL with 0.1% F-104 & 12% U-66, 829 Bbls 3% NH4Cl with F-104 @ 3700 psig Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 5 0 480 3.8 6 547 Tubin~ Pressure 206 306 13 x 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒ] GasD Development ŒI Service D 14. Attachments: Copies of Logs and Surveys run_ Daily Report of Well Operations" WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron ßd~~. Title Production Technical Assistant Form 10-404 Revised 4/2004 Phone 564-4657 U:-<!GINAL Date 10/7/04 Signature .BFL OCT 1 1 ?~)ni~ '. \ ) ') 15-23A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/16/04 MIRU CTU#5 FOR ACID. RU ACID & N2 EQUIPMENT. MU 211 JSN WI STINGER. PT SURFACE LINES AND REVERSE OUT SKID. CONTINUED ON 08/17/04 WSR. 08/17/04 CONTINUED FROM 08/16/04 WSR. BLEED AND lOAD IA WI 200 BBl CRUDE. PICKLE COil WI 6 BBl 100/0 HCl, DISPLACE WI 45 BBl NH4CL. KllUlOAD WEll WI 277 BBlS FilTERED 1 % KCL. PUMP 40 BBlS DOWN TBG FOR POSITIVE WHP. PUMP 100 BBlS NH4Cl @ 103301. PUMP 107 BBlS NH4Cl WI U-66 ADDITIVE WHilE RIH TO 117701. PUMP 15 ACID STAGES IN 501 INTERVALS OVER PERFS FROM 10330'-17701. EACH ACID STAGES CONSIST OF: 11-14 BBlS 10% HCl, 24-30 BBlS 8-2 MUD ACID, 24-30 BBlS NH4Cl, NH4Cl WI N2 DIVERTER. STAGE 59 @ NOZZLE. CONTINUED ON 8/18/04 WSR. 08/18/04 CONTINUED FROM 08/17/04 WSR. PUMP REMAINING STAGES 60-64. DISPLACE REMAINING NH4Cl FROM COil AT 103701. POOH, KEEPING HOLE FULL. POST INJECTIVITY DOWN CT WAS 1.6 BPM/1672 PSI, LIMITED BY COil PRESSURE. RDMO. WEll READY TO POP. TURN OVER TO ASRC TESTERS. FLUIDS PUMPED BBLS 345 1 % KCL 207 Crude 10 Methonal/W ater 81 Diesel 195 10°10 HCL 829 3°1o NH4CL w/0.1 % F-104 123 3°1o NH4CL w/0.1 % F-104, 120/0 U-66 414 8-2 Mud Acid 6 Fresh Water 2210 TOTAL Page 1 lREE = FMC WELLH~ 0 = IVCEVOY Ä"(~TŒ'TÕR = ""·~'·''''''~·'·''~6Tis 'RB-:ËiBì-;" "·"'··"'''''·'''''''··-'s'j' BF. I3...EV;'__·m_'·_"-~"3"2.4ì ---_.-...............,'~......_---'"-._.~, KOP= 4074' ....... """""""" I'v1ax Angle = 91 @ 11647' Datum rvo = 9782' 't5ätum tvb = saOo; 'S8 \ ) 113-3/8" CSG, 68#, L-80, ID = 12.415" 1-1 3518' ~ Minimum ID = 3.725" @ 8829' 4-1/2" HES XN NIPPLE I I-ES EZSV 1-1 4100' 15-23A J ') SAFETY NOTES: 4·1/2" CHROME TBG. ** TxlA COMM, MAX lAP = 2500 PSI, MAX OAP = 1000 PSI (12125103 WAIVER) ** 2213' 1-1 4-1/2" HES X NIP, ID = 3.813" ~ GAS LIFT MANDRI3...S ST rvD lVD DEV lYPE VLV LATa-J RJRf DATE L 4 3200 3139 1 KBG-2 DOME BK 16 09/02/03 3 5870 5809 35 KBG-2 DOME BK 16 09/02/03 2 7997 7936 31 KBG-2 DOME BK 16 09/02/03 1 8696 8635 31 CAMCO SO BK 20 07/27/04 g ~ 3656' 1-1 9-5/8" x 7" BKR ZXP LNR TOP A<R, ID = 6.276" I 19-5/8" CSG, 47#, L-80, ID= 8.681" 1-1 8720' ~ I I" I ... II II ... 17" LNR 29#, L-80, ,0371 bpf, ID = 6.184" H 10600' r- .. 14-112"LNR 12.6#. L-80, .0152 bpI, ID= 3.95g' H 11273" ~ I 1D H 11500' ~ ÆRFORA TON SUrvfv1ARY REF LOG: ANGLEATTOPÆRF: 86 @ 10330' Note: Refer to Production DB for historical perf data SIZE SFf" INTERVAL Opn/Sqz DATE 2-1/2" 4 10330 - 10460 0 07/27/03 2-1/2" 4 10510 - 10560 0 07/27/03 2-1/2" 4 10610 - 10690 0 07/27/03 2-1/2" 4 10950 - 11030 0 07/27/03 2-1/2" 4 11100- 11260 0 07/27/03 2-1/2" 4 11370- 11770 0 07/27/03 2-1/2" 4 11820-11870 0 07/27/03 2-1/2" 4 11900-11950 0 07/27/03 2-1/2" 4 12030 - 12120 0 07/27/03 01\ lE 12/25/91 07/29103 08101/03 08122/03 09/02/03 09/12/03 RBI BY COrvfv1ENTS ORIGINAL COM PLErION DAC/KK RIG SIDETRACK (15-23A) MI-VTLH GLV 00 TH'KAK PERF GUN SIZE DTRlKK GLV 00 CI'v1OIlLP DATUM MO& PERF ANGLE MILLOUT WINOOW 4074' - 4090' 8764' 1-1 4-1/2" I-ES X NIP, ID = 3.813" I 8785' 1-17" X 4-1 /2" BKR 8-3 PKR ID = 3.875" I 8809' 1-14-112" I-ESX NIP, ID =3.813" I 8829' H 4-112" I-ES XN NIP, ID = 3.725" I 8842' H4-1/2" WLEG, 10 = 3.958" 1 I 8843' - 7' X 4-1/2" BKR ZXP PKR, ID = 4.420" 4-1/2"1BG, 12.6#, 13-CR -I 112182' H A3TD I .0152 bpf, ID = 3.958" I 7' CSG, 26#, L-80, ID = 6.276" H 4-1/2" LNR, 12.6#, L-80, .0152 bpf, D = 3.958" H 12268' I DA TE REV BY COMrvENfS 12/25/03 TJPIlLP WAIVERSAFETY NOTE 02/04104 CMOffLP PERF ANGLE CORREC1l0N 07/27/04 J...JIlLP GL V C/O PRLOI-OE BAY LNIT WELL: 15-23A PERMT t\b: 2031110 API t\b: 50-029-22225-01 SEC 22, T11 N, R14E, 3641.4' FI3... & 2937.84' FNL BP Exploration (Alas ka) Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well D.S.7-06A )~- tJ-\q ~ H-05 \ ,- t}3::) D.S.11-30 I ~ -()"1 G-12A q ( C ....1 ~ F-26A q~- ~c D.S. 15-23A an -=) 1 , ,\\ Job # 10564479 10662964 10559806 10564480 10568459 10559821 Log Description SCMT CET/USIT USIT SCMT SCMT SCMT 11/11/03 NO. 3039 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Date Blueline Prints CD 06/06/03 2 10/15/03 2 06/23/03 2 06/08/03 2 06/07/03 2 07/26/03 2 c____- ~/.:\ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH IO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~R" ECEIVF[",: ~ - .,', ;~ .0:" NOV 24 2003 Alaaka On & Gas Gon~ \MnmiØcn Anchomge Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth ~--'._"" ." '"'=-~ . Received by:~a~~\f'\._'\ ~)~A'\ ) ) dC)~3 '·-1 J J /19'?J,~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Howard Okland 33 3 West 7tJ.l Avenue, Suite 100 Anchorage, Alaska September 9, 2003 RE: MWD Formation Evaluation Logs 15-23A, AK-MW-2548429 1 LDWG formatted Disc with verification listing. API#: 50-029-22225-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: '·,C ., .", Signed~~c:~~,-....y\. ~.&-~~.c-.\.~ RECEIVED SE? 16 2003 .LJaska C~·; &: Gas Cons. Commiaeion ÀnchOf!l';e '-- '-. " \~~Df\(\~ .) . STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMfSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1382' SNL, 274' EWL, SEC. 22, T11N, R14E, UM Top of Productive Horizon: 1959' SNL, 2496' WEL, SEC. 21, T11N, R14E, UM Total Depth: 1653' SNL, 4878' WEL, SEC. 21, T11 N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 676211 y- _~9601 05 Zone- ASP4 TPI: x- 673456 y- 5959464 Zone- ASP4 --- Total Depth: x- 671067 y- 5959715 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: DIR, GR, ABI, DEN, NEU, CBL One Other 5. Date Camp., Susp., or Aband. 7/28/2003 6. Date Spudded 7/15/2003 7. Date T.D. Reached 7/24/2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 60.9' 9. Plug Back Depth (MD+TVD) 12181 + 8961 Ft 10. Total Depth (MD+ TVD) 12268 + 8967 Ft 11. Depth where SSSV set (Nipple) 2213' MD 19. Water depth, if offshore NIA MSL 1 b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-111 13. API Number 50- 029-22225-01-00 14. Well Number PBU 15-23A 15. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 16. Lease Designation and Serial No. ADL 028306 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 22. CASING· .. SIZE', 20" 13-3/8" 9-518" I I I , ~,,', I, ,', I " ,",' I .:' ", WT..· PERF1i,:·, 94.5# 68# 47# 26# 12.6# "''.:.", , .1':1 ; ", ":':",11'1,' .,':, " 'GRÞ:PEi".'I' H-40 1-80 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD .. Se:TTING:DEPTH"",·, ... ",.: HóL~;,'I¡. ;:'},::I'i":'i','i.' 1,:1,;.1",::",,1' : . ",itOI?,I.¡I"II"Bo:;rr:oM', ,:Ii,:II:i~IZE',':,":,CË~Ù·~~'TIN~Iß~¢ÓijD',···' , Surface 110' 30' 33' 3518' 16" 37' 4074' 12-1/4" 3645' 8985' 8-1/2" 8835' 12268' 6-1/8" 7" 4-1/2" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): ~1n"GunD~m~e~4s¢ MD TVD MD TVD 10330' - 10460' 8934' - 8941' 10510' - 10560' 8942' - 8942' 10610' - 10690' 8942' - 8942' 10950' - 11030' 8949' - 8951 ' 11100' - 11260' 8954' - 8963' 11370' - 11770' 8964' - 8963' 11820' - 11870' 8962' - 8962' 11900' -11950' 8961' - 8961' 12030' - 12120' 8960' - 8960' 27. Form 1 0-407 Rev¡sed..~Q~.__.. ,II:'; I I'" "'~ ',:,1, 1',.\ I':' 1,1.::;,: :>,:,:, ',' I '"I,': 'i I ~' : 'I 'i' ,I, I' I": I' , :AK4P\JJ)lT,·PUÜ~EO, 1329 sx CS III, 400 sx 'G', 100 sx CS II 1435 sx Class 'G' 365 sx Class 'G', 97 sx Class 'G' 414 sx Class 'G' 24. SIZE 4-1/2", 12.6#, 13Cr80 TLJSING RECó'RD' DEPTH SET (MD) 8842' PACKER SET (MD) 8785' 25. ',ACrR,FRACTLJRE,.· CEMENTSaUEEZE,ETC. DEPTH INTERVAL (MD) 2200' AMOUNT & KIND OF MATERIAL USED Freeze Protect with 155 Bbls of Diesel GAs-McF 162 W A TER-BsL -0- 26. PRODUCTION TEST :::>ate First Production: Method of Operation (Flowing, Gas Lift, etc.): August 9,2003 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BsL 8/22/2003 3.2 TEST PERIOD + 303 Flow Tubing Casing Pressure CALCULATED + OIL-BsL Press. 282 24-HoUR RATE 2,273 CORE DATA Brief descriQ~ion of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit co~e'chips; if none, state "none". None "?k$0 V~;=:i,;".· --...4¿.' ~~~~;::"~'~~='J~~ GAs-McF 1,215 W A TER-BsL -0- OR\G NAL CHOKE SIZE GAS-OIL RATIO 65° 533 OIL GRAVITy-API (CORR) ~;" ' ~ :,'-- C:. "0 ~BOMSB\fl if AUG 2 r;, 2Ü03 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKEl ) 29. )FORMATION TESTS . Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 8995' 8309' None Shublik 9040' 8349' Sadlerochit 9103' 8404' Top CGL 9295' 8568' Base CGL 9397' 8645' 23SB 9468' 8693' 22TS 9557' 8748' 21TS 9633' 8791' Zone 1 B 9847' 8877' Zone 1 A 9952' 8906' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed. ~.. JJ 4.liJ", Terne Hubble . tPA,tt e. 'JlLXrU4" PBU 15-23A 203-111 Well Number Title Technical Assistant Date 08-R.5-o.=5 Permit No. / Approval No. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Rob Tirpack, 564-4166 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 ORIGINAL Legal Name: Common Name: Test Date 7/14/2003 7/20/2003 FIT FIT 15-23 15-23A Test Type Test Depth (TMD) 4,074.0 (ft) 8,985.0 (ft) TestDepth (TVD) 4,074.0 (ft) 8,922.0 (ft) Surface Pressure EMW 12.03 (ppg) 9.50 (ppg) AMW 9.10 (ppg) 8.65 (ppg) Leak Off Pressure (BHFN 2,546 (psi) 4,401 (psi) 620 (psi) 392 (psi) <- -< Printed: 8/4/2003 9:24:45 AM Accept Rig For Well Work At 06:00 Hrs On 7/9/2003 Held Pre-Job Safety And Environmental Meeting Held PJSM - Install Secondary Annulus Valve Held PJSM - Rig Up DSM And Pull BPV Held PJSM - Rig Up Circulating Lines And Test Same To 3,000 Psi. (Test Good) Circulate Out Freeze Protection To Cuttings Tank Thru Choke Manifold At 3 BPM With 240 Psi. Held PJSM - Blow Down Circulating Lines And Rig Down Hoses Held PJSM - Dry Rod In BPV And Test From Below To 1,000 Psi. (Test Good) Held PJSM - Nipple Down Production Tree And Adaptor Flange - Inspect Threads And Install Blanking Plug Held PJSM - Nipple Up BOP And Related Equipment Held PJSM - Rig Up BOP Testing Equipment Held PJSM - Fill BOP Equipment With Water - Test BOP And Related Equipment Witness Of BOP Test Waived By AOGCC Inspector Jeff Jones - Test Annular, Upper And Lower Pipe Rams, Blind Rams, Manual And HCR Valves On Choke And Kill Lines, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Perform Accumulator Test DECOMP Held PJSM - Rig Down BOP Testing Equipment - Pull BPV With DSM - Clear Rig Floor - Clean Up Rig DECOMP Make Up Landing Joint And Cross Overs DECOMP Held PJSM - Back Out LDS - Pick Up On Tubing String To 160K And Repeat Process - Tubing String Stuck - Calculate Stretch Free Point Of 15 1/2" With 20K Over Pull Tubing Appears To Be Stuck At 5,018' Consult With Anchorage Drilling Engineer Rob Tirpack - Circulate Bottoms Up - Work Tubing String Every 15 Minutes And Monitor Well Bore - Lay Down Landing Joint Hold Pre-Job Safety Meeting Regarding Logging Operation - Rig Up Schlumberger E-Line - Install Lubricator - Make Up Logging Tools RIH With RST Tools - Log Down With GR-CCL From 3,000' To 6,659' Started Taking Weight - Log Up With RST Sigma From 6,659' To 3,000' - Log Down With RST GP From 3,800' To 5,990' - POH To 3,100' Log Down With RST GP From 3,100' To 3,900' - POH With Logging Tools DECOMP Held PJSM - Lay Down Schlumberger Logging Tools And Clear Rig Floor - Rig Up Sheave In Mast For Free Point And Chemical Cutting Operations Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-23 15-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES From- To Hours Task Code NPT Phase 7/8/2003 20:00 - 00:00 4.00 MOB P PRE 7/9/2003 00:00 - 06:00 6.00 RIGU P PRE 06:00 - 07:00 1.00 WHSUR P DECOMP 07:00 - 07:30 0.50 WHSUR P DECOMP 07:30 - 08:00 0.50 WHSUR P DECOMP 08:00 - 09:00 1.00 WHSUR P DECOMP 09:00 - 11 :30 2.50 WHSUR P DECOMP 11 :30 - 12:00 0.50 WHSUR P DECOMP 12:00 - 12:30 0.50 WHSUR P DECOMP 12:30 - 14:30 2.00 WHSUR P DECOMP 14:30 - 16:30 2.00 BOPSURP DECOMP 16:30 - 17:00 0.50 BOPSUR P DECOMP 17:00 - 21 :30 4.50 BOPSURP DECOMP 21 :30 - 23:30 2.00 BOPSURP 7/10/2003 23:30 - 00:00 00:00 - 01 :00 0.50 PULL P 1.00 PULL P 01 :00 - 04:00 3.00 PULL P DECOMP 04:00 - 06:00 2.00 EVAL P DECOMP 06:00 - 17:00 11.00 EVAL P DECOMP 17:00 - 18:00 1.00 EVAL P Start: 7/9/2003 Rig Release: 7/28/2003 Rig Number: Spud Date: 11/24/1991 End: 7/28/2003 Description of Operations Held PJSM - Move Camp Unit, Pump Room Pit Complex And Stage On Pad - Move Sub Base Off Well And Move To Well Row Around Corner Lay Out Herculite - Load Up Truck Shop And Misc. Rig Equipment Held PJSM - Lay Out Herculite And Position Sub Base - Move And Spot Pit Complex - Berm Rig And Cuttings Tank - Spot Truck Shop And Welding Shop - Hook Up Utilities And Srervice Lines From Sub Base To Pit Complex. Printed: 8/4/2003 9:24:56 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-23 15-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To Hours Task Code NPT Phase 7/10/2003 18:00 - 20:00 2.00 EVAL P DECOMP 20:00 - 21 :00 1.00 EVAL P DECOMP 21 :00 - 00:00 3.00 EVAL P DECOMP 7/11/2003 00:00 - 01 :00 1.00 EVAL P DECOMP 01 :00 - 01 :30 0.50 EVAL P DECOMP 01 :30 - 02:30 1.00 EVAL P DECOMP 02:30 - 03:30 1.00 EVAL P DECOMP 03:30 - 04:30 1.00 EVAL P DECOMP 04:30 - 06:00 1.50 EVAL P DECOMP 06:00 - 07:00 1.00 EVAL P DECOMP 07:00 - 08:30 1.50 EVAL P DECOMP 08:30 - 09:30 1.00 PULL P DECOMP 09:30 - 10:30 1.00 EVAL P DECOMP 10:30 - 11 :00 0.50 EVAL P DECOMP 11:00-12:00 1.00 EVAL P DECOMP 12:00 - 13:00 1.00 PULL P DECOMP 13:00 - 21 :00 8.00 PULL P DECOMP Start: 7/9/2003 Rig Release: 7/28/2003 Rig Number: Spud Date: 11/24/1991 End: 7/28/2003 DescriptiOn of Operations Held PJSM - Pick Up And Make Up Lubricator With Side Door Entry Sub - Install Safety Valve And Pump In Sub - Make Up Landing Joint To Tubing Hanger Held PJSM - Make Up Free Point Tools And RIH To 1,500' Take Free Point Readings At 1,500' - Stage In Hole Taking Free Point Readings: 3 1/2" Tubing String Found To Have 82% Movement At 4,125' Held PJSM - POH With Free Point Tools From 4,125' And Lay Down Same Held PJSM - Make Up String Shot Tools RIH With String Shot And E-Line Tools To 4,290' - Log Up And Position Strip String Shot From 4,112' To 4,128' - Fire String Shot And POH All Shots Fired Held PJSM - Make Up Chemical Cutter E-Line Tools RIH With 2.375 0.0. Chemical Cutter And E-Line Tools To 2,148' Set Down At SSSV - POH With Chemical Cutter Due To Reduced 1.0. Sleeve (2.31) In SSSV Order 2.1250.0. Chemical Cutter From Schlumberger Yard RIH With Chemical Cutter To 4,125' - Pull 30K Over On Tubing String - Cut 31/2" Tubing At 4,125' - Notice 2K Reduction On Weight Indicator POH With Chemical Cutter Hung Up At 2,908' - Attempt To Free With Circulation Down Tubing - Continue To Work 3 1/2" Tubing At 155K - Tubing Came Free String Up Weight At 70K Monitor Well Bore Static - Circulate Bottoms Up At 9.6 BPM With 1 ,270 Psi. While Circulating Chemical Cutter Released At 2,908' - POH With Schlumberger E-Line - Hold PJSM And Lay Down Chemical Cutter Held PJSM - Rig Down Schlumberger Tools And Equipment Held PJSM - Lay Down Lubricator And Side Door Entry Sub - Clear Rig Floor Held PJSM - Rig Up 31/2" Casing Tools And Control Line Spooling Unit Held PJSM - Lay Down FMC Tubing Hanger And 3 1/2" Landing Joint - POH Laying Down 3 1/2" Tubing Completion Assembly From 4,125' (Top Of Fish) *NOTE* When Removing Chemical And SSSV Control Line Clamps Gravel Was On The Inside On Top Of The Couplings. 6 Stainless Steel Bands Recovered For SSSV 125 Clamps Recovered For Chemical Injection Line 5.5 0.0. 4 Modified Clamps Recovered For Chemical Injection Line 6.1250.0 127 Joints Of 3 1/2" Tubing 1 GLM With Pup Joints Top And Bottom - Perforations In Top Pup Joint 1 SSSV With Pup Joints Top And Bottom Printed: 8/4/2003 9:24:56 AM ) ) SF> ·.E2XP t.ORA-lION Opêrafiol"ls·.·.SØn1rnªry·Repørt 1 Cut Off Joint 15.96' Long Held PJSM - Rig Down 3 1/2" Casing Tools And Control Line Spooling Unit - Clear Rig Floor Wash And Clean Same Held PJSM - Install BOP Test Plug - Test Annular, Top And Bottom Pipe Rams With 4" Drill Pipe At 250 Psi. Low And 3,500 Psi. High Held PJSM - .Install Wear Bushing And Energize LDS Pick Up And Make Up BHA No.1 - Baker Over Shot And Jarring Assembly - RIH To 321' Pick Up (54) Singles Of 4" Drill Pipe And RIH With BHA No.1 From 321' To 2,015' RIH With BHA No.1 On 4" Drill Pipe From Mast From 2,015' To 3,505' Slip And Cut 1 1/4" Drilling Line, Service Top Drive And Traveling Blocks RIH With BHA No.1 On 4" Drill Pipe From Mast From 3,505' tagged at 3,765' w/ 10K Wash Down f/ 3,765' To 4,123' Pumping Sweeps w/ 162 spm, 400 gpm, 650 psi, 65 RPM, Rotary Torque 4000# - Up Weight 110,000# - Down Weight 110,000# - Rotating Weight 110,000# - Occasional Increase In Flow From 33% To 44% Monitor Well Gas Breaking Out At Bell Nipple Circulate Bottoms Up At Reduced Rate As Needed w/ 104 spm, 262 gpm, 300 Psi DECaMP Engage Top Of Fish At 4,123' (Bottom Of Fish At 6,643' WLM) - Maximum Up Weight Pulled At 200,000# - Unable To Circulate Thru Fish DECaMP POH With 31/2" Tubing Fish From 4,123' To 3,602' Attempting To Circulate Thru Fish (No Good) Up Weight 140,000# - POH From 3,602' To 3,218' (Bottom Of Fish At 5,738') - Fluids Starting To Flow Out Drill Pipe Shut In Well - Record Shut In Pressures Drill Pipe At 230 Psi. And Casing At 20 Psi. - Allow Well To U-Tube - Bled Off 5 Barrels And Monitor Well (Stable) POH With 3 1/2" Tubing Fish From 3,602' To 883' (Bottom Of Fish At 3,403') Circulate At 8 BPM With 330 Psi. Observe Flow Increase- Shut In Well - Record Shut In Pressures Drill Pipe At 20 Psi. And Casing At 50 Psi. - Circulate Out Gas Thru Choke Manifold And Poor Boy Degasser At 3 BPM With 130 Psi. Circulate At 8 BPM With 400 Psi. - Increase Mud Weight From 8.4 PPG To 8.6 PPG - Monotor Well (Stable) POH With 3 1/2" Tubing Fish From 883' To 321' (Bottom Of Fish At 2,841') - Monitor Well Bore (Stable) POH With BHA No.1 - Stand Back 8" Drill Collars - Lay Down Baker Fishing Tools Held PJSM - Break Down Baker Fishing Tool Over Shot Held PJSM - Rig Up Tools And Equipment To Lay Down 3 1/2" Tubing Fish Held PJSM - POH From 2,520' Laying Down 3 1/2" Tubing Fish - Due To Chemical Injection Control Line Wrapped Around Tubing And Wadded Up With Control Line Clamps Packed Off With Sand Laying Down This Fish Is A Slow Process - Exterior Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-23 15-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES FrOm -To Hours Task Code N PT Phase 7/11/2003 13:00 - 21 :00 8.00 PULL P DECaMP 21 :00 - 22:30 1.50 PULL P DECOMP 22:30 - 23:30 1.00 BOPSURP DECaMP 23:30 - 00:00 0.50 BOPSURP DECaMP 7/12/2003 00:00 - 02:00 2.00 FISH P DECOMP 02:00 - 03:30 1.50 FISH P DECOMP 03:30 - 04:00 0.50 FISH P DECaMP 04:00 - 05:00 1.00 FISH P DECaMP 05:00 - 05:30 0.50 FISH P DECaMP 05:30 - 10:30 5.00 FISH P DECaMP 10:30 - 11 :00 0.50 FISH P 11 :00 - 13:00 2.00 FISH P 13:00 - 15:00 2.00 FISH P DECaMP 15:00 - 17:00 2.00 FISH P DECaMP 17:00 - 19:30 2.50 FISH P DECaMP 19:30 - 22:30 3.00 FISH P DECaMP 22:30 - 23:00 0.50 FISH P DECaMP 23:00 - 00:00 1.00 FISH P DECaMP 7/13/2003 00:00 - 00:30 0.50 FISH P DECaMP 00:30 - 01 :15 0.75 FISH P DECaMP 01: 15 - 07:00 5.75 FISH P DECaMP Start: 7/9/2003 Rig Release: 7/28/2003 Rig Number: Spud Date: 11/24/1991 End: 7/28/2003 Description Of Operations Printed: 8/4/2003 9:24:56 AM ') ) E3P..·EE)(~L(D)RA[ION °iperåtiol1s·...Syl'l'ln1ét.rj·..Repørt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-23 15-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/9/2003 Rig Release: 7/28/2003 Rig Number: Spud Date: 11/24/1991 End: 7/28/2003 N PT Phase Description of Operations 7/13/2003 01 :15 - 07:00 5.75 FISH P DECaMP Of Tubing Covered In Sand From 4,125' To 4,425' (10 Joints) And With Cement Sheath From 4,425' To 6,643' (67 Joints) *NOTE* Recovered Items: 77 Joints 3 1/2" L-80 9.3 lb. Tubing 1 Partial Cut Off Joint Length At 17.00 2 GLM With Pup Joints Top And Bottom 4 Stainless Steel Control Line Bands 78.5 Chemical Injection Control Line Clamps Junk Left In Hole: Half Of Control Line Clamp, Several Pieces Of 3/8" Control Line +/- 30 Stainless Steel Bands Unaccounted For 07:00 - 08:00 1.00 FISH P DECaMP Held PJSM - Rig Down Casing Tools And Equipment - Rig Down Control Line Spooling Unit - Clear Rig Floor 08:00 - 09:30 1.50 CLEAN P DECaMP Held PJSM - Make Up BHA NO.2 To 965' 09:30 - 11 :00 1.50 CLEAN P DECaMP Held PJSM - RIH With BHA No.2 From 965' To 3,685' 11 :00 - 15:30 4.50 CLEAN P DECaMP Held PJSM - Wash And Ream From 3,685' Tagged Up On Obstruction At 4,210'. Unable To Work Passed. WOB Rotating 2,000# To 15,000#, RPM 75, Torque Off Bottom 2,000 ft / Ibs - On Bottom 3,000 ft I Ibs To 6,000 ft / Ibs, Pump Rate 515 gpm, SPP 670 psi, String Weight Up 130,000#, String Weight Down 130,000#, String Weight Rotating 130,000# 15:30 - 16:30 1.00 CLEAN P DECaMP Circulate Hi-Vis Sweep From Surface To Surface At 7 BPM 360 Psi. - Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive 16:30 -17:30 1.00 CLEAN P DECaMP Held PJSM - POH With BHA No.2 From 4,210' To 965' - Monitor Well Bore (Static) 17:30 - 19:30 2.00 CLEAN P DECaMP Held PJSM - Stand Back 5" HWDP And 61/2" Drill Collars - Lay Down Baker Clean Out Tools And Remove 8 1 /2" Bit - Clean Out Boot Baskets - Clear And Clean Rig Floor 19:30 - 20:30 1.00 EVAL P DECaMP Held PJSM - Make Up Haliburton Circulation Sub And RTTS Tool - RIH With BHA No.3 To 691' 20:30 - 22:00 1.50 EVAL P DECaMP Held PJSM - RIH With BHA No.3 From 691' To 4,200' - Set Haliburton RTTS Tool 22:00 - 22:30 0.50 EVAL P DECaMP Held PJSM - Test 9 5/8" Casing At 3,500 Psi. Record On Circle Chart For 30 Minutes (Test Good) 22:30 - 00:00 1.50 EVAL P DECaMP Held PJSM - POH With BHA No.3 From 4,200' To 691' 7/14/2003 00:00 - 01 :00 1.00 EVAL P DECaMP Held PJSM - POH With BHA No.3 - Lay Down Haliburton RTTS - Clear Rig Floor 01 :00 - 02:30 1.50 EVAL P DECaMP Held PJSM - Rig Up Schlumberger - Install Lubricator - Make Up Logging Tools 02:30 - 04:00 1.50 EVAL P DECaMP Logging With Schlumberger Run NO.1- RIH With GR- CCL- 8.5 Gauge Ring - And Junk Basket To 4,139' (WLM) - Set Down 3 Times With Junk Basket - POH Junk Basket Was Empty - Lay Down Tools 04:00 - 06:00 2.00 EVAL P DECaMP Logging With Schlumberger Run No.2 - Make Up Haliburton EZSV - RIH With GR- CCL - CPST - Haliburton EZSV Packer - Set EZSV At 4,100' (WLM) - POH 06:00 - 07:00 1.00 EVAL P DECaMP Held PJSM - Lay Down Logging Tools - Rig Down Printed: 8/4/2003 9:24:56 AM ) ) Schlumberger And Lubricator - Clear Rig Floor Held PJSM - Test 9 5/8" Casing At 3,500 Psi. Record On Circle Chart For 10 Minutes (Test Good) Held PJSM - Make Up BHA No.4 - Pick Up Bottom Trip Anchor 9 5/8" Whipstock - Make Up Milling Assembly And Orient - RIH With BHA No.4 To 1,001' Held PJSM - RIH With BHA No.4 From 1,001' To 4,080' Held PJSM - Rig Up Sperry Sun Wire Line And Gyrodata Tools And Equipment Held PJSM - Orient 9 5/8" Whipstock To 137 Degrees Azmith With Gryo - Set Bottom Trip Anchor On EZSV At 4,098' With 25,000 Ibs. Shear Whipstock Lug With 45,000 Ibs. Held PJSM - Rig Down Sperry Sun Wire Line And Gyrodata Tools And Equipment Held PJSM - Displace Well To 9.2 PPG LSND Milling Fluid At 13 BPM With 1,280 Psi. - Clean Under Shakers Milling 95/8" Window At 137 Degrees Azmith From 4,074' Top Of Window To 4,090' Bottom Of Window - WOB Rotating 2,000# To 5,000# While Milling Window And 5,000# To 8,000# While Milling Formation, RPM 65 To 95, Rotary Torque 4,000 ft / Ibs To 6,000 ft / Ibs, Pump Rate 463 gpm, SPP 934 psi, String Weight Up 125,000#, String Weight Down 125,000#, String Weight Rotating 125,000# - Drill Formation From 4,090' To 4,104' To Get Upper String Mill Out Of Window - Recovered 180 Ibs. Of Metal WEXIT Work String Mills In And Out Of Window While Circulating Sweep Around At 11 BPM With 940 Psi. WEXIT Hold Pre-Job Safety Meeting - Preform FIT To 12.03 PPG EMW Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-23 15-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Hours Task Code N AT Phase 7/14/2003 06:00 - 07:00 1.00 EVAL P DECaMP 07:00 - 07:30 0.50 EVAL P DECOMP 07:30 - 09:30 2.00 STWHIP P WEXIT 09:30 - 11 :30 2.00 STWHIP P WEXIT 11 :30 - 12:00 0.50 STWHIP P WEXIT 12:00 - 14:00 2.00 STWHIP P WEXIT 14:00 - 14:30 0.50 STWHIP P WEXIT 14:30 - 15:30 1.00 STWHIP P WEXIT 15:30 - 22:00 6.50 STWHIP P WEXIT 22:00 - 22:30 0.50 STWHIP P 22:30 - 23:00 0.50 EVAL P 23:00 - 23: 15 0.25 STWHIP P WEXIT 23:15 - 00:00 0.75 STWHIP P WEXIT 7/15/2003 00:00 - 00:30 0.50 STWHIP P WEXIT 00:30 - 02:30 2.00 STWHIP P WEXIT Start: 7/9/2003 Rig Release: 7/28/2003 Rig Number: Spud Date: 11/24/1991 End: 7/28/2003 Description of Operations Closed Top Pipe Rams And Performed FIT. Strokes Pmp'd Pressure 2 50 psi 4 123 psi 6 204 psi 8 340 psi 10 446 psi 12 580 psi 13 620 psi Held Test F/ 10 minutes w/ 100 Psi. Pressure Loss. MW 9.1 ppg, Top Of Window TVD 4,074' Pressure 620 psi = 12.03 PPG. EMW. Bleed Pressure To 0 Psi. - Open Top Pipe Rams Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive Held PJSM - POH With BHA No.4 From 4,050' To 2,110' - Test Choke Manifold At 250 Psi. Low And 3,500 Psi. High During Trip Out Of The Hole Held PJSM - POH With BHA No.4 From 2,110' To 1,001' Held PJSM - Stand Back BHA No.4 From 1,001' To 82' - Lay Down UBHO Sub, Bumper Sub, And String Mills - *NOTE* Upper String Mill At 81/2" O.D. - Clear Rig Floor Printed: 8/4/2003 9:24:56 AM ) ') BP EXPLORATION Opê~atiøn$..·.$LJrnl1'lar'Y...R~p()r1: Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-23 15-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/9/2003 Rig Release: 7/28/2003 Rig Number: Spud Date: 11/24/1991 End: 7/28/2003 7/15/2003 02:30 - 03:00 0.50 BOPSURP LNR1 Held PJSM - Remove Wear Bushing - Pick Up Johnny Wacker And Flush Out BOP Stack - Lay Down Flushing Tool- Recovered Additional 5 Ibs. Metal From BOP Stack And Under Shakers - Total Metal Recovered 185 Ibs. 03:00 - 07:00 4.00 BOPSURP LNR1 Hold Pre-Job Safety Meeting - Install Test Plug - Rig Up Testing Equipment - Test BOP And Related Equipment - Witness Of BOP Test Waived By AOGCC Inspector Jeff Jones - Test Annular, Upper And Lower Pipe Rams, Blind Rams, Manual And HCR Valves On Choke And Kill Lines, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Perform Accumulator Test - Rig Down Testing Equipment 07:00 - 07:30 0.50 BOPSUR P LNR1 Held PJSM - Pull Test Plug - Install Wear Bushing And Energize LDS - Blow Down Choke Manifold And Kill Lines - Clear Rig Floor 07:30 - 10:30 3.00 DRILL C LNR1 Held PJSM - Make Up BHA NO.5 - Pick Up Sperry Sun Motor, Make Up 8 1/2" HTC PDC Bit, Pick Up MWD/LWD Tools - Orient And Initialize MWD/LWD Tools - Make Up UBHO Sub, Pick Up Flex Drill Collars - Surface Test Sperry Sun Equipment - RIH With BHA NO.5 To 1,185' 10:30 - 12:00 1.50 DRILL C LNR1 Held PJSM - RIH With BHA NO.5 - Pick Up 4" Drill Pipe From 1,185' To 2,985' 12:00 - 13:00 1.00 DRILL C LNR1 RIH With BHA NO.5 On 4" Drill Pipe From 2,085' To 4,031' 13:00 - 15:30 2.50 DRILL C LNR1 Held PJSM - Rig Up Sperry Sun Wire Line Unit And Gyrodata Tools And Equipment - Orient And Work Thru Whipstock Window From 4,074' To 4,090' With No Problems 15:30 - 16:00 0.50 DRILL C LNR1 Wash And Ream Under Gage Hole From 4,097' To 4,104' - Directional Drill Ahead From 4,104' To 4,121' - Lost Returns - Hole Taking 108 Barrels Per Hour While Pumping - AST = .54 hrs. 16:00 - 19:00 3.00 DRILL C LNR1 Pull Above Whipstock Window To 4,031' - Static Losses At 30 To 40 BPH - Mix And Pump 20 BBL LCM Pill With 10 PPB Barofibre, 10 PPB Fine Walnut Displace Out Of Bit And Squeeze Away 10 BBL Down Backside Into Open Hole Section - Monitor Well Static Losses At 36 BPH - Reduce Mud Weight To 9.0 PPG - Build 150 BBL Mud Volume And Second 40 BBL LCM Pill With 10 PPB Barofibre, 10 PPB Fine Walnut - Displace Out Of Bit Squeeze Away 32 BBL Down Backside Into Open Hole Section - During Bullheading Operation Starting Pump Pressure At 120 Psi And Climbed To 320 Psi - Shut Down Pump And Pressure Stabilized At 210 Psi. - Bleed Pressure Off Open Annular And Monitor Well No Static Losses 19:00 - 22:30 3.50 DRILL C LNR1 RIH 4,031' To 4,121' - Establish Circulation And Stage Up Pump Rates To 503 GPM With Very Little Losses - Orient Gryo And Directional Drill Ahead By Sliding From 4,121' To 4,286' WOB Sliding 2,000# To 5,000#, Motor RPM 174, Pump Rate 503 gpm, SPP Off Bottom 1,814 psi, On Bottom 1,930 psi. String Weight Up 135,000#, String Weight Down 135,000#, String Weight Rotating 135,000# - Build To 7 Degrees Angle - Take 30' Surveys With Gryo And MWD Tools - AST = 1.11 hrs. 22:30 - 23:00 0.50 DRILL C LNR1 Held PJSM - POH With BHA NO.5 From 4,286' To 4,031'- Monitor Well Bore Losses At 3 BPH 23:00 - 00:00 1.00 DRILL C LNR1 Held PJSM - Rig Down Gryodata Side Door Entry Sub - POH Printed: 8/4/2003 9:24:56 AM ) ) BP EXPLORATION O.p.e.rctf¡··().·AS·..·S.·Ð..·.m.l'I1·a.Pj...·.Rep.(j.rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-23 15-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES HoÙrs Task Code N PT Phase 7/15/2003 23:00 - 00:00 1.00 DRILL C LNR1 7/16/2003 00:00 - 00:30 0.50 DRILL C LNR1 00:30 - 01 :00 0.50 DRILL C LNR1 01 :00 - 12:00 11.00 DRILL C LNR1 12:00-18:00 6.00 DRILL C LNR1 18:00 - 19:45 1.75 DRILL C LNR1 19:45 - 20:30 0.75 DRILL C LNR1 20:30 - 00:00 3.50 DRILL C LNR1 7/17/2003 00:00 - 16:00 16.00 DRILL C LNR1 16:00 - 17:00 1.00 DRILL C LNR1 17:00 - 19:30 2.50 DRILL C LNR1 19:30 - 20:30 1.00 DRILL C LNR1 20:30 - 00:00 3.50 DRILL C LNR1 Start: 7/9/2003 Rig Release: 7/28/2003 Rig Number: Spud Date: 11/24/1991 End: 7/28/2003 Descri ption of Operations With Sperry Sun Wire Line - Rig Down Sperry Sun Unit Tools And Equipment - Clear Rig Floor Held PJSM - Service Top Drive And Traveling Blocks Held PJSM - RIH With BHA NO.5 From 4,031' To 4,183'- Connect Top Drive Establish Circulation As Precaution Wash To Bottom At 4,286' With No Problems Drilled 8 1/2" Directional Hole By Sliding From 4,286' To 5,117' WOB Sliding 5,000# To 10,000#, Motor RPM 188, Pump Rate 569 gpm, SPP Off Bottom 2,025 psi, On Bottom 2,350 psi. String Weight Up 150,000#, String Weight Down 137,000#, String Weight Rotating 145,000# - Well Bore Losses At 3 BPH - AST = 6.25 hrs. Drilled 8 1/2" Directional Hole By Rotating And Sliding From 5,117' to 5,773' WOB Rotating 5,000# - 10,000#, WOB Sliding 5,000# To 10,000#, RPM 100, Motor RPM 188, Torque Off Bottom 6,000 ft / Ibs - On Bottom 8,000 ft / Ibs, Pump Rate 569 gpm, SPP Off Bottom 2,620 psi, On Bottom 2,900 psi. String Weight Up 160,000#, String Weight Down 135,000#, String Weight Rotating 150,000# - ART = 1.50 hrs. - AST = 2.37 hrs. Monitor Well Bore Static - POH (Wet) With Directional Drilling BHA NO.5 From 5,773' Well Swabbing Pump Out Of The Hole As Needed To 4,031' Monitor Well Bore Static - Wash And Clean Off Rig Floor - RIH With Directional BHA NO.5 From 4,031' To 5,680' With No Problems - As Precaution Wash To Bottom From 5,680' To 5,773' Drilled 8 1/2" Directional Hole By Rotating And Sliding From 5,773' to 6,146' WOB Rotating 5,000# - 10,000#, WOB Sliding 5,000# To 10,000#, RPM 100, Motor RPM 188, Torque Off Bottom 6,000 ft / Ibs - On Bottom 8,000 ft / Ibs, Pump Rate 569 gpm, SPP Off Bottom 2,620 psi, On Bottom 2,900 psi. String Weight Up 170,000#, String Weight Down 130,000#, String Weight Rotating 155,000# - ART = 1.80 hrs. - AST = .30 hrs. Drilled 8 1/2" Directional Hole By Rotating And Sliding From 6,146' to 7,734' WOB Rotating 10,000# - 20,000#, WOB Sliding 10000# To 15,000#, RPM 100, Motor RPM 177, Torque Off Bottom 8,000 ft / Ibs - On Bottom 11,000 ft / Ibs, Pump Rate 540 gpm, SPP Off Bottom 3,050 psi, On Bottom 3,250 psi. String Weight Up 190,000#, String Weight Down 145,000#, String Weight Rotating 157,000# - ART = 7.32 hrs.- AST = 3.57 hrs. Circulate Hi-Vis Sweep At 13 BPM With 3,380 Psi. While Rotating And Reciprocating Drill String Monitor Well Bore Static - POH (Wet) With Directional Drilling BHA NO.5 From 7,734' Well Swabbing Pump Out Of The Hole As Needed To 5,430' Wash And Clean Off Rig Floor - RIH With BHA NO.5 From 5,430' To 7,641' With No Problems - As Precaution Wash From 7,641' To 7,734' Drilled 8 1/2" Directional Hole By Rotating And Sliding From 7,734' to 8,015' WOB Rotating 10,000# - 20,000#, WOB Printed: 8/4/2003 9:24:56 AM ) ) 8PE*PL.OR~TIQN º!~~rati()h$···.SUrrtt'l"lary..··.Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-23 15-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/9/2003 Rig Release: 7/28/2003 Rig Number: Spud Date: 11/24/1991 End: 7/28/2003 !-lours 7/17/2003 20:30 - 00:00 3.50 DRILL C LNR1 7/18/2003 00:00 - 13:00 13.00 DRILL C LNR1 13:00 - 14:30 1.50 DRILL C LNR1 14:30 - 15:30 1.00 DRILL C LNR1 15:30 - 16:00 0.50 DRILL C LNR1 16:00 - 17:30 1.50 DRILL C LNR1 17:30 - 20:30 3.00 DRILL C LNR1 20:30 - 21 :00 0.50 DRILL C LNR1 21 :00 - 22:00 1.00 DRILL C LNR1 22:00 - 23:45 1.75 DRILL C LNR1 23:45 - 00:00 0.25 DRILL C LNR1 7/19/2003 00:00 - 02:00 2.00 DRILL C LNR1 Sliding 10000# To 15,000#, RPM 100, MotorRPM 177, Torque Off Bottom 8,000 ft / Ibs - On Bottom 11,000 ft / Ibs, Pump Rate 540 gpm, SPP Off Bottom 3,050 psi, On Bottom 3,250 psi. String Weight Up 210,000#, String Weight Down 150,000#, String Weight Rotating 175,000# ART = 1.62 hrs. - AST = 0 hrs. - Raise Mud Weight From 9.3 PPG To 9.8 PPG Drilled 8 1/2" Directional Hole By Rotating And Sliding From 8,015' to 8,985' Casing Depth - WOB Rotating 15,000# - 20,000#, WOB Sliding 15,000# To 18,000#, RPM 90 To 100, Motor RPM 179, Torque Off Bottom 9,000 ft / Ibs - On Bottom 13,000 ft I Ibs, Pump Rate 543 gpm, SPP Off Bottom 3,520 psi, On Bottom 3,780 psi. String Weight Up 225,000#, String Weight Down 150,000#, String Weight Rotating 180,000#- Increase In Gas Raise Mud Weight From 9.8 PPG To 10.1 PPG - ART = 4.60 hrs. - AST = 3.49 hrs. Formation Tops: MD TVD SV1 4,115' 4,115' UG4 4,615' 4,605' UG4A 4,648' 4,637' UG1 5,495' 5,386' CM3 6,550' 6,243' CM2 7,090' 6,693' CM1 7,937' 7,409' THRZ 8,242' 7,670' BHRZ 8,458' 7,849' LCU/T JC 8,470' 7,858' JB 8,773' 8,114' TSGR PROJECTED 8,985' 8,300' Circulate Sweep Around At 12.9 BPM With 3,520 Psi. While Rotating And Reciprocating Drill String - Monitor Well Bore Static Held PJSM - POH (Wet) With Directional Drilling BHA NO.5 From 8,985' Well Swabbing Pump Out Of The Hole As Needed To 8,570' - Continue To POH To 8,015' RIH With BHA No.5 From 8,015' To 8,943' - As Precaution Wash From 8,943' To 8,985' - 10' Fill On Bottom Circulate Sweep Around At 12.9 BPM With 3,520 Psi. While Rotating And Reciprocating Drill String - Raise Mud Weight From 10.1 PPG To 10.2 PPG - Monitor Well Bore Static Held PJSM - POH (Wet) With Directional Drilling BHA NO.5 From 8,985' To 3,999' With No Hole Problems - Monitor Well Bore Static - Clean And Wash Off Rig Floor Held PJSM - Service Top Drive, Traveling Blocks, And Crown Sheaves Held PJSM - Slip And Cut 1 1/4" Drilling Line Held PJSM - RIH With Directional Drilling BHA No.5 From 3,999' To 8,943' With No Hole Problems - As Precaution Wash From 8,943' To 8,985' - No Fill On Bottom Circulate Sweep Around At 12.9 BPM With 3,520 Psi. While Rotating And Reciprocating Drill String Circulate Sweep Around Until Hole Clean At 12.9 BPM With Printed: 8/4/2003 9:24:56 AM ) ) BPEX1P1..0RA-r10N Q.p.e.,.at¡·().l"Is··..·S·u..rn.·m··ét.ff¡.····Re·p.e.rtt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-23 15-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES NPT Phäse 7/19/2003 00:00 - 02:00 2.00 DRILL C LNR1 02:00 - 02:30 0.50 DRILL C LNR1 02:30 - 06:00 3.50 DRILL C LNR1 06:00 - 09:30 3.50 DRILL C LNR1 09:30 - 10:30 1.00 BOPSURC LNR1 10:30 - 11 :00 0.50 BOPSURC LNR1 11:00-11:30 0.50 BOPSUR C LNR1 11 :30 - 12:00 0.50 BOPSURC LNR1 12:00 - 13:00 1.00 CASE C LNR1 13:00 - 19:00 6.00 CASE C LNR1 19:00 - 19:30 19:30 - 21 :00 0.50 CASE C 1.50 CASE C LNR1 LNR1 21 :00 - 22:30 1.50 CASE C LNR1 22:30 - 23:00 0.50 CASE C LNR1 23:00 - 00:00 1.00 CEMT C LNR1 7/20/2003 00:00 - 00:15 0.25 CEMT C LNR1 00:15 - 02:00 1.75 CEMT C LNR1 02:00 - 02:30 0.50 CASE C LNR1 Start: 7/9/2003 Rig Release: 7/28/2003 Rig Number: Spud Date: 11/24/1991 End: 7/28/2003 3,520 Psi. While Rotating And Reciprocating Drill String - Monitor Well Bore Static Spot Liner Running Pill In Open Hole Section - Monitor Well Bore Static Held PJSM - POH With BHA No.5 From 8,985' To Window With No Problems - Monitor Well Bore Static - POH To 1,185' Held PJSM - Lay Down 8 1/2" Directional Drilling Assembly BHA No.5 - Clear Rig Floor Held PJSM - Change Out Pipe Rams In Top BOP Gate To 7" Held PJSM - Pull Wear Bushing And Install Test Plug - Rig Up Testing Equipment Held PJSM - Test 7" Rams At 250 Psi. Low And 3,500 Psi. High (Good Test) Held PJSM - Rig Down Testing Equipment - Pull Test Plug - Install Wear Bushing And Energize Lock Down Studs Held PJSM - Rig Up Casing Tools And Equipment Held PJSM - Pick Up And RIH With Shoe Track - Baker Lock Connections To Landing Collar Joint No.3 - Verify Floats Holding - RIH With 100 Joints Of 7" BTC-M 26 lb. L-80 Casing To 4,055' - Make Up Torque To 8,200 ftJlbs. Held PJSM - Circulate 7" Liner Volume At 7 BPM With 600 Psi. Held PJSM - RIH With Total Of 131 Joints Of 7" BTC-M 26 lb. L-80 Casing And Baker 9 5/8" Liner Hanger With ZXP Packer To 5,351' - 7" Liner Up Weight At 160K And Down Weight At 140K Held PJSM - Pick Up Cross Over And Drill Pipe Pup Joint - Rig Down Casing Tools And Equipment - Clear Rig Floor - RIH With 7" Liner On 4" Drill Pipe From 5,351' To 8,955' While Filling Drill Pipe On The Run Held PJSM - Pick Up Baker Cement Head - Install Manifold And Circulating Lines - Establish Circulation At 1 BPM With 420 Psi And Full Returns - Wash To Bottom At 8,985' Stage Up Pumping Rates From 1 BPM With 420 Psi. To 6.5 BPM With 1,107 Psi. - Condition Mud With No Pipe Movement And Full Returns Circulate And Condition Mud With 7" Liner At 8,985' - Pump Rate At 6.5 BPM With 1,107 Psi. - No Pipe Movement And Full Returns Held PJSM With All Personal Regarding Cementing Operation - Shut Down And Turn Over To Dowell - Pump 5 BBLS Water - Test Surface Lines And Equipment To 4,500 Psi. (Test Good) - Clear Lines With Mud Push Prior To Going Down Hole - Pump 35 BBLS 11.0 PPG Mud Push, Followed With 154 BBS (364 Sacks) 12.0 PPG Lead Cement At 5 BPM, 20 BBLS (97 Sacks) 15.8 PPG Class "G" Tail Cement At 5 BPM - Wash Up Lines To Floor - Drop Dart And Displace With 10.2 PPG LSND Mud At 6.7 BPM With 939 Psi. - Slow Rate And Latch Liner Wiper Plug With 35.5 BBLS Pumped Away - Increase Rate To 6.4 BPM Continue To Displace - Slow Rate To 3.1 BPM With Final Circulating Pressure At 984 Psi. - Bump Plug With A Total Of 239 BBLS Pumped - Cement In Place At 02:01 Hours Held PJSM - Increase Pressure To 2,500 Psi. To Set Baker Liner Hanger - Pressure Up To 4,000 Psi. To Set Packer- Printed: 8/4/2003 9:24:56 AM ) ) BPE><FJEORATI<DN Opératiol1s· .SUrt1111ªrý.··.·.Rep()rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-23 15-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/9/2003 Rig Release: 7/28/2003 Rig Number: Spud Date: 11/24/1991 End: 7/28/2003 HOUrs Task 7/20/2003 02:00 - 02:30 0.50 CASE C LNR1 02:30 - 03:00 0.50 CASE C LNR1 03:00 - 03:30 0.50 CASE C LNR1 03:30 - 05:00 1.50 CASE C LNR1 05:00 - 06:00 1.00 BOPSURP LNR1 06:00 - 06:30 0.50 BOPSUR P LNR1 06:30 - 07:00 0.50 BOPSUR P LNR1 07:00 - 09:30 2.50 DRILL P PROD1 09:30 - 12:30 3.00 DRILL P PROD1 12:30 - 14:00 1.50 DRILL P PROD1 14:00 - 14:30 0.50 DRILL P PROD1 14:30 - 15:00 0.50 DRILL P PROD1 15:00 - 16:00 1.00 EVAL P PROD1 16:00 - 18:30 2.50 DRILL P PROD1 18:30 - 21 :00 2.50 DRILL P PROD1 21 :00 - 22:00 1.00 DRILL P PROD1 22:00 - 22:30 0.50 DRILL P PROD1 Bleed Off Pressure And Check Floats (Floats Held) - Rotate 15 Turns To The Right And Release From Liner - Pressure Up Down Drill Pipe To 1,000 Psi. And Unsting Cups - Circulate Bottoms Up At Maximum Rate 13 BPM With 2,644 Psi. - Contaminated Mud Push Back To Surface PH Went From 8.0 To 11.1 With Mud Weight At 11.8 PPG - Estimated Lead Cement Volume Back To Surface At 15 BBLS Held PJSM - Break Down Circulating Lines And Lay Down Baker Cementing Head - Mix Dry Job And Clean Under Shakers Held PJSM - Pump Dry Job And Blow Down Top Drive Held PJSM - POH With Baker 7" Liner Running Tool From 3,644' - Clear Rig Floor Held PJSM - Change Out Pipe Rams In Top BOP Gate To 3 1/2" By 6" Variables Held PJSM - Pull Wear Bushing And Install Test Plug - Rig Up Testing Equipment - Test 3 1/2" X 6" Variables To 250 Psi. Low And 3,500 Psi. High (Good Test) Held PJSM - Rig Down Testing Equipment And Pull Test Plug - Install Wear Bushing And Energize Lock Down Studs Held PJSM - Make Up BHA NO.6 - Pick Up Sperry Sun Motor, Make Up 6 1/8" Smith XR20 nsert Bit, Pick Up MWD/LWD Tools - Orient And Initialize MWD/LWD Tools - Pick Up (1) Flex Drill Collar - Surface Test Sperry Sun Equipment - Hold PJSM And Install Nuke Sources Lower Below Rig Floor - Pick Up (2) Flex Drill Collars, Daily Mechanical Jars, Circulating Sub, And Cross Over Sub To 230' Held PJSM - RIH With Directional Drilling Assembly BHA NO.6 Picking Up 4" Drill Pipe From 230' To 4,522' Held PJSM - RIH With BHA No.6 From 4,522' To 8,642' Held PJSM - Service Top Drive, Traveling Blocks, And Crown Sheaves Held PJSM - RIH With BHA NO.6 From 8,642' To 8,897' Held PJSM - Test 9 5/8" Casing, 7" Liner Top Packer, And 7" Casing At 3,500 Psi. Record On Circle Chart For 30 Minutes (Test Good) Held PJSM - Tag Baker Landing Collar At 8,897' - Drill Landing Collar And Wiper Plugs - Drill Cement To Float Collar At 8,940' - Drill Cement To Float Shoe At 8,985' Held PJSM - Change Over Mud System - Pump Spacer, 100 BBLS Water, Spacer, Followed Up With 8.6 PPG QuickDriln Mud - Clean Under Shakers Drill 6 1/8" Hole From 8,985' To 9,005' - Pull Into Casing Hold Pre-Job Safety Meeting - Preform FIT To 9.5 PPG EMW Closed Top Pipe Rams And Performed FIT. Strokes Pmp'd Pressure 2 90 psi 4 160 psi 6 230 psi 8 300 psi 10 370 psi 11 390 psi Printed: 8/4/2003 9:24:56 AM ) ) BPEEXPl..ORA"flON Oþé..éltiol1s···.·~l.Immª.Pl····.Rêp.ort Held Test F/ 10 minutes w/ 10 Psi. Pressure Loss. MW 8.65 ppg, 7" Casing Shoe TVD 8,922' Pressure 390 psi = 9.5 PPG. EMW. Bleed Pressure To 0 Psi. - Open Top Pipe Rams PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 9,005' to 9,055' WOB Rotating 5,000# - 15,000#, WOB Sliding 5,000# To 10,000#, RPM 60, Motor RPM 82, Torque Off Bottom 4,000 ft / Ibs - On Bottom 5,000 ft / Ibs, Pump Rate 250 gpm, SPP Off Bottom 1,600 psi, On Bottom 1,740 psi. String Weight Up 165,000#, String Weight Down 145,000#, String Weight Rotating 155,000# - ART = 1.71 hrs. - AST = .29 hrs. PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 9,055' to 9,296' WOB Rotating 5,000# - 15,000#, WOB Sliding 5,000# To 10,000#, RPM 60, Motor RPM 82, Torque Off Bottom 4,000 ft / Ibs - On Bottom 5,000 ft / Ibs, Pump Rate 250 gpm, SPP Off Bottom 1,600 psi, On Bottom 1,740 psi. String Weight Up 165,000#, String Weight Down 145,000#, String Weight Rotating 155,000# - Rig Up Solids Control Van And Start Mud Cleaner - Well Bore Taking Fluid At 20 To 25 BPH - String In Barafibre To Control Losses - Mixing 20 BBL Calcium Carbonate Pill At 20 Pounds Per Barrel - ART = 4.29 hrs. - AST = .69 hrs. Spot 20 BBL LCM Pill (10 PPB Baracarb 50 And 10 PPB Baracarb 5) - POH From 9,296' To 8,981' - Static Loss Rate At 2 BPH Held PJSM - Squeeze 7.5 Barrels Of LCM Pill Into Formation At 1/4 BPM - Repeat Squeeze Process Until Formation Holding 500 Psi. Held PJSM - RIH From 8,981' To 9,296' - Establish Circulation Loss Rate At 18 BPH Drilled 6 1/8" Directional Hole By Rotating And Sliding From 9,296' to 9,870' WOB Rotating 20,000# - 24,000#, WOB Sliding 10,000# To 15,000#, RPM 70, Motor RPM 82, Torque Off Bottom 4,000 ft / Ibs - On Bottom 6,000 ft / Ibs, Pump Rate 250 gpm, SPP Off Bottom 1,700 psi, On Bottom 1,840 psi. String Weight Up 178,000#, String Weight Down 145,000#, String Weight Rotating 162,000# - ART = 5.73 hrs. - AST = 4.59 hrs. PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 9,870' to 1 0,137' WOB Rotating 20,000# - 24,000#, WOB Sliding 10,000# To 15,000#, RPM 70, Motor RPM 82, Torque Off Bottom 4,000 ft / Ibs - On Bottom 6,000 ft / Ibs, Pump Rate 250 gpm, SPP Off Bottom 1,700 psi, On Bottom 1,840 psi. String Weight Up 178,000#, String Weight Down 145,000#, String Weight Rotating 162,000# - ART = 4.44 hrs. - AST = 2.12 hrs. Circulate Bottoms Up At 250 GPM With 1,650 Psi. - Spot 40 Barrel LCM Pill - Monitor Well Bore (Static) Held PJSM - POH With Directional Drilling BHA No.6 From 10,137' To 8,922' With No Hole Problems Drop Dart And Open Circulation Sub - Circulate Bottoms Up At Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-23 15-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Ðåtè FrOm-To Hours Task Code NPT Phase 7/20/2003 22:00 - 22:30 0.50 DRILL P PROD1 22:30 - 00:00 1.50 DRILL P 7/21/2003 00:00 - 06:30 6.50 DRILL P 06:30 - 07:00 0.50 DRILL P PROD1 07:00 - 08:00 1.00 DRILL P PROD1 08:00 - 08:30 0.50 DRILL P PROD1 08:30 - 00:00 15.50 DRILL P PROD1 7/22/2003 00:00 - 09:00 9.00 DRILL P 09:00 - 10:00 1.00 DRILL P PROD1 10:00 - 10:30 0.50 DRILL P PROD1 10:30 - 11 :30 1.00 DRILL P PROD1 Start: 7/9/2003 Rig Release: 7/28/2003 Rig Number: Spud Date: 11/24/1991 End: 7/28/2003 Dèsc:ri ption·ofOperåtiöns Printed: 8/4/2003 9:24:56 AM '" ) ) E3P E><Pl...0R.fXTION Op~ rélti()ns·..·.Sllmmäl¥..·~épºrt Legal Well Name: 15-23 Common Well Name: 15-23A Spud Date: 11/24/1991 Event Name: REENTER+COMPLETE Start: 7/9/2003 End: 7/28/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/28/2003 Rig Name: NABORS 2ES Rig Number: HÖUrs Task COde NPT Phase Description of Operations 7/22/2003 10:30-11:30 1.00 DRILL P PROD1 13 BPM With 1,700 Psi. - Remove Blower Hose - Monitor Well Bore (Static) - Pump Dry Job 11 :30 - 14:30 3.00 DRILL P PROD1 POH With BHA No.6 From 8,922' To 230' - Test Choke Manifold On Trip Out Of The Hole At 250 Psi. Low And 3,500 Psi. High 14:30 - 15:30 1.00 DRILL P PROD1 Held PJSM - Handle BHA NO.6 - Stand Back BHA - Remove Nukes - Down Load MWD/LWD Data - Remove 61/8" Bit - Lay Down Sperry Sun Mud Motor - Clear Rig Floor 15:30 - 16:00 0.50 BOPSUR P PROD1 Held PJSM - Remove Wear Bushing - Install Test Plug - Rig Up Testing Equipment 16:00 - 18:00 2.00 BOPSUR P PROD1 Hold Pre-Job Safety Meeting - Test BOP And Related Equipment - Witness Of BOP Test Waived By AOGCC Inspector Chuck Sheave - Test Annular, Upper And Lower Pipe Rams, Blind Rams, Manual And HCR Valves On Choke And Kill Lines, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Perform Accumulator Test - Rig Down Testing Equipment 18:00 - 18:30 0.50 BOPSUR P PROD1 Held PJSM - Pull Test Plug - Install Wear Bushing And Energize LOS - Blow Down Choke Manifold And Kill Lines - Clear Rig Floor 18:30 - 20:00 1.50 DRILL P PROD1 Held PJSM - Make Up BHA NO.7 - Pick Up Sperry Sun Motor, Make Up 61/8" Security PDC Bit, Pick Up MWD/LWD Tools- Orient And Initialize MWD/LWD Tools - Make Up Flex Drill Collars, Dailey Jars, Circ. Sub, And Cross Over Sub - Surface Test Sperry Sun Equipment - RIH With BHA NO.5 To 199' 20:00 - 22:45 2.75 DRILL P PROD1 RIH With BHA NO.5 On 4" Drill Pipe From 199' To 8,891' - Fill Drill String Every 3,000' On Trip In Hole 22:45 - 23:30 0.75 DRILL P PROD1 Held PJSM - Slip And Cut 1 1/4" Drilling Line 23:30 - 00:00 0.50 DRILL P PROD1 Held PJSM - Service Top Drive, Traveling Blocks, And Crown Sheaves 7/23/2003 00:00 - 00:30 0.50 DRILL P PROD1 Held PJSM - RIH With BHA No.7 From 8,891' To 10,030' 00:30 - 01 :00 0.50 DRILL P PROD1 Establish Circulation And Stage Up Pump Rates To 7.1 BPM - As A Precaution Wash And Ream From 10,077' To 10,137' 01 :00 - 12:30 11.50 DRILL P PROD1 Directional drill from 10,137' to 10,853'. ART = 3.41 hrs, AST = 2.34 hrs, ADT = 5.75 hrs P/U weight 178K, S/O weight 145K, Rot weight 162K. Slide / Rotate 716' (10,137' - 10,853') Slide at TF 130 to 160 LHS Flow rate 300 gpm, on btm 2,300 psi, off btm 2,000 psi. WOB 10 - 20 K, ROP 30-80 fph Rotate at 80 RPM Flow rate 280 - 320 gpm, on btm 2,300 psi, off btm 2,000 psi. Torque on btm 6,000; Torque off btm 4,000 WOB 6 -12K, ROP 100 -175 fph 12:30 -13:30 1.00 DRILL N SFAL PROD1 Replace washed out 3/4" nipple at Sperry Sun pressure transducer. 13:30 - 00:00 10.50 DRILL P PROD1 Directional drill from 10,853' to 11,435'. ART = 3.50 hrs, AST = 2.00 hrs, ADT = 5.50 hrs Printed: 8/4/2003 9:24:56 AM ) ) Rotate at 1 00 RPM Flow rate 280 gpm, on btm 2,200 psi, off btm 1,800 psi. Torque on btm 8,000; Torque off btm 5,000 WOB 6 K, ROP 100 -175 fph PROD1 Directional drill from 11,435' to 12,268', ART = 4.69 hrs, AST = 1.42 hrs, ADT = 6.11 hrs Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-23 15-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date FrOm-To Hours Task Cbde NPT Phasé 7/23/2003 13:30 - 00:00 10.50 DRILL P PROD1 7/24/2003 00:00 - 10:00 10.00 DRILL P 10:00 - 11 :30 1.50 DRILL P PROD1 11 :30 - 13:30 2.00 DRILL P PROD1 13:30 -14:30 1.00 DRILL P PROD1 14:30 -15:30 1.00 DRILL P PROD1 15:30 - 17:30 2.00 DRILL P PROD1 17:30 - 19:00 1.50 DRILL P PROD1 19:00 - 19:30 0.50 DRILL P PROD1 19:30 - 22:30 3.00 DRILL P PROD1 22:30 - 00:00 1.50 DRILL P PROD1 7/25/2003 00:00 - 01 :00 1.00 CASE P COMP 01 :00 - 01 :30 0.50 CASE P COMP 01 :30 - 02:00 0.50 CASE P COMP 02:00 - 05:00 3.00 CASE P COMP 05:00 - 07:30 07:30 - 08:00 08:00 - 09:00 09:00 - 09:30 2.50 CASE P 0.50 CASE P 1.00 CASE P 0.50 CASE P COMP COMP COMP COMP Start: 7/9/2003 Rig Release: 7/28/2003 Rig Number: Spud Date: 11/24/1991 End: 7/28/2003 Description of Operations P/U weight 180K, S/O weight 140K, Rot weight 162K. Slide / Rotate 582' (10,853' - 11,435') Slide at TF 120 to 30 LHS Flow rate 280 gpm, on btm 2,250 psi, off btm 1,800 psi. WOB 10 - 15 K, ROP 30-80 fph P/U weight 180K, S/O weight 140K, Rot weight 162K. Slide / Rotate 515' (11,435' - 12,268') Slide at TF 160 LHS to HS Flow rate 280 gpm, on btm 2,050 psi, off btm 1,850 psi. WOB 10 - 15 K, ROP 30-60 fph Rotate at 1 00 RPM Flow rate 280 gpm, on btm 2,200 psi, off btm 1,850 psi. Torque on btm 9,000; Torque off btm 6,000 WOB 6 - 8K, ROP 100 - 170 fph Pump Hi Vis sweep. CBU at 280gpm and 1,950 psi. Monitor well. POOH from 12,268' to 8,981', Overpull of 10 - 20K. Service top drive. Clean rig floor. RIH from 8,981' to 12,268'. Circulate Hi Vis sweep around at 6 1/2 bpm and 1,900 psi. Spot liner running pill. POOH from 12,268' to 8,981'.10 - 20K overpull at 9,930', 9,840', 9,760', and 9,487'. Drop dart and shear open circ sub. Pump dry job. POOH from 8,981' to 199'. UD BHA. Download MWD, break bit. Clear rig floor. Clear rig floor. RlU to run 4 1/2", 12.6#, L-80 liner. PJSM with crew regarding M/U production liner. M/U shoe joints. BakerLok shoe joint connections. Check floats. O.K. M/U 82 joints 41/2", 12.6#, L-80, IBT-M liner to 3,407'. Average M/U torque 3,800 ft-Ibs. Fill pipe on the fly and top off every 5 joints. M/U Baker hanger I packer. P/U one dp single. Circulate liner volume at 6 bpm and 220 psi. RID liner equipment. Liner hanging weight 65K. RIH with 4 1/2" liner on drill pipe from 3,565' to 8,976'. Circulate drill pipe volume at 6 bpm and 670 psi. RIH with 4 1/2" liner on drill pipe from 8,976' to 12,257'. M/U cement head. Tag at 12,268'. Up weight 180K, On weight Printed: 8/4/2003 9:24:56 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-23 15-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/9/2003 Rig Release: 7/28/2003 Rig Number: Spud Date: 11/24/1991 End: 7/28/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/25/2003 09:00 - 09:30 0.50 CASE P CaMP 140K. 09:30 - 11 :30 2.00 CEMT P CaMP Circulate and condition at 5 bpm and 1,000 psi. PJSM regarding cement operation. Batch mix cement slurry. 11 :30 - 12:00 0.50 CEMT P CaMP Swap over to Dowell. Pump 5 bbl water and test lines to 4,500 psi. 12:00 - 13:30 1.50 CEMT P CaMP Pump 20 bbl CW1 00, 30 bbl1 0.0 ppg MudPUSH, and 86 bbl 15.8 ppg 'G' cement. Wash out lines, drop dart, displace with 70 bbl perf pill followed by 68 bl mud. Bump plug on calculated displacement. Increase pressure to 3,500 psi. Bleed off and check floats. Floats held. CIP at 13:00 hours. 13:30 - 14:30 1.00 CEMT P CaMP Release from hanger. Displace well to seawater at 12 bpm and 3,000 psi. Reciprocate pipe. Rotate down on liner top packer and set. Observed late arrival of seawater and CW at surface during CBU. Calculated approximately 140 bbls lost during circulation. No evidence of cement in returns. Good indication of consistent pressure increase during cement displacement. Decided to run CBL to confirm sufficient cement placement prior to tcp perforating. 14:30 - 15:00 0.50 CEMT P CaMP LID rotary cement head. RID circulating lines and manifold. 15:00 - 17:30 2.50 CEMT P CaMP POOH with drill pipe from 8,835' to 1,120'. 17:30 - 18:30 1.00 CEMT P CaMP Service top drive. 18:30 - 20:00 1.50 CEMT P CaMP LID drill pipe, 1 X 1, from 1,120'. LID liner running tool. Clear rig floor. 20:00 - 20:30 0.50 CASE P CaMP M/U muleshoe. RIH with drill pipe from derrick to 2,240'. 20:30 - 22:30 2.00 CASE P CaMP LID 24 stands drill pipe, 1 X 1. RID muleshoe. Clear rig floor. 22:30 - 23:00 0.50 CASE P CaMP Pressure test 9 5/8" X 7" X 4 1/2" casing to 3,500 psi for 30 minutes. 23:00 - 00:00 1.00 CASE P CaMP R/U SWS. 7/26/2003 00:00 - 00:30 0.50 CASE P CaMP PJSM with SWS and crew. 00:30 - 04:30 4.00 EVAL P CaMP RIH with SWS E-line and SCMT. Log interval from 9,900' to 8,800'. TOC located at 9,450'. POOH, RID SWS. 04:30 - 05:00 0.50 PERF P CaMP PJSM with HES and crew regarding tcp perforating. R/U handling equipment. 05:00 - 07:00 2.00 PERF P CaMP P/U and M/U tcp guns to 1,816'. 07:00 - 09:00 2.00 PERF P CaMP M/U 2 7/8" drill pipe from 1,816' to 3,398'. 09:00 - 13:30 4.50 PERF P CaMP cIa handling equipment. RIH with drill pipe from 3,398' to 12,181'. Tag LlC at 12,181' Space out guns. P/U weight 176K, S/O weight 143K. 13:30 - 14:00 0.50 PERF P CaMP PJSM. Increase annulus pressure to 3,200 psi. Good indication guns fired. 14:00 - 15:00 1.00 PERF P CaMP POOH from 12,123' to 10,184'. 15:00 - 15:30 0.50 PERF P CaMP Monitor well at 10,184'. Static loss rate 3 bph. Slug pipe. BID surface equipment. 15:30 - 19:00 3.50 PERF P CaMP LID drill pipe from 10,284' to 3,926'. 19:00 - 19:30 0.50 PERF P CaMP RIH with drill pipe from derrick to 5,886'. 19:30 - 21 :00 1.50 PERF P CaMP Cut and slip drilling line. Service top drive. 21 :00 - 22:30 1.50 PERF P CaMP LID drill pipe from 5,886' to 3,398'. 22:30 - 00:00 1.50 PERF P CaMP R/U 2 7/8" handling equipment. LID 2 7/8" drill pipe from 3,398' to 2,438'. 7/27/2003 00:00 - 01 :00 1.00 PERF P CaMP LID 2 7/8" drill pipe from 2,438' to 1,816'. cIa handling equipment. 01 :00 - 04:00 3.00 PERF P CaMP PJSM. LID tcp guns. All shots fired. Printed: 8/4/2003 9:24:56 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-23 15-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 7/9/2003 Rig Release: 7/28/2003 Rig Number: Spud Date: 11/24/1991 End: 7/28/2003 Code NPT 7/27/2003 04:00 - 07:00 3.00 RUNCOIVP COMP 07:00 - 08:00 08:00 - 19:00 1.00 RUNCOIVP 11.00 RUNCOIVP COMP COMP 19:00 - 20:30 1.50 RUNCOIVP COMP 20:30 - 23:30 3.00 RUNCOIVP COMP 23:30 - 00:00 0.50 RUNCOIVP COMP 7/28/2003 00:00 - 02:00 2.00 RUNCOIVP COMP 02:00 - 04:00 2.00 BOPSURP COMP 04:00 - 06:00 2.00 WHSUR P COMP 06:00 - 07:00 1.00 WHSUR P COMP 07:00 - 07:30 0.50 WHSUR P COMP 07:30 - 09:30 2.00 WHSUR P COMP 09:30 - 10:00 0.50 WHSUR P COMP 10:00 - 11 :00 1.00 RIGD P COMP RID handling equipment. Clear rig floor. Pull wear bushing. R/U to run 41/2",12.6#, 13Cr-80, VAM ACE completion. PJSM with all personnel. P/U tailpipe and Baker S-3 packer. P/U 41/2",12.6#, 13Cr-80, VAM ACE tubing and completion components. Tag at 8,838'. P/U weight 125K, S/O weight 108K. Work string up and down, rotate and work rotation down. String slipped into TBS and bottomed out at 8,845'. Space out tubing with 6 pup joints ( 37.90'). M/U tubing hanger and land same. RILDS. WLEG at 8,841.77' (tubing measurement). R/U circulating lines and pressure test to 4,000 psi. Reverse circulate Seawater and SW with Corrosion Inhibitor at 3 bpm and 250 psi. Drop ball/rod. Set Baker S-3 packer with 3,500 psi. Pressure test tubing to 3,500 psi for 30 minutes and recored test. Bleed tubing pressure to 1,500 psi and pressure test annulus to 3,500 psi for 30 minutes. Record test. Bleed tubing pressure to shear DCK in GLM at 3,200'. Install TWC and test from below to 1,000 psi. N/D BOPE. N/U tree and test to 5,000 psi. R/U DSM and pull TWC. PJSM. R/U Little Red HOT Oil. Reverse circulate 155 bbl diesel for freeze protection to 2,200' at 3 bpm and 1,850 psi. Allow diesel to U-tube. Dry rod in FMC BPV and test from below to 1,000 psi. RID lines, remove secondary annulus valve, secure well. Rig RELEASED at 11 :00 hrs. Printed: 8/4/2003 9:24:56 AM ) AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 15-23A Dear Dear Sir/Madam: ) 24-Aug-03 c903-\ It Enclosed are two survey hard copies and a disk with the *.PTT and *.PDF files. Tie-on Survey: 3,908.40' MD Window / Kickoff Survey: 4,074.00' MD (if applicable) Projected Survey: 12,268.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AUG 29 2.003 Alaska ()j & Gas Cons. Ccmmis!ion Anchorage Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 15 15-23A "-"'" Job No. AKZZ2548429, Surveyed: 24 July, 2003 Survey Report 22 August, 2003 Your Ref: API 500292222501 Surface Coordinates: 5960105.48 N, 676210.75 E (70017' 47.7256" N, 148034' 22.8594" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~ Surface Coordinates relative to Project H Reference: 960105.48 N, 176210.75 E (Grid) Surface Coordinates relative to Structure Reference: 1269.70 N, 57.46 W (True) Kelly Bushing: 60.90ft above Mean Sea Level Elevation relative to Project V Reference: 60.90ft Elevation relative to Structure Reference : 60.90ft 5pe!1'.....y-5UI! bRI L.'LINS··'SERVlc:e's A Halliburton Company Survey Ref: svy4085 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 - 15-23A Your Ref: API 500292222501 Job No. AKZZ2548429, Surveyed: 24 July, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) C/100ft} 3908.40 0.500 116.020 3847.20 3908.10 23.43 S 27.03 E 5960082.69 N 676238.33 E -29.78 Tie On Point AK-6 BP _IFR-AK 4074.00 0.540 109.650 4012.80 4073.70 24.01 S 28.42 E 5960082.14 N 676239.72 E 0.042 -31.23 Window Point 4106.00 2.600 153.200 4044.78 4105.68 24.71 S 28.89 E 5960081 .45 N 676240.21 E 6.999 -31.78 4137.00 3.500 145.800 4075.74 4136.64 26.12 S 29.74 E 5960080.06 N 676241.09 E 3.163 -32.80 4169.00 4.500 111 .700 4107.66 4168.56 27.39 S 31.45 E 5960078.83 N 676242.84 E 7.911 -34.67 .~ 4201.00 5.800 109.600 4139.53 4200.43 28.40 S 34.14 E 5960077.89 N 676245.55 E 4.104 -37.46 4227.67 7.210 117.970 4166.03 4226.93 29.64 S 36.89 E 5960076.72 N 676248.33 E 6.358 -40.34 4260.21 8.720 125.540 4198.26 4259.16 32.03 S 40.70 E 5960074.42 N 676252.19 E 5.641 -44.43 4311.49 10.630 133.610 4248.81 4309.71 37.55 S 47.29 E 5960069.05 N 676258.91 E 4.560 -51.66 4369.67 12.330 139.430 4305.83 4366.73 45.97 S 55.22 E 5960060.82 N 676267.03 E 3.532 -60.59 4405.13 12.810 146.270 4340.44 4401.34 52.12 S 59.86 E 5960054.78 N 676271.82 E 4.408 -65.98 4449.82 13.310 157.920 4383.98 4444.88 61.01 S 64.55 E 5960046.00 N 676276.71 E 5.986 -71.75 4498.71 13.860 170.080 4431.51 4492.41 71 .99 S 67.67 E 5960035.10 N 676280.09 E 5.938 -76.24 4551 .23 14.370 181.580 4482.46 4543.36 84.70 S 68.58 E 5960022.41 N 676281.29 E 5.418 -78.74 4590.39 14.750 188.990 4520.36 4581.26 94.49 S 67.66 E 5960012.61 N 676280.61 E 4.851 -79.08 4627.04 15.070 195.900 4555.78 4616.68 103.68 S 65.63 E 5960003.37 N 676278. 79 E 4.926 -78.22 4658.74 15.450 201.810 4586.36 4647.26 111.56 S 62.93 E 5959995.42 N 676276.28 E 5.049 -76.54 4685.99 15.540 206.710 4612.62 4673.52 118.19 S 59.94 E 5959988.72 N 676273.45 E 4.814 -74.42 4720.07 16.220 213.470 4645.41 4706.31 126.24 S 55.26 E 5959980.57 N 676268.96 E 5.779 -70.80 4750.97 16.650 219.810 4675.05 4735.95 133.24 S 50.05 E 5959973.45 N 676263.91 E 5.966 -66.51 4779.28 17.290 224.470 4702.12 4763.02 139.36 S 44.51 E 5959967.20 N 676258.51 E 5.308 -61.78 4813.46 18.480 230.270 4734.66 4795.56 146.45 S 36.78 E 5959959.93 N 676250.95 E 6.263 -55.02 '-" 4844.38 19.800 236.470 4763.87 4824.77 152.48 S 28.64 E 5959953.72 N 676242.96 E 7.833 -47.71 4872.02 20.170 236.460 4789.84 4850.74 157.69 S 20.77 E 5959948.32 N 676235.21 E 1.339 -40.56 4906.48 19.960 240.940 4822.21 4883.11 163.83 S 10.68 E 5959941.94 N 676225.27 E 4.501 -31.32 4937.92 20.890 244.100 4851.68 4912.58 168.89 S 0.94 E 5959936.66 N 676215.65 E 4.587 -22.31 4965.78 22.280 244.300 4877.58 4938.48 173.35 S 8.28W 5959931.98 N 676206.53 E 4.996 -13.72 5000.28 24.020 249.770 4909.31 4970.21 178.61 S 20.77 W 5959926.43 N 676194.18 E 8.013 -2.00 5029.79 25.150 252.190 4936.14 4997.04 182.61 S 32.37 W 5959922.16 N 676182.67 E 5.128 9.01 5057.45 26.490 253.730 4961.04 5021.94 186.14 S 43.89 W 5959918.37 N 676171.23 E 5.417 19.99 22 August, 2003 - 8:55 Page 2 of 7 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 - 15-23A Your Ref: API 500292222501 Job No. AKZZ2548429, Surveyed: 24 July, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 5152.27 30.500 258.090 5044.37 5105.27 197.03 S 87.76 W 5959906.44 N 676127.63 E 4.762 62.12 5245.87 34.200 262.610 5123.44 5184.34 205.328 137.11 W 5959897.00 N 676078.49 E 4.720 110.03 5340.00 36.490 266.760 5200.22 5261.12 210.31 S 191.31 W 5959890.75 N 676024.43 E 3.524 163.16 5433.15 35.900 266.740 5275.40 5336.30 213.43 S 246.23 W 5959886.34 N 675969.60 E 0.634 217.24 5526.50 35.580 266.480 5351 .17 5412.07 216.65 8 300.66 W 5959881.84 N 675915.25 E 0.379 270.82 ~ 5620.05 35.760 266.600 5427.17 5488.07 219.948 355.11 W 5959877.27 N 675860.90 E 0.206 324.42 5713.52 35.630 267.820 5503.08 5563.98 222.608 409.58 W 5959873.34 N 675806.50 E 0.774 378.12 5807.65 35.490 267.420 5579.65 5640.55 224.87 8 464.27 W 5959869.79 N 675751.88 E 0.288 432.08 5900.45 35.380 267.480 5655.26 5716.16 227.26 8 518.02 W 5959866.13 N 675698.20 E 0.124 485.10 5993.35 35.840 266.530 5730.79 5791.69 230.09 8 572.04 W 5959862.04 N 675644.26 E 0.774 538.32 6087.15 36.720 263.720 5806.41 5867.31 234.82 8 627.33 W 5959856.01 N 675589.10 E 2.005 592.57 6180.27 36.280 263.380 5881.27 5942.17 241.04 S 682.37 W 5959848.50 N 675534.22 E 0.520 646.38 6272.31 35.920 259.620 5955.64 6016.54 249.05 S 735.98 W 5959839.24 N 675480.81 E 2.438 698.55 6366.87 35.280 259.190 6032.53 6093.43 259.178 790.09 W 5959827.86 N 675426.96 E 0.727 750.94 6460.10 35.240 258.630 6108.66 6169.56 269.528 842.90 W 5959816.27 N 675374.40 E 0.349 802.02 6553.12 35.470 258.330 6184.52 6245.42 280.27 S 895.64 W 5959804.29 N 675321.92 E 0.310 852.98 6646.46 34.910 258.160 6260.80 6321.70 291.23 8 948.31 W 5959792.10 N 675269.53 E 0.609 903.83 6738.53 33.830 257.550 6336.80 6397.70 302.16 8 999.12 W 5959779.98 N 675218.99 E 1.231 952.85 6831.13 32.880 257.430 6414.14 6475.04 313.198 1048.82 W 5959767.79 N 675169.56 E 1.028 1000.76 6925.12 33.550 257.050 6492.78 6553.68 324.56 8 1099.04 W 5959755.24 N 675119.62 E 0.746 1049.13 7018.69 32.450 256.540 6571.25 6632.15 336.20 8 1148.65 W 5959742.44 N 675070.30 E 1.212 1096.87 7111.60 30.350 256.190 6650.55 6711.45 347.608 1195.69 W 5959729.94 N 675023.54 E 2.269 1142.09 7206.08 30.600 257.230 6731.98 6792.88 358.62 8 1242.32 W 5959717.83 N 674977.18 E 0.618 1186.96 ~' 7299.42 31.840 259.780 6811.80 6872.70 368.24 S 1289.73 W 5959707.11 N 674930.01 E 1.941 1232.76 7393.96 32.270 260.350 6891.93 6952.83 376.89 8 1339.15 W 5959697.29 N 674880.80 E 0.556 1280.69 7488.88 31.820 260.730 6972.39 7033.29 385.178 1388.83 W 5959687.85 N 674831.33 E 0.519 1328.92 7581.32 31.840 260.250 7050.92 7111.82 393.23 8 1436.91 W 5959678.67 N 674783.45 E 0.275 1375.60 7674.81 32.950 259.010 7129.86 7190.76 402.258 1486.18 W 5959668.50 N 674734.41 E 1.384 1423.32 7769.27 34.910 257.980 7208.24 7269.14 412.78 S 1537.83 W 5959656.76 N 674683.02 E 2.162 1473.24 7862.51 33.880 258.650 7285.17 7346.07 423.45 8 1589.41 W 5959644.88 N 674631.70 E 1.177 1523.05 7956.31 31.250 257.230 7364.22 7425.12 433.97 8 1638.78 W 5959633.20 N 674582.59 E 2.920 1570.69 8050.14 30.930 257.030 7444.57 7505.47 444.77 8 1686.02 W 5959621.31 N 674535.62 E 0.358 1616.18 8144.42 30.350 257.240 7525.69 7586.59 455.468 1732.86 W 5959609.51 N 674489.04 E 0.626 1661.29 8237.34 31 .220 258.750 7605.52 7666.42 465.35 8 1779.38 W 5959598.54 N 674442.77 E 1.252 1706.18 8330.44 34.740 260.000 7683.60 7744.50 474.668 1829.18 W 5959588.06 N 674393.20 E 3.851 1754.41 22 August, 2003 - 8:55 Page 3 of 7 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 - 15-23A Your Ref: API 500292222501 Job No. AKZZ2548429, Surveyed: 24 July, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 o Oft) 8423.03 35.750 260.750 7759.22 7820.12 483.59 S 1881.86 W 5959577.90 N 674340.75 E 1.187 1805.53 8516.00 34.230 260.200 7835.39 7896.29 492.41 S 1934.44 W 5959567.85 N 674288.39 E 1.670 1856.57 8608.98 32.800 261.160 7912.90 7973.80 500.73 S 1985.09 W 5959558.34 N 674237.94 E 1.640 1905.77 8701.59 30.980 260.900 7991.53 8052.43 508.36 S 2033.42 W 5959549.59 N 674189.81 E 1.971 1952.74 8793.70 29.480 261.340 8071.12 8132.02 515.52 S 2079.23 W 5959541 .35 N 674144.17 E 1.646 1997.28 -- ) 8887.15 28.800 260.960 8152.74 8213.64 522.52 S 2124.20 W 5959533.30 N 674099.39 E 0.754 2041.00 8921.84 28.200 261.310 8183.22 8244.12 525.07 S 2140.55 W 5959530.37 N 674083.10 E 1.795 2056.90 8972.07 27.080 260.790 8227.72 8288.62 528.69 S 2163.57 W 5959526.21 N 674060.17 E 2.281 2079.27 9065.13 29.360 259.850 8309.71 8370.61 536.10 S 2206.94 W 5959517.78 N 674016.98 E 2.496 2121.36 9100.69 29.220 259.010 8340.73 8401.63 539.30 S 2224.04 W 5959514.19 N 673999.96 E 1.221 2137.92 9132.06 29.620 260.920 8368.05 8428.95 541.98 S 2239.22 W 5959511.15 N 673984.86 E 3.251 2152.63 9158.36 29.960 261.740 8390.88 8451.78 543.95 S 2252.13 W 5959508.88 N 673971.99 E 2.018 2165.19 9194.26 30.570 263.920 8421.89 8482.79 546.20 S 2270.08 W 5959506.20 N 673954.10 E 3.500 2182.71 9228.21 31.080 261.960 8451.04 8511.94 548.34 S 2287.34 W 5959503.66 N 673936.89 E 3.318 2199.57 9253.13 32.190 261.890 8472.26 8533.16 550.18 S 2300.29 W 5959501.52 N 673924.00 E 4.457 2212.17 9285.14 33.920 260.620 8499.09 8559.99 552.84 S 2317.54 W 5959498.46 N 673906.81 E 5.821 2228.95 9317.81 38.100 261.750 8525.51 8586.41 555.77 S 2336.52 W 5959495.08 N 673887.91 E 12.955 2247.40 9345.80 41.660 263.050 8546.98 8607.88 558.14 S 2354.30 W 5959492.30 N 673870.18 E 13.062 2264.75 9380.77 44.400 263.330 8572.54 8633.44 560.96 S 2378.00 W 5959488.92 N 673846.56 E 7.854 2287.89 9411.25 45.860 262.780 8594.05 8654.95 563.58 S 2399.44 W 5959485.80 N 673825.19 E 4.958 2308.83 9438.91 47.380 261.270 8613.04 8673.94 566.37 S 2419.35 W 5959482.54 N 673805.35 E 6.778 2328.22 9474.44 49.960 264.700 8636.51 8697.41 569.61 S 2445.82 W 5959478.68 N 673778.96 E 10.259 2354.07 9505.50 52.410 265.920 8655.98 8716.88 571 .59 S 2469.94 W 5959476.14 N 673754.89 E 8.461 2377.75 '-" 9532.61 53.590 267.570 8672.29 8733.19 572.81 S 2491.55 W 5959474.41 N 673733.31 E 6.525 2399.03 9568.11 54.090 267.810 8693.24 8754.14 573.97 S 2520.19 W 5959472.58 N 673704.71 E 1.511 2427.30 9598.62 54.720 268.510 8711.00 8771.90 574.76 S 2544.98 W 5959471.21 N 673679.94 E 2.783 2451.79 9626.45 56.970 268.790 8726.62 8787.52 575.31 S 2568.01 W 5959470.12 N 673656.94 E 8.128 2474.56 9661.82 60.320 269.120 8745.02 8805.92 575.85 S 2598.20 W 5959468.87 N 673626.76 E 9.505 2504.44 9692.88 63.840 269.060 8759.57 8820.47 576.29 S 2625.64 W 5959467.79 N 673599.34 E 11.334 2531.60 9719.83 66.210 270.400 8770.94 8831.84 576.40 S 2650.07 W 5959467.10 N 673574.93 E 9.882 2555.82 9753.76 68.190 269.510 8784.09 8844.99 576.43 S 2681.34 W 5959466.34 N 673543.66 E 6.317 2586.84 9784.03 68.960 268.850 8795.15 8856.05 576.83 S 2709.52 W 5959465.28 N 673515.50 E 3.254 2614.74 9813.50 70.400 271.000 8805.38 8866.28 576.87 S 2737.15 W 5959464.60 N 673487.88 E 8.407 2642.15 9847.59 72.220 271.380 8816.31 8877.21 576.20 S 2769.43 W 5959464.51 N 673455.59 E 5.442 2674.26 9878.45 73.030 271.980 8825.52 8886.42 575.33 S 2798.87 W 5959464.68 N 673426.13 E 3.214 2703.57 22 August, 2003 - 8:55 Page 4 of 7 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 - 15-23A Your Ref: API 500292222501 Job No. AKZZ2548429, Surveyed: 24 July, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) 9905.26 73.940 271.680 8833.14 8894.04 574.51 S 2824.56 W 5959464.90 N 673400.43 E 3.560 2729.16 9941.97 76.670 271 .320 8842.46 8903.36 573.58 S 2860.06 W 5959465.00 N 673364.93 E 7.497 2764.48 9974.98 78.910 271 .870 8849.44 8910.34 572.68 S 2892.31 W 5959465.14 N 673332.67 E 6.978 2796.58 9999.4 7 80.750 271 .700 8853.76 8914.66 571.93 S 2916.40 W 5959465.33 N 673308.56 E 7.544 2820.58 10033.17 83.040 273.080 8858.51 8919.41 570.54 S 2949.73 W 5959465.94 N 673275.21 E 7.913 2853.82 '-- 10065.16 84.970 273.450 8861.85 8922.75 568.73 S 2981.49 W 5959467.00 N 673243.41 E 6.142 2885.55 10094.19 87.280 274.390 8863.81 8924.71 566.75 S 3010.39 W 5959468.31 N 673214.48 E 8.588 2914.47 10123.86 88.460 273.040 8864.92 8925.82 564.83 S 3039.97 W 5959469.53 N 673184.86 E 6.041 2944.06 10153.62 89.320 275.590 8865.49 8926.39 562.59 S 3069.64 W 5959471.08 N 673155.15 E 9.041 2973.77 10186.95 89.100 274.660 8865.95 8926.85 559.61 S 3102.83 W 5959473.27 N 673121.89 E 2.867 3007.07 10217.98 87.870 274.530 8866.77 8927.67 557.13 S 3133.75 W 5959475.03 N 673090.92 E 3.986 3038.06 10245.36 87.1 00 274.040 8867.98 8928.88 555.08 S 3161.03 W 5959476.44 N 673063.61 E 3.332 3065.37 10282.96 86.070 272.620 8870.22 8931.12 552.90 S 3198.50 W 5959477.74 N 673026.10 E 4.660 3102.82 10311.25 85.890 271.780 8872.20 8933.10 551.82 S 3226.70 W 5959478.16 N 672997.88 E 3.030 3130.93 10338.57 85.990 271.250 8874.13 8935.03 551 .1 0 S 3253.94 W 5959478.24 N 672970.63 E 1.969 3158.04 1 0429.19 87.470 270.780 8879.30 8940.20 549.50 S 3344.39 W 5959477.72 N 672880.16 E 1.713 3247.97 10523.62 90.400 273.590 8881.06 8941.96 545.90 S 3438.72 W 5959479.11 N 672785.78 E 4.299 3341.99 10617.21 90.090 273.970 8880.66 8941.56 539.73 S 3532.10 W 5959483.09 N 672692.27 E 0.524 3435.41 10711.50 88.830 276.120 8881.55 8942.45 531.44 S 3626.02 W 5959489.18 N 672598.19 E 2.643 3529.62 10805.75 88.300 276.920 8883.91 8944.81 520.74 S 3719.63 W 5959497.68 N 672504.36 E 1.018 3623.83 10898.95 88.390 273.600 8886.60 8947.50 512.20 S 3812.38 W 5959504.04 N 672411.42 E 3.562 3716.92 10992.12 88.980 272.680 8888.74 8949.64 507.10 S 3905.39 W 5959506.96 N 672318.33 E 1.173 3809.82 11084.99 86.450 270.950 8892.44 8953.34 504.16 S 3998.12 W 5959507.72 N 672225.54 E 3.299 3902.18 -' 11177.46 86.010 271.790 8898.52 8959.42 501.95 S 4090.37 W 5959507.77 N 672133.28 E 1.024 3993.96 11272.24 89.510 275.330 8902.22 8963.12 496.07 S 4184.86 W 5959511 .43 N 672038.67 E 5.250 4088.44 11366.27 89.110 274.750 8903.36 8964.26 487.81 S 4278.52 W 5959517.49 N 671944.84 E 0.749 4182.40 11460.04 89.440 276.380 8904.54 8965.44 478.72 S 4371.84 W 5959524.39 N 671851.34 E 1.773 4276.11 11553.83 90.650 280.600 8904.47 8965.37 464.87 S 4464.58 W 5959536.06 N 671758.30 E 4.681 4369.86 11647.05 90.900 283.080 8903.21 8964.11 445.75 S 4555.80 W 5959553.04 N 671666.65 E 2.674 4462.77 11739.88 90.310 284.990 8902.23 8963.13 423.24 S 4645.85 W 5959573.43 N 671576.10 E 2.153 4554.94 11834.34 90.800 285.990 8901.31 8962.21 398.01 S 4736.87 W 5959596.52 N 671484.51 E 1.179 4648.42 11925.07 90.740 286.890 8900.09 8960.99 372.34 S 4823.88 W 5959620.14 N 671396.92 E 0.994 4737.99 12018.04 90.310 287.480 8899.24 8960.14 344.87 S 4912.70 W 5959645.52 N 671307.49 E 0.785 4829.56 12111.25 90.030 288.110 8898.97 8959.87 316.38 S 5001.45 W 5959671.92 N 671218.09 E 0.740 4921.20 12203.71 86.450 285.450 8901.81 8962.71 289.71 S 5089.91 W 5959696.51 N 671129.04 E 4.823 5012.33 22 August, 2003 - 8:55 Page 5 of 7 DríllQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 - 15-23A Your Ref: API 500292222501 Job No. AKZZ2548429, Surveyed: 24 July, 2003 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 12221.72 86.640 287.020 8902.89 8963.79 12268.00 86.640 287.020 8905.60 8966.50 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 5107.17 W 5151.34 W 5959701.13 N 5959713.62 N 284.68 S 271.16 S All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 277.270° (True). Magnetic Declination at Surface is 25.856°(12-Jul-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 12268.00ft., The Bottom Hole Displacement is 5158.48ft. in the Direction of 266.987° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 3908.40 4074.00 12268.00 3908.10 4073.70 8966.50 23.43 S 24.01 S 271.16 S Tie On Point Window Point Projected Survey 27.03 E 28.42 E 5151.34 W 22 August, 2003 - 8:55 Page 6 of 7 671111 .66 E 671067.18 E Dogleg Vertical Rate Section CO/100ft) BPXA Comment 8.765 5030.08 0.000 5075.62 Projected Survey --' '----- DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 - 15-23A Your Ref: API 500292222501 Job No. AKZZ2548429, Surveyed: 24 July, 2003 BPXA North Slope Alaska Survey tool program for 15-23A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 3908.40 0.00 3908.40 3908.10 12268.00 3908.10 BP High Accuracy Magnetic (15-23) 8966.50 AK-6 BP _IFR-AK (15-23A) '-/ -' 22 August, 2003 - 8:55 Page 70f7 DríllQuest 3.03.02.005 ) ) 24-Aug-03 AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 30:3-\ \ , Re: Distribution of Survey Data for Well 15-23A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and a disk with the *.PTT and *.PDF files. Tie-on Survey: 3,908.40' MD Window / Kickoff Survey: 4,074.00' MD (if applicable) Projected Survey: 12,268.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AUG 29 2003 K~m~ Alaska Œ{ & Gas Ccn~. Ccmmi~ AnchOfege Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 15 15-23A MWD ,-,,' Job No. AKMW2548429, Surveyed: 24 July, 2003 Survey Report 22 August, 2003 Your Ref: API500292222501 Surface Coordinates: 5960105.48 N, 676210.75 E (70017' 47.7256" N, 148034'22.8594" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 .---' Surface Coordinates relative to Project H Reference: 960105.48 N, 176210.75 E (Grid) Surface Coordinates relative to Structure Reference: 1269.70 N, 57.46 W (True) Kelly Bushing: 60.90ft above Mean Sea Level Elevation relative to Project V Reference: 60.90ft Elevation relative to Structure Reference: 60.90ft sr-=-""""Y-5UI'1 b RI LL 11\1[;·' "s e FiV Ie: e S A Halliburton Company Survey Ref: svy4086 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 - 15-23A MWD Your Ref: API500292222501 Job No. AKMW2548429, Surveyed: 24 July, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3908.40 0.500 116.020 3847.20 3908.10 23.43 8 27.03 E 5960082.69 N 676238.33 E -29.78 Tie On Point MWD Magnetic 4074.00 0.540 109.650 4012.80 4073.70 24.01 8 28.42 E 5960082.14 N 676239.72 E 0.042 -31 .23 Window Point 4106.00 2.600 153.200 4044.78 4105.68 24.71 8 28.89 E 5960081.45 N 676240.21 E 6.999 -31.78 4137.00 3.500 145.800 4075.74 4136.64 26.128 29.74 E 5960080.06 N 676241.09 E 3.163 -32.80 4169.00 4.500 111 .700 4107.66 4168.56 27.39 S 31 .45 E 5960078.83 N 676242.84 E 7.911 -34.67 -- 4201.00 5.800 109.600 4139.53 4200.43 28.408 34.14 E 5960077.89 N 676245.55 E 4.104 -37.46 4227.67 7.210 117.970 4166.03 4226.93 29.64 8 36.89 E 5960076.72 N 676248.33 E 6.358 -40.34 4260.21 8.720 106.140 4198.26 4259.16 31.28 S 41.06 E 5960075.17 N 676252.54 E 6.826 -44.69 4311.49 10.630 130.530 4248.83 4309.73 35.44 S 48.40 E 5960071 .19 N 676259.96 E 8.731 -52.49 4369.67 12.330 139.830 4305.85 4366.75 43.67 S 56.48 E 5960063.15 N 676268.24 E 4.311 -61.56 4405.13 12.810 148.500 4340.46 4401.36 49.92 S 60.98 E 5960057.01 N 676272.88 E 5.485 -66.81 4449.82 13.310 158.950 4384.00 4444.90 58.94 8 65.42 E 5960048.09 N 676277.53 E 5.393 -72.35 4498.71 13.860 170.810 4431.53 4492.43 69.988 68.37 E 5960037.12 N 676280.75 E 5.797 -76.68 4551 .23 14.370 182.090 4482.48 4543.38 82.70 8 69.14 E 5960024.42 N 676281.81 E 5.318 -79.05 4590.39 14.750 188.930 4520.38 4581 .28 92.48 8 68.19 E 5960014.62 N 676281.09 E 4.494 -79.35 4627.04 15.070 195.760 4555.80 4616.70 101.688 66.17 E 5960005.38 N 676279.29 E 4.871 -78.51 4658.74 15.450 201.050 4586.38 4647.28 109.59 8 63.54 E 5959997.41 N 676276.84 E 4.551 -76.89 4685.99 15.540 206.210 4612.65 4673.55 116.258 60.62 E 5959990.68 N 676274.08 E 5.068 -74.84 4720.07 16.220 212.900 4645.43 4706.33 124.34 S 56.02 E 5959982.49 N 676269.67 E 5.726 -71.30 4750.97 16.650 219.100 4675.07 4735.97 131.408 50.88 E 5959975.31 N 676264.70 E 5.842 -67.1 0 4779.28 17.290 223.570 4702.15 4763.05 137.608 45.42 E 5959968.98 N 676259.39 E 5.131 -62.47 4813.46 18.480 229.200 4734.68 4795.58 144.82 8 37.82 E 5959961.59 N 676251.96 E 6.137 -55.84 '.-, 4844.38 19.800 232.130 4763.89 4824.79 151.24 8 29.98 E 5959954.99 N 676244.26 E 5.279 -48.87 4872.02 20.170 235.860 4789.86 4850.76 156.78 S 22.34 E 5959949.26 N 676236.76 E 4.802 -42.00 4906.48 19.960 240.420 4822.23 4883.13 163.02 8 12.30 E 5959942.79 N 676226.87 E 4.580 -32.83 4937.92 20.890 243.490 4851.70 4912.60 168.178 2.62 E 5959937.41 N 676217.31 E 4.512 -23.88 4965.78 22.280 243.730 4877.60 4938.50 172.73 8 6.56W 5959932.65 N 676208.24 E 4.999 -15.35 5000.28 24.020 249.340 4909.33 4970.23 178.108 19.00 W 5959926.98 N 676195.93 E 8.138 -3.69 5029.79 25.150 251 .840 4936.16 4997.06 182.178 30.58 W 5959922.64 N 676184.45 E 5.204 7.28 5057.45 26.490 253.320 4961.06 5021.96 185.788 42.07 W 5959918.77 N 676173.05 E 5.376 18.22 22 August, 2003 - 8:57 Page 2 of 7 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA OS 15 - 15-23A MWO Your Ref: API500292222501 Job No. AKMW2548429, Surveyed: 24 July, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) C/100ft) 5152.27 30.500 257.260 5044.38 5105.28 197.168 85.82 W 5959906.36 N 676129.58 E 4.669 60.18 5245.87 34.200 262.790 5123.46 5184.36 205.70 S 135.11 W 5959896.66 N 676080.50 E 5.058 108.00 5340.00 36.490 266.130 5200.24 5261.14 210.91 S 189.30 W 5959890.19 N 676026.45 E 3.182 161.08 5433.15 35.900 266.490 5275.42 5336.32 214.46 S 244.19 W 5959885.36 N 675971.66 E 0.673 215.09 5526.50 35.580 267.080 5351.19 5412.09 217.51 8 298.63 W 5959881.02 N 675917.30 E 0.504 268.70 ~ 5620.05 35.760 266.660 5427.19 5488.09 220.49 S 353.10 W 5959876.77 N 675862.92 E 0.325 322.36 5713.52 35.630 268.380 5503.10 5564.00 222.85 8 407.58 W 5959873.13 N 675808.51 E 1.083 376.10 5807.65 35.490 268.610 5579.67 5640.57 224.29 8 462.30 W 5959870.41 N 675753.83 E 0.206 430.20 5900.45 35.380 267.610 5655.29 5716.19 226.07 S 516.08 W 5959867.38 N 675700.12 E 0.636 483.32 5993.35 35.840 267.050 5730.81 5791.71 228.598 570.11 W 5959863.59 N 675646.16 E 0.607 536.60 6087.15 36.720 264.680 5806.43 5867.33 232.60 8 625.46 W 5959858.28 N 675590.92 E 1.765 590.99 6180.27 36.280 264.410 5881.29 5942.19 237.87 S 680.60 W 5959851.72 N 675535.92 E 0.503 645.02 6272.31 35.920 260.070 5955.67 6016.57 245.18 S 734.30 W 5959843.16 N 675482.40 E 2.805 697.37 6366.87 35.280 259.550 6032.55 6093.45 254.91 S 788.48 W 5959832.15 N 675428.47 E 0.749 749.88 6460.10 35.240 258.200 6108.68 6169.58 265.30 8 841.28 W 5959820.53 N 675375.92 E 0.837 800.95 6553.12 35.470 258.360 6184.55 6245.45 276.23 8 893.99 W 5959808.37 N 675323.48 E 0.267 851 .84 6646.46 34.910 258.330 6260.83 6321.73 287.108 946.67 W 5959796.27 N 675271.07 E 0.600 902.73 6738.53 33.830 256.480 6336.82 6397.72 298.42 S 997.39 W 5959783.76 N 675220.63 E 1.632 951.61 6831.13 32.880 256.770 6414.17 6475.07 310.208 1046.92 W 5959770.82 N 675171.39 E 1.040 999.25 6925.12 33.550 256.620 6492.80 6553.70 322.04 8 1097.03 W 5959757.80 N 675121.58 E 0.718 1047.45 7018.69 32.450 256.270 6571 .28 6632.18 333.99 S 1146.57W 5959744.70 N 675072.33 E 1.193 1095.09 7111.60 30.350 255.420 6650.58 6711.48 345.81 8 1193.50 W 5959731.78 N 675025.68 E 2.310 1140.15 7206.08 30.600 255.890 6732.00 6792.90 357.68 S 1239.93 W 5959718.82 N 674979.55 E 0.366 1184.70 .~-' 7299.42 31 .840 259.990 6811.83 6872.73 367.768 1287.22 W 5959707.64 N 674932.51 E 2.635 1230.33 7393.96 32.270 260.200 6891.96 6952.86 376.39 8 1336.65 W 5959697.86 N 674883.29 E 0.470 1278.27 7488.88 31.820 260.260 6972.42 7033.32 384.93 8 1386.28 W 5959688.15 N 674833.88 E 0.475 1326.42 7581.32 31.840 260.170 7050.96 7111.86 393.22 8 1434.32 W 5959678.74 N 674786.04 E 0.056 1373.03 7674.81 32.950 259.300 7129.90 7190.80 402.158 1483.61 W 5959668.66 N 674736.98 E 1.288 1420.79 7769.27 34.910 258.630 7208.27 7269.17 412.258 1535.35 W 5959657.35 N 674685.48 E 2.112 1470.84 7862.51 33.880 258.930 7285.20 7346.10 422.508 1587.02 W 5959645.89 N 674634.08 E 1.120 1520.79 7956.31 31 .250 257.650 7364.25 7425.15 432.73 8 1636.45 W 5959634.51 N 674584.89 E 2.898 1568.54 8050.14 30.930 257.350 7444.60 7505.50 443.21 8 1683.76 W 5959622.91 N 674537.85 E 0.379 1614.13 8144.42 30.350 257.630 7525.72 7586.62 453.62 8 1730.66 W 5959611.41 N 674491.20 E 0.634 1659.35 8237.34 31.220 258.650 7605.55 7666.45 463.39 8 1777.20 W 5959600.55 N 674444.90 E 1.092 1704.28 8330.44 34.740 260.180 7683.63 7744.53 472.668 1827.02 W 5959590.11 N 674395.32 E 3.885 1752.51 22 August, 2003 - 8:57 Page 3 of 7 OrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 - 15-23A MWD Your Ref: API500292222501 Job No. AKMW2548429, Surveyed: 24 July, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) 8423.03 35.750 260.580 7759.25 7820.15 481.59 S 1879.70 W 5959579.95 N 674342.86 E 1.119 1803.64 8516.00 34.230 260.060 7835.41 7896.31 490.55 S 1932.25 W 5959569.76 N 674290.54 E 1.666 1854.64 8608.98 32.800 260.450 7912.93 7973.83 499.24 S 1982.84 W 5959559.88 N 674240.16 E 1.555 1903.73 8701.59 30.980 260.200 7991.56 8052.46 507.46 S 2031.07 W 5959550.54 N 674192.14 E 1.970 1950.53 8793.70 29.480 260.800 8071.14 8132.04 515.12 S 2076.81 W 5959541.81 N 674146.59 E 1.661 1994.92 .--, 8887.15 28.800 261.170 8152.77 8213.67 522.25 S 2121.75 W 5959533.62 N 674101.83 E 0.753 2038.60 8921.84 28.200 261.570 8183.25 8244.15 524.74 S 2138.11 W 5959530.76 N 674085.53 E 1.815 2054.52 8972.07 27.080 260.790 8227.75 8288.65 528.31 S 2161.14 W 5959526.65 N 674062.59 E 2.343 2076.91 9065.13 29.360 260.520 8309.74 8370.64 535.46 S 2204.56 W 5959518.48 N 674019.35 E 2.454 2119.07 9100.69 29.220 259.640 8340.76 8401.66 538.45 S 2221.69 W 5959515.09 N 674002.29 E 1.273 2135.69 9132.06 29.620 261.660 8368.08 8428.98 540.95 S 2236.90 W 5959512.23 N 673987.15 E 3.410 2150.46 9158.36 29.960 262.500 8390.91 8451.81 542.75 S 2249.84 W 5959510.13 N 673974.26 E 2.047 2163.07 9194.26 30.570 264.810 8421.91 8482.81 544.75 S 2267.82 W 5959507.71 N 673956.33 E 3.661 2180.65 9228.21 31.080 262.510 8451.07 8511.97 546.67 S 2285.11 W 5959505.38 N 673939.09 E 3.782 2197.56 9253.13 32.190 262.600 8472.29 8533.19 548.37 S 2298.07 W 5959503.38 N 673926.17 E 4.458 2210.20 9285.14 33.920 260.590 8499.11 8560.01 550.93 S 2315.33 W 5959500.42 N 673908.97 E 6.398 2227.00 9317.81 38.100 261.650 8525.54 8586.44 553.88 S 2334.31 W 5959497.02 N 673890.07 E 12.936 2245.45 9345.80 41.660 263.150 8547.01 8607.91 556.25 S 2352.09 W 5959494.24 N 673872.34 E 13.174 2262.79 9380.77 44.400 263.750 8572.57 8633.47 558.96 S 2375.80 W 5959490.97 N 673848.71 E 7.922 2285.97 9411.25 45.860 263.540 8594.08 8654.98 561.36 S 2397.27 W 5959488.07 N 673827.30 E 4.815 2306.96 9438.91 47.380 261.850 8613.07 8673.97 563.92 S 2417.20 W 5959485.05 N 673807.43 E 7.065 2326.41 9474.44 49.960 265.150 8636.54 8697.44 566.92 S 2443.71 W 5959481.42 N 673781.01 E 10.067 2352.32 9505.50 52.41 0 266.720 8656.01 8716.91 568.63 S 2467.84 W 5959479.15 N 673756.92 E 8.816 2376.05 ~ 9532.61 53.590 268.410 8672.32 8733.22 569.55 S 2489.47 W 5959477.72 N 673735.31 E 6.613 2397.39 9568.11 54.090 268.420 8693.27 8754.17 570.34 S 2518.12 W 5959476.26 N 673706.69 E 1 .409 2425.71 9598.62 54.720 270.070 8711.03 8771.93 570.67 S 2542.93 W 5959475.35 N 673681.90 E 4.858 2450.27 9626.45 56.970 270.610 8726.65 8787.55 570.53 S 2565.96 W 5959474.95 N 673658.87 E 8.243 2473.13 9661.82 60.320 269.570 8745.05 8805.95 570.48 S 2596.16 W 5959474.28 N 673628.68 E 9.798 2503.09 9692.88 63.840 270.500 8759.60 8820.50 570.46 S 2623.60 W 5959473.66 N 673601.25 E 11.637 2530.32 9719.83 66.210 272.150 8770.98 8831.88 569.90 S 2648.02 W 5959473.66 N 673576.82 E 10.399 2554.61 9753.76 68.190 269.170 8784.13 8845.03 569.54 S 2679.29 W 5959473.28 N 673545.55 E 9.980 2585.68 9784.03 68.960 267.600 8795.18 8856.08 570.34 S 2707.45 W 5959471.82 N 673517.41 E 5.457 2613.51 9813.50 70.400 273.240 8805.42 8866.32 570.13 S 2735.07 W 5959471.38 N 673489.79 E 18.599 2640.94 9847.59 72.220 274.030 8816.35 8877.25 568.08 S 2767.30 W 5959472.68 N 673457.53 E 5.772 2673.17 9878.45 73.030 273.170 8825.56 8886.46 566.23 S 2796.69 W 5959473.83 N 673428.10 E 3.737 2702.56 22 August, 2003 - 8:57 Page 4 of 7 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA OS 15 - 15-23A MWO Your Ref: API500292222501 Job No. AKMW2548429, Surveyed: 24 July, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 o Oft) 9905.26 73.940 271.700 8833.18 8894.08 565.14 S 2822.37 W 5959474.32 N 673402.40 E 6.257 2728.17 9941.97 76.670 272.880 8842.50 8903.40 563.72 S 2857.85 W 5959474.91 N 673366.90 E 8.060 2763.54 9974.98 78.910 271.120 8849.48 8910.38 562.59 S 2890.09 W 5959475.28 N 673334.64 E 8.556 2795.66 9999.47 80.750 268.710 8853.80 8914.70 562.63 S 2914.19 W 5959474.68 N 673310.55 E 12.258 2819.57 10033.17 83.040 274.470 8858.56 8919.46 561.70 S 2947.53 W 5959474.83 N 673277.20 E 18.233 2852.75 -' 10065.16 84.970 274.190 8861.90 8922.80 559.30 S 2979.25 W 5959476.48 N 673245.43 E 6.096 2884.52 10094.19 87.280 270.050 8863.86 8924.76 558.23 S 3008.18 W 5959476.87 N 673216.48 E 16.302 2913.36 10123.86 88.460 271.650 8864.96 8925.86 557.79 S 3037.83 W 5959476.62 N 673186.83 E 6.698 2942.82 10153.62 89.320 274.200 8865.54 8926.44 556.27 S 3067.54 W 5959477.44 N 673157.09 E 9.041 2972.49 10186.95 89.1 00 272.720 8866.00 8926.90 554.26 S 3100.81 W 5959478.67 N 673123.79 E 4.489 3005.74 10217.98 87.870 272.570 8866.82 8927.72 552.83 S 3131.79 W 5959479.38 N 673092.78 E 3.993 3036.66 10245.36 87.1 00 272.690 8868.02 8928.92 551.57 S 3159.12 W 5959479.99 N 673065.43 E 2.846 3063.92 10282.96 86.070 271.110 8870.26 8931 .16 550.33 S 3196.63 W 5959480.35 N 673027.90 E 5.010 3101.29 10311.25 85.890 271.730 8872.24 8933.14 549.63 S 3224.84 W 5959480.39 N 672999.68 E 2.277 3129.36 10338.57 85.990 269.820 8874.18 8935.08 549.26 S 3252.09 W 5959480.12 N 672972.43 E 6.983 3156.44 1 0429.19 87.470 266.470 8879.35 8940.25 552.19 S 3342.50 W 5959475.07 N 672882.12 E 4.036 3245.75 10523.62 90.400 273.530 8881.11 8942.01 552.19 S 3436.84 W 5959472.86 N 672787.80 E 8.093 3339.33 10617.21 90.090 272.010 8880.71 8941.61 547.67 S 3530.32 W 5959475.19 N 672694.24 E 1.658 3432.63 10711.50 88.830 275.450 8881.60 8942.50 541.53 S 3624.39 W 5959479.12 N 672600.06 E 3.885 3526.72 10805.75 88.300 276.270 8883.96 8944.86 531.91 S 3718.11 W 5959486.54 N 672506.13 E 1.036 3620.91 10898.95 88.390 273.580 8886.65 8947.55 523.92 S 3810.92 W 5959492.36 N 672413.16 E 2.887 3713.99 10992.12 88.980 270.070 8888.79 8949.69 520.95 S 3904.01 W 5959493.14 N 672320.03 E 3.819 3806.70 11084.99 86.450 272.680 8892.49 8953.39 518.73 S 3996.76 W 5959493.19 N 672227.25 E 3.912 3898.99 - 11177.46 86.010 272.200 8898.57 8959.47 514.80 S 4088.95 W 5959494.95 N 672135.00 E 0.703 3990.93 11272.24 89.510 277.090 8902.28 8963.18 507.13 S 4183.30 W 5959500.41 N 672040.49 E 6.341 4085.49 11366.27 89.110 276.170 8903.41 8964.31 496.27 S 4276.69 W 5959509.07 N 671946.87 E 1.067 4179.51 11460.04 89.440 274.660 8904.60 8965.50 487.42 S 4370.03 W 5959515.73 N 671853.35 E 1.648 4273.22 11553.83 90.650 282.090 8904.52 8965.42 473.77 S 4462.76 W 5959527.20 N 671760.33 E 8.026 4366.93 11647.05 90.900 281.540 8903.26 8964.16 454.69 S 4553.99 W 5959544.14 N 671668.67 E 0.648 4459.84 11739.88 90.310 285.260 8902.28 8963.18 433.18 S 4644.27 W 5959563.53 N 671577.91 E 4.057 4552.12 11834.34 90.800 285.630 8901.37 8962.27 408.03 S 4735.32 W 5959586.54 N 671486.30 E 0.650 4645.62 11925.07 90.740 287.880 8900.15 8961.05 381.87 S 4822.18 W 5959610.65 N 671398.85 E 2.481 4735.09 12018.04 90.310 283.730 8899.29 8960.19 356.56 S 4911.61 W 5959633.86 N 671308.85 E 4.488 4827.01 12111.25 90.030 280.070 8899.02 8959.92 337.34 S 5002.81 W 5959650.94 N 671217.23 E 3.938 4919.90 12203.71 86.450 283.870 8901.86 8962.76 318.18 S 5093.18 W 5959667.97 N 671126.43 E 5.645 5011.97 22 August, 2003 - 8:57 Page 5 of 7 OrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 - 15-23A MWD Your Ref: API500292222501 Job No. AKMW2548429, Surveyed: 24 July, 2003 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (tt) 12221.72 86.640 284.450 8902.94 8963.84 12268.00 86.640 284.450 8905.65 8966.55 Local Coordinates Northings Eastings (tt) (ft) Global Coordinates Northings Eastings (ft) (tt) 313.79 S 302.26 S 5110.61 W 5155.35 W 5959671.96 N 5959682.43 N All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 277.270° (True). Magnetic Declination at Surface is 25.856°(12-Jul-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 12268.00ft., The Bottom Hole Displacement is 5164.20ft., in the Direction of 266.645° (True). Comments Measured Depth (tt) Station Coordinates TVD Northings Eastings (tt) (tt) (tt) Comment 3908.40 4074.00 12268.00 23.43 S 24.01 S 302.26 S Tie On Point Window Point Projected Survey 3908.10 4073.70 8966.55 27.03 E 28.42 E 5155.35 W 22 August, 2003 - 8:57 Page 6 of 7 671108.90 E 671063.90 E Dogleg Vertical Rate Section (0/100tt) BPXA Comment 3.383 5029.82 0.000 5075.66 Projected Survey -.,~./ -' DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 - 15-23A MWD Your Ref: API500292222501 Job No. AKMW2548429, Surveyed: 24 July, 2003 BPXA North Slope Alaska Survey tool program for 15-23A MWD Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 3908.40 0.00 3908.40 3908.10 12268.00 3908.10 BP High Accuracy Magnetic (15-23) 8966.55 MWD Magnetic (15-23A MWD) ,-",' ~ 22 August, 2003 - 8:57 Page 7 of 7 DrillQuest 3.03.02.005 ) ) cJ.,~~ to ~ P i"9\Iac4 ZO 1 ~ III P ~ H to dvl¡. ð-f'>, \fJ. r:A~" 7 I IV /-¿,o 0 . To: Winton Aubert - AOGCC Date: July 14, 2003 From: Rob Tirpack - BPXA GPB Rotary Drilling Subject: 15-23 - Change in operations for P&A and Sidetrack Approval is requested for changes to operations for 15-23. Collapsed tubing was discovered at 6714' during pre-rig slickline operations. The tubing was cut above the collapsed joint at 6643', but circulation could not be established. Holes were shot in the tubing at 3140' and circulation was established. Nabors 2es then moved in, rigged up and was unable to pull tubing from the cut at 6643'. A RST log was run in gravel pack mode which showed fill from .....3800' to .....4800'. A free point indicator tool was run and showed pipe to be 82% free at 4125'. The tubing was cut and recovered from 4125'. After washing out fill, the second section of tubing was successfully fished from the cut at 6643'. Next, an 8-1/2" bit with qn 8-1/2" string reamer were run in the hole. This BHA worked through several tight spots, but was unable to get any deeper than 4210'. After working the BHA at the obstruction, the decision was made to sidetrack out of the 9-5/8" above 4210'. An RTTS packer was run to 4200' and the 9-5/8" casing was successfully pressure tested to 3500 psi for 30 minutes. Finally a gauge ring/junk basket was run and would not go any deeper than 4139'. A CI BP has been set 4100' and preparations are being made for window milling operations. Ria Operations: 1. MU and RIH with GR/JB to 4100'. 2. MU bridge plug on e-line with eeL. RIH and set at 4100' MD, set as needed to avoid cutting a casing / collar. 3. RIH with 9-5/8" Baker bottom trip whipstock assembly. Orient whipstock and set on bridge plug. 4. Displace well over to 9.8 ppg milling/drilling fluid. / 5. Mill ¡æin in 9-5/8" casing at 4100' MD, plus 20' past middle of window. Perform FIT. POOH. 6. MU -1 drilling assembly with Dir/GR/Res and RIH. Kick off and drill the 8-1/2" intermediate inte ,building and turning at 4°/100' to a 31 ° hold angle. / 7. Drill ahead to casing point at Top Sag River to an estimated depth of 8,902' MD. /' 8. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing to 3,900' MD'æ¡ ce cement with mud. POOH. 9. MU -1/' BHA with Dir/GR/Den/Neu and RIH. 10. Drill "6-1/8" production interval building at 12°/100' to horizontal, targeting Z1A Ivishak. Drill ahead to an estimated TD of 12,220' MD. 11. Run and cement a 4-1/2" solid liner throughout the 6-1/8" wellbore and back into the 7" liner. /' 12. Displace well to clean seawater. 13. RIH with DPC perf guns. Perf intervals to be determined from LWD logs. 14. POOH. LD DP and perf guns. 15. Run 4-1/2", 12.6#, Chrome completion tying into the 4-1/2" liner top. ' 16. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. /' 17. Set and test TWe. 18. NO BOPE. NU and test the tree to 5000 psi. 19. Freeze protect the well to .....2200' and secure the well. 20. RDMO 15-23 Change in Operations ) ) Post-RiQ Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. / Pre-rig Start Date: Spud Date: 07/05/03 07/09/03 Rob Tirpack Operations Drilling Engineer 564-4166 Intermediate Hole Section Mud Program Section Milling Mud Properties: LSND Density (ppg) Viscosity PV 9.8 50 - 65 11-13 I Whip Stock Window 9 5/8" I YP TauO HTHP FL PH 25-30 5-9 <12 8.5 - 9.0 Intermediate Mud Properties: LSND Density (PDQ) Viscosity PV 9.8 / - 45 - 55 12-15 I 8-1/2" hole section YP TauO 20-25 3-7 I HTHP FL PH <12 8.5 - 9.0 Directional - Sperry wp04 KOP: 14,000' MD Maximum Hole Angle: Close Approach Well: -310 in 8-1/2" hole 15-05, 15-05A, and 15-05APB1 all require 1/200 minor risk to pass BP's anti-collision policy. Center to center distance at the closest point is over 600'. MWD with IFR/Casandra Survey Program: Casing/Tubing Program Hole Size CsglTbg 0.9. WtlFt Grade Conn Length 8-1/2" 7" 26# L-80 BTC-M 5,002' Top MDITVD 3,900'/3900' Btm MDITVD 8,902'/8245' 15-23 Change in Operations ) ) Cement Program Casing Size 11" 26#, L-80 Intermediate Liner I Basis: Lead: Based on 3902' of 7" X 8-1/2" open hole with 40% excess Lead TOC: 4500' MD Tail: Based on 80' shoe track and 500' of 7" X 8-1/2" open hole with 40% excess Tail TOC: 8402' MD I Total Cement Volume: Lead Tail 123 bbls, 690 ft3, 291 sacks of Class G @ 12.0 ppg, 2.37 ft3/sack 20 bbls, 113 ft3, 97 sacks Class G @ 15.8 ppg, 1.16 ft3/sack Density Rate Volume 9.8 5 N/A 11.0 5 40 12.0 5 123 15.8 5 20 9.8 6 215 9.8 2 2 I Pump Schedule: Mud Mud Push XL Lead Cement Tail Cement Mud Mud Logging Program 8-1/2" Intermediate: Sample Catchers - None Drilling: Dir/GRlRes- Real time Open Hole: None Cased Hole: None Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing Test Integrity Test - 8-1/2" hole 3567 psi (8.3 ppg @ 8264' TVDss) 2741 psi (.10 psi/ft gas gradient to surface) /' 120 bbls with a 12.0 ppg FIT Rams test to 3,500 psi/250 psi. Annular test to 2,500 psi/250 psi 3500 psi surface pressure 12.0 ppg FIT after drilling 20' outside window 15-23 Change in Operations ') ') 15-23A Intermediate Hole Drilling Program Job 4: Window Mill Hazards and Contingencies )0> Position bridge plug to avoid cutting a casing collar while milling the window. )0> Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP . 1.C<':U:I.UI.lllln: --I-II-:I-lnml~_I··· .:1'-1111-- --I--_I_i:-m:.:m'n"~·""_1_lImll_J__II__1 1_ _nlnm_ .1II1I":I,,IUUUllllm-.I. .11I1111111I. ¡;~IW¡;.If>.-'II!I:llllln- .m. 1::ml~IIIIIT!~::II::II'1 wntlllllml.IIIIIIUIIIII:m.I..1 Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies )0> The intermediate section will kick off in the SV1 sand package and TO at the top of Sag River. Since 15-23A will be at -300 inclination at a260° azimuth, maintain mud weight at minimum 9.8 ppg to interval TO. Follow all shale drilling practices to minimize potential problems. )0> There are no fault crossings in the intermediate section. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. ~ 15-05 has been 1/200 minor risk based to pass BP's anti-collision policy. )0> KICK TOLERAN"C~: In the worst-case scenario of 8.8 ppg pore pressure at the Sag River depth, a fracture gr~~ii~nt C.f 12.0 ppg at the 9-5/8" casing window, and 9.8 ppg mud in the hole, the kick tolerance is ~~. Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .. _ "I.....r--~-- ~ -; Job 6: Install 7" Intermediate Liner Hazards and Contingencies )0> Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. )0> Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP 15-23 Change in Operations ). ) 15-23A Proposed ·Completion 2200' 14-1/2" 'X' Nipple I TREE = WELLHEAD = AëiiJA'TOR = KS. ELEV = SF: ËLËv' = KOP= Max Angle '= . Datum MD = oäïÙin TV D '= FMC MCEVOY OTIS 69.6' 3518' .4 l ~ 13-3/8", 68#, L-80 4558' 90@"; 8800' SS ------14-1/2", 12.6#, 13Cr80, VAM ACE Tubing I 4070' KOP Tubing Tail: -10' Pup Joint -X Nipple (3.813") -10' Pup Joint -Packer -20' Pup Joint -X Nipple (3.813") -20' Pup Joint -XN Nipple (3.725") -10' Pup Joint -WLEG 3900' 8 8 9-5/8" X 7" Flex-Lock Liner Hanger with ZXP Liner Top Packer and TBR 6643' 7" X 4-1/2" 8-3 Permanent Packer @8700' 7" X 4-1/2" HMC Liner Hanger with ZXP Liner Top Packer andTBR @ 8750' 4100' 4210' 6714' 8309' 8526' 8720' .. 9420' i I I', 10600' .. :,,: ~ 7", 29#, L-80 11273' ~ 4-1/2",12.6#, L-80 11500'" 6"hole ",26#, L-80, BTC-M @ 8902' PXN Plug to. 9-5/8",47#, L-80 '. 4-1/2",12.6#, L-80, IBT-M .: .'i?', :.~.:"~:,..'.,.-",-,~,, ..'~~; ','" 'II':;¡' "I" ,~:h"':; 12,220' GLM Design: #4 - 3200' TVD - 4-1/2" X 1" - SV #3 - 5700' TVD - 4-1/2" X 1" - DV #2 - 7450' TVD - 4-1/2" X 1" - DV #1 - 8500' TVD - 4-1/2" X 1" - DV Date 7-01-03 Rev By Comments RBT Proposed Completion Design PRUDHOE BAY UNIT WELL: 15-23A API NO: Permit NO: GPB Rotary Drilling ~. ..1/--.., North Slope Alaska '-tftJl..L.U·a -~I"·Vt.' -.}\ BPXA .. tH!!itw4W1·""......" ~~~~c:P~¡ 15DrillQ"est~ 15-23A WP04 Proposal Data Current Well Properties 15-23A W P04 Dogleg severity: Degrees per 100 feet (US Survey) Vertical Section Azimuth: 277.270c Vertical Section Description: Well Vertical Section Origin: 0.00 N,O.OO E Measured Incl. Azim. Depth Vertical Origin: Horizontal Origin: Measurement Units: North Reference: 4000.00 4020.00 4821U5 5045.02 9072.17 10055.88 11246.39 11632.52 122] 9.915 0.522 2.922 30.400 30.398 30.398 88.797 88.797 90.301 90.30 I Well: Well Well ft True North Horizontal Coordinates: Ref. Global Coordinates : Ref. Structure Reference . Ref. Geographical Coordinates : RKB Elevation : 5960105.48 N, 676210.75 E 1269.70 N, 57.46 W lOc 17' 47.7256" N, 148~ 34' 22.8594" W 50.90ft above Mean Sea Level 50.90ft above Structure Reference True North Feet (US Survey) 112.375 112.375 242.000 259.175 259.] 75 270.188 270.188 293.308 293.308 Vertical Depth . .. no _.._num________u.________.__..__m_____ 3999.70 23.77 S 40]9.69 23.99S 4792.57 130.70 S 4979.8] 166.80 S 8453.33 549.53 S 8930.90 599.]2 S 8955.90 595.21 S 8958.98 517.12 S 8955.90 284.68 S Eastings Vertical Dogleg Section Rate 27.78 E -30.56 28.33 E -3 Ll4 ]2.000 137.63 W 119.98 4.000 240.07 W 217.03 4.000 2241.59 W 2154.03 0.000 3050.64 W 2950.30 6.000 4240.87 W 4131.46 0.000 4616.33 W 4513.78 6.000 5155.84 W 5078.37 0.000 '-" Northings North Reference: Units: --. ill S ø 0> c :.ë ...... o¢:: z8 r--. II ..c: ü .S -700 - -1400 - àj ro ü if) .", ""',..,,.......... Total Deplh : 12219.98ftMO,8955.90ftTVD \ End Oir, Start Sail @ 90.301' : 11632.52ftMD,8958.98ftTVO \ ....... Fault #3 Crossing: 11468.00ft MD 4 1121n liner \ "'<, !3egin Oir @ 6.000'(1000: 11246.39ft MO, 8955.90ft TVD 12219.9811 Met' \... ......' \ fault #2 Crossing: 10650.00ft NO 8955.9011 TVc[ \, . . _ ........>...... \ \, ~nd Oir, Start Sail @ 88.797· : lOCi':;: -¡<¡.r,MD '11:0 ~9~:r\"P _ j \ .~',........ \ \'\ r.!ul'.'~:':j::.'rèf,·n·:}::;;:;;~r¡ jl'-;'~l1rJD :\~~,))JnTVD . 0-0 \, \ \, í.... .Begin 6-1/S" Hole Size ,'$-.?J4/1tþO~~';;"""~-\\ '-. _. ~\\:-"-':~"-:.,-~._. -¡'.,.. \\ L '\,oo.c-o , . ,! -~ ,- ,,,""~ \-.5073 '94033 ,. \9(>0" ~"'C<)...... \. ,.-' - - '- ~ 15-23AFault#3' ---:".·-'is:23Â·F-;;lt#2 . -. .~ """.'~, 8305.98ftTVD ..... / 15-23A Fault #1 ",-"".w '.. 15-23A WP03 T1 DD Poly @ 95% MWD+IFR+MS 15-23A'WP03 T2 15.23A '."1;03 T1 15-23A WP03 T1 Geo Poly 8955.90ft rVD 8930.9Oft TVD 595.21 S, 4240.87 W 599.12 S, 3050.64 '."I /" I -5600 -4900 Scale: 1 inch = 700ft o DDI 5.6 - - ST Exit: Dir@ 12.000·/1000, High Side TF : 4000.000 MO, 3999.700 TVD . Begin 8-1(2" Hole Size Begin Dir@4.000·/10Oft: 4020.00ft MD. 4019.69ft TVD \ // End Dir, Start Sail @30.398' : 5045.02ftMO,4979.S1ftTVO. ............" \ / l .~ 1S-23A WP03 T3 TO 8955.901t TVD 284.68 S, 5155.84 W I -4200 I -2800 Eastings(Well) -1400 -700 0 Reference is True North I -2100 -3500 ~r~..-.y-!!SU'1 North Slope Alaska Cf~.L..r.""1fíi» :iV'"1.J"':Vt(-~~ BPXA ., tlli!lÞ<iW1 ~'f - ëV ß ..c Õ. 6500 Q) o ëõ ü :e Q) > 4= g 8500 o II ..c ü .S Qj ëõ ü if) 9500 ~~~3¡~~: 15DFiJ1Q"es·t~ 15-23A WP04 Proposal Data Vertical Origin: Horizontal Origin: Measurement Units: North Reference: Well Well ft True North Dogleg severity: Degrees per 100 feet (US Survey) Vertical Section Azimuth: 277.270" Vertical Section Description: Well Vertical Section Origin: 0.00 N,O.OO E 4500 r"" ~"I'~"'~';')'- -.-.-.-- ŠV1.,,~ 7r:¡f!T~ \':" 'Begin 8-1/2" Hole Size , ",." ':-ST Exit: Dir @ 12.000·'100ft. High Side TF : 4000.00ft MD, 3999.700 TVD !!.<'..4. '1.~¡~' íf.ð'q '~.':.gin_..~.~r ~.~~.OOO:'.~~Oft_:~02~~~ft ~~.:. 4019.69ft TVD ui'" J";n 11:¡;-¡''O'- . - -. - . - . - . - -'~", ,'J \ ~., > / End Dir, Start Sail @ 30.398' : 5045.02ftMD,4979.81ftTVD ~.u \ \ UG1." 5~·7~~I~it-f{Ò···- -- _. - . - . - - \."<,,, \ \ \"""'J 'ë"iX3'- ij;;'~'¡ ié~T'¡D .-..\ ---. " . \ \ -. -. -. -. \\".'''''-' ~..~\<:) C!A¿. 1)1)9(" 9[tft rVD _~~.. ~'> \ ~ \ ~ # # ~"'", ", ~ Oj$- ..""~<:) ~... \ ¿;~0 OJ.{;.ry. 9~"" b~~t§ 9<:.'ò?i CM!. ï42?, ijr;7tTv6 - . - \ :J..0 s:,'{-" ~<:)'? ~ Æ)'? \ ~~f~~~~dD ,,~o ~~<:j 'ò~'" ,&-~<:)' ~~"<:'. ~<:) ri"jj·,'1., '}'i¡ ') 9',)'1;-7\/0 --.... -- 2.~OO 8305.98ft TVD "o!'~ <o~~ ~ ",,,,,,,,. ~ <0,>0) ~ ...."O~ry. ~ OJ'''~ ß.t!fV ..7.I!.fP,9.f!!JJVD.._.. ì,w:"" ~~ @¡ ~ ." ~ ....~ '!:- ~ . ...... ~c; . . \= . ø <:l ¡§:- !\' ,,~"-:.- ...... ,,~ ".... ,,'I! Lcu¡i.JC:- ·8'11.UUfi ¡vn if ",ry<:;$ t§>~0) <o~"'~ s:,"-:.- t?'ò~ s:,,>v ~~v /fQ'li .'!f' .~@¡ .."(:S ~~<:s ...."'@¡O)<»ol;j - - ~" ~ s:,v ~. .~ ~... . Æ;j~~~ ;f~Ž:I: ~;.~~. ;~~~g = .' ,.= _ /// ,p"'~""~ -ø?:- ~1i ,p",;f @¡ <o~ ,p"'<'.s< ....'l>~ ~'b' . .....ry ~. ~'{i·..('! ~s, 8324:90;' rvp _ _ ".""ó;".,.",,,,,,.. """" '"'0 ..~ - ",t''' .Q~~ "'~o "Q" ",,ç." .<t~ ,.Q"'" := := :=~ /" r ~, «3:;;~\ <" ~gftM,¡àEIIi; ;f~,~t:¡~;.>tl, ~":" ~/~~'2rf;;~" ï'''''' ;;'23i:;:~\ -----------~-~ Measured Depth Incl. Azim. Vertical Northings Depth 0.522 112.375 3999.70 23.77 S 2.922 112.375 4019.69 23.99 S 30.400 242.000 4792.57 130.70 S 30.398 259.175 4979.81 166.80 S 30.398 259.175 8453.33 549.53 S 88.797 270.188 8930.90 599.12 S 88.797 270.188 8955.90 595.21 S 90.301 293.308 8958.98 5LÎ.12S 90.301 293.308 8955.90 284.68 S 4000.00 4020.00 4828.35 5045.02 9072.17 10055.88 11246.39 11632.52 12219.98 5500 RKB Elevation: __________________u.. Eastings Vertical Section 27.78 E 28.33 E 137.63 W 240.07 W 2241.59 W 3050.64 W 4240.87 W 4616.33 W 5155.84 W -30.56 -31.14 119.98 217.03 2154.03 2950.30 4131.46 4513.78 5078.37 Well: Current Well Properties 15-23A WP04 -- -- -- Horizontal Coordinates: Ref. Global Coordinates : Ref. Structure Reference . Ref. Geographical Coordinates : North Reference: Units: 7500 ll~L ·~t~.~~T·fJß-...·~· !..?.!.B. !!.~!i' .9'!!!...!YD_. 'IZ1ft 1l!l!i \iiiJIrIV!J =: . f3$AD. fjg~ ij¡Jir TVD 4 1i2ín liner 12219.98ft MD 8955.900 TVD o Scale: 1 inch = 1000ft I 1000 15-23A WP03 T1 8930.90ft TVD 599.12 S, 3050.64 W I 3000 4000 Vertical Section (Well) I 5000 6000 Section Azimuth: 277.270° (True North) 15-23A WP03 T2 8955.90ft TVO 595.21 S, 4240.87 W 15-23A WP03 T3 TD 8955.9(jft TVD 284.S8 S, 5155.84 IN I 2000 .,.. .....................,.. Dogleg Rate 12.000 4.000 4.000 0.000 6.000 0.000 6.000 0.000 --- 5960105.48 N, 676210.75 E 1269.70 N, 57.46 W 70c 17' 47.7256" N, 148034' 22.8594" W 60.9Oft above Mean Sea Level 50.90ft above Structure Reference True North Feet (US Survey) ___J --- ~.. II ..~..., North Slope Alaska PBU - EOA DS 15 Drill "est' !..t~)¡ L. k,.:l1J.1IJ ..~vt~-~ BPXA 15-23A WP04 .,tk""JII"!('_'f . . _.__"'_'~M..__m__..__._...h__h'·.'·'_·_··_·___·_"___" 15-23A WP04 Target Data ---- --- Measurement Units: ft Target Coordinate TVD Northings Eastings SSTVD Northings Eastings Target Name Point Type Well Well Well MSL ASPY ASPX Shape (ft) (ft) (ft) (ft) (ft) (ft) J 5-231\ Fault # I Entry Point 8945.90 454.52 5 2776.17 W 8885.00 5959586.00 N 673446.00 E Polygon BoundaJ} Point A 8945.90 454.52 5 2776.17 W 8885.00 5959586.00 N 673446.00 E B 8945.90 809.83 S 2596.45 W 8885.00 5959235.00 N 673634.00 E C 8945.90 454.52 S 2776.17 W 8885.00 5959586.00 N 673446.00 E 15-23/\ WP03 1'1 DO Poly Entry Point 8930.90 599.]25 3050.64 W 8870.00 5959435.00 N 673175.00 E Polygon @ 95% MWD··HFRt-MS . Boundary Point A 8930.90 725.70 S 2430.43 W 8870.00 5959323.00 N 673798.00 E -. B 8930.90 619.05 S 3011.09 W 8870.00 5959416.00 N 673215.00 E C 8930.90 676.37 S 3808.65 W 8870.00 5959340.00 N 672419.00 E D 8930.90 664.88 S 4554.59 W 8870.00 5959334.00 N 671673.00 E E 8930.90 493.72 5 5241.ï7 W 8870.00 5959489.00 N 670982.00 E F 8930.90 221.21 5 5132.35 W 8870.00 5959764.00 N 671085.00 E (J 8930.90 437.93 5 4464.24 W 8870.00 5959563.00 N 671758.00 E H 8930.90 503.28 S 3810.60 W 8870.00 5959513.00 N 672413.00 E I 8930.90 468.40 S 2994.56 \V 8870.00 5959567.00 N 673228.00 E J 8930.90 601.20 S 2407.51 W 8870.00 5959448.00 N 673818.00 E 1 5-23A WP03 l' J Geo Poly Entry Point 8930.90 599.125 3050.64 W 8870.00 5959435.00 N 673175.00 E Polygon Boundary Point A 8930.90 661.97 S 2204.88 W 8870.00 5959392.00 N 674022.00 E B 8930.90 418.405 2695.30 W 8870.00 5959624.00 N 673526.00 E C 8930.90 460.18 S 3899.61 W 8870.00 5959554.00 N 672323.00 E D 8930.90 397.63 5 4519.32 W 8870.00 5959602.00 N 671702.00 E E 8930.90 80.34 S 5381.11 W 8870.00 5959899.00 N 670833.00 E F 8930.90 489.36 S 5427.72 W 8870.00 5959489.00 N 670796.00 E G 8930.90 714.84 S 4769.82 W 8870.00 5959279.00 N 671459.00 E H 8930.90 731.74 S 3835.96 W 8870.00 5959284.00 N 672393.00 E 1 8930.90 664.62 S 3030.17 W 8870.00 5959370.00 N 673197.00E J 8930.90 688.52 5 2906.69 W 8870.00 5959349.00 N 673321.00 E K 8930.90 794.02 5 2332.01 \\1 8870.00 5959257.00 N 673898.00 E ..~ 15-23A Fault #2 EntIy Point 8950.90 397.23 5 3811.11 W 8890.00 5959619.00 N 672410.00 E Polygon Boundary Point A 8950.90 397.23 S 3811.11W 8890.00 5959619.00 N 672410.00 E B 8950.90 722.64 S 3541.67 W 8890.00 5959300.00 N 672687.00 E C 8950.90 397.23 S 3811.11 W 8890.00 5959619.00 N 672410.00 E 15-23A WP03 T2 Enhy Point 8955.90 595.21 5 4240.87 W 8895.00 5959411.00 N 671985.00 E Point 15-231\ Fault #3 EntlY Point 8955.90 279.54 S 4649.58 W 8895.00 5959717.00 N 671569.00 E Polygon Boundary Point A 8955.90 279.545 4649.58 W 8895.00 5959717.00 N 671569.00 E ß 8955.90 761.06 S 4334.79 W 8895.00 5959243.00 N 671895.00 E C 8955.90 279.54 S 4649.58 W 8895.00 5959717.00 N 671569.00 E 15-23/\ WP03 1'3 TO Entry Point 8955.90 284.68 S 5155.84W 8895.00 5959700.00 N 671063.00 E Point _ ._....._._.._.._.__._u.__._..___........_._....___n___~ ,..... ",.,... ...................... .......,... DrillQuest - 1 - 11 July, 2003 - 12:11 .~.._"....._,_ "':'''~_~__''--:-_ 'U",:,""_' ..~__ ._....~ ........._... ."':'" _.__ . _·--·_·1·....---......·_·_-~·.'..... _.. . --" u_.. .-..-..-.--.-..-....-.--:--.- .-." .~----- - ~ ~_.- ~--~- -.-- ----..~..-_.~_.._-_......-..-......---.--..-..-.-.-..-~............--..-......,.-.. .-.-.-..-.....-. "'--""'1 MD·· Delta. ·Inclin. Azimuth TVD Delta; Northings . Eastings ; Dogleg A. Build .1 A Turn Toolface VS (277") i .(ft) MD (ft). (0) . (") . (ft) TVD (ft) . (ft) (ft)·· C'/100ft) ·C/100ft) J(O/100ft) . (")' (ft). ¡ .---"""1.................-.....................--.--.......--......--....,,-....-----.--.....I...,----;......-....--:---..,..-.:-.~':""".-.- ..-. .... . _____._M.._....._~---....._..·· ........~._M__--..---..._J .-.:-J.__.._~~.~~.:.~gO.52 .112.~7 .:3999.70 ·~3.77S ·27.78E '. ~ . ~30.6! ~...' 4020.00..._ .....2.~:_Q~ '2.92' 112.37 4019.69 19.99, 23.99 S 28.33 E . ....1~.~O..:· 12.~O: . :O.OO"L .___ 0:2..9.. . ~31.1 i . 3 4828.35:,,".ß9.~..:.~?._ 30.40 242.00 4792.^57 772.88 130.70 S 1"37.63 W _'_'''M~':'OO 3,40 16.0~;_"....1..~~..:?2 120.0) 4. 5045.02 21.6.67 30.40' 259.17 4979.81 187.24: 166.80 S· 240.07 W 4.00 . O~OO:·· 7.93'. 97.43 217.0] . 5 9072.17 4027.15. 30.40 259.17 8453.33 3473.53 549.53 S 2241.59 W 0.00 0.00 0.00 0.00 2154.01 6T 10055.88 91:33.72 88.80 270.19 8930.90 477.57 599.12S 3050.64W 6.00 ·5.94 1.12 12.87 2950.3! r7T~' 11246.39 1190.50"·~"·ãã~äor "·-27Ò~·1'9r8955·.90: .25.001 595.21-Sr"4240,87-W¡·"·'·"·Õ",·ÕÕ! 0.00 0.00: 0.001· 4131.5: , ' " , .___.....,,,,,,........,. -.-"..,,-,..--.--..--...-...-,--------......................................... , " " I '8 11632.52· 386.13' 90.30 293.31 8958.98 3.08 517.12 S . 4616.33 W 6.00 0.39 5.99 86.42 4513.8: I ~T 12219.98 587.46 90.30 293.31 8955.90 '·3.08 284.68 S 5155.84 W 0.000..00 0.00 0.00 5078.41 ) ) Sperry-Sun Drilling Services Proposal Data - 15-23A WPS - 15-23A WP04 Approved Plan ) 15-23A Sidetrack and Complete Procedure Summary Pre-Rig Work In preparation for the sidetrack the following pre-work has been performed: ./ Failed TIFL - 11/24/02 ./ 3-1/2" Tubing tail plug set in SWN nipple @ 8526' - 12/26/02 ./ MITOA passed to 2000 psi - 4/11/03 ./ PPPOT - T passed to 5000 psi and PPPOT -IC passed to 3000 psi - 4/11/03 ./ LOS on both hangers function tested ok and torqued to 500 ft-Ibs ./ Failed CMIT TxlA - 4/17/03. Calculated LLR of 2 GPM. ./ Obstruction found in 3-1/2" tubing at 6714' SLM. Remaining Work: 1. Chemical cut the 3-1/2", 9.3#, L-80 tubing above obstruction. 2. Fluid pack T X IA with seawater and freeze protect same. 3. Function all lock-down screws. Repair or replace as needed. 4. Remove the well house. If necessary, level the pad. Please provide total well preparation cost on the handover form. Rig Operations: 1. MIRU N2es. 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull 3-1/2" tubing from above pre-rig cut. 5. RIH with burn shoe and 100'-120' of wash pipe. Burn over tubing to verify 00. 6. RIH with external tubing cutter and 100'-120' of washpipe. 7. Washover damaged tubing and perform external cut below damaged section. 8. POOH with damaged tubing section. 9. RIH with overshot and engage tubing stub. 10. RU slickline. RIH and retrieve 3-1/2" PXN plug from SWN nipple at 8526'. 11. RU eline. Chemical cut tubing at 9420' MD. 12. POOH with tubing fish. 13. RIH with 7", 29# cement retainer and set at 9370' MD. 14. P&A existing perforations and slotted liner with 50 bbls cement. Obtain squeeze. 15. Unsting from retainer, reverse circulate clean, and POOH. 16. RIH with 7" Baker bottom trip whipstock assembly. Orient whipstock and set on cement retainer. 17. Swap over to Quickdril milling/drilling fluid. 18. Mill window in 7", 29# casing at 9350' MD. Perform FIT. POOH 19. MU 6" BHA with Dir/GR/Res/ABI/Den/Neu and RIH. 20. Drill the 6" production interval building at 12°/100' to horizontal, targeting Z1A Ivishak. Drill ahead to an estimated TO of 12,726' MD. 21. Run and cement a 4-1/2" solid liner throughout the 6" wellbore and back into the 7" liner. 22. Displace well to clean seawater. 23. RIH with DPC perf guns. Perf intervals to be determined from LWD logs. 24. POOH. LD DP and perf guns. 25. Run 4-1/2", 12.6#, Chrome completion tying into the 4-1/2" liner top. 26. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 27. Set and test TWC. 28. NO BOPE. NU and test the tree to 5000 psi. t\ I ,) ') 29. Freeze protect the well to -2200' and secure the well. 30. RDMO .Post-RiQ Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod 1 RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves t \ Il~ mr~ f~ ~ I~ ~ LS ~ lJ lA.\ b lrù ~J ,..l AItASIiA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE,SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit, 15-23A B.P. Exploration (Alaska) Inc. Pennit No: 203-111 Surface Location: 1382'SNL, 274' EWL, SEC. 22, TI1N, R14E, UM Bottomhole Location: l668'SNL, 4882' WEL, SEC. 21, TllN, R14E, UM Dear Mr. Isaacson: Enclosed is the approved application for pennit to redrill the above development well. This pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this permit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~ L 6; ~driCh ~ V[ Commissioner BY ORDER OF THE COMMISSION DATED this ~ day of June, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section îtJl1A- /P/I?/-z..CJ03 ì a. Type of work 0 Drill 181 Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at su rface x = 676211, Y = 5960105 1382' SNL, 274' EWL, SEC. 22, T11 N, R14E, UM At top of productive interval x = 673175, Y = 5959435 1982' SNL, 2778' WEL, SEC. 21, T11N, R14E, UM At total depth x = 671063, Y = 5959700 1668' SNL, 4882' WEL, SEC. 21, T11 N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028305,397' MD 15-04 is 620' away at 11887' MD 16. To be completed for deviated wells Kick Off Depth 9350' MD Maximum Hole Angle 18. casingJ;~gram Specifications Hole CasinQ Weiç¡ht Grade CouDlina 6" 4-1/2" 12.6# L-80 IBT-M " STATE OF ALASKA '. \ ALASKA_.l AND GAS CONSERVATION COMfvh_J;ON PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 181 Development Oil / o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool Plan KBE = 60.9' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028306 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / 15-23A _ 9. Approximate~ptJ'êf 9ate prlÓ4/)J5 Amount $200,000.00 14. NumberGf-a6es in property 15. Prcyosed depth (MD and TVD) 2560 12602' MD / 8956' TVD o 17. Anticipated pressure {s,ee 20 AAC 25.035 (e) (2)} 90 Maximum surface 2396 psig, At total depth (TV D) 8895' I 3285 psig Setting Depth Top Bottom Quantity of Cement Lenath MD TVD MD TVD (include staae data) ~ .9a5ð' 8705' 12602' 8956' 377 sx Class 'G' :r4()'¡': 'too' tµfJÍ;r 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Liner 11500 feet 8963 feet 11243 feet 8970 feet Length Plugs (measured) RE,CE\VEO JUN 1. 9 2.003 Multiple Fish - See Diagram ¡"'W'W Comm\SS\on Maska em FA ßas, UI\)1II,.1>" Cemented MQ\nchorage TVD Junk (measured) Size 110' 20" 110' .¡ 110' 3518' 13-3/8" 1329 sx CS III, 400 sx 'G', Top Job: 100 sx CS II 3518' .I 3518' 8720' 9-5/8" 1435 sx Class 'G' 8720' 8375' 2291' 7" 470 sx Class 'G' 8309' - 10600' 8068' - 8979' 1164' 4-1/2" Uncemented Slotted Liner 10109' - 11273' 8928' - 8970' Perforation depth: measured Open: 10026' - 10066', 10150' - 10170', 10225' - 10250', 10260' - 10285', 10320' - 10345', 10395'- 10420'; Slotted Liner: 10324' - 11227' true vertical Open: 8917' - 8922', 8932' - 8935', 8941' - 8944', 8945' - 8948', 8953' - 8956', 8963' - 8965'; Slotted Liner: Slotted Liner: 8953' - 8970' 20. Attachments 181 Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 181 Drilling Program 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 181 20 AAC 25.050 Requirements Contact Engineer Name/Number: Rob Tirpack, 564-4166 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 Billlsaacson ~ ~.. A ~ t('u.. _ Title Senior Drilling Engineer Date Jv.., E. \8, 2a:l~ ·c.···.. c,.,::· ·.·....c;::çQritro..ic:Þn:.tJ$etii~.· Permit Number API Number 2.0 3.- / / / 50- 029-22225-01 Conditions of Approval: Samples Required 0 Yes 'E No Hydrogen Sulfide Measures 'ßI Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other: i-€.s t- ]~ I) f to ·~S'OO 'P ~ . ¡fi> ~ by order of Approved B, y 1J~1.t.A-RcL ~ <t0plT1jì1l01eJ\ L the commission Form 10-4iBð'WK DC 20. 0 K \ \j , \ \ 1-\ ApyrovaI Djte See cover letter Ço( ~ / ~ 5 for other requirements Mud Log ReqUired 0 Yes ~ No Directional Survey Required EYes 0 No o 4K D5K D10K D15K 0 3.5K psi for CTU Date ¡, /¡¡-c;::> / CJ 7 Submit In Triplicate ) ) Well Name: 115-23A Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: Estimated Target Location: Ivishak Zone 1 A Bottom Hole Location: x = 675,210.75 Y = 5,960,105.48 , 1382' FNL 274' FWL Sec. 22, T11N, R14E Umiat /' X = 673,175 Y = 5,959,435 TVDss 8885' 1982' FNL 2502' FWL Sec. 21, T11 N, R14E Umiat ./ X = 671,063 Y = 5,959,700 TVDss 8895' 1668' FNL 397' FWL Sec. 21, T11 N, R14E Umiat ,/' I AFE Number: I PBD4P2097 I I Estimated Start Date: 107/04/03 I RiQ: I Nabors 2ES /' I OperatinQ days to complete: 118.5 I MD: 112,602' I I TVD: 18956' I 1 GL: 132.4' I I KB: 128.5' I I KBE: 160.9' I Well DesiQn (conventional, slim hole, etc.): 1 Single String Horizontal Sidetrack I Objective: I Ivishak Zone 1 A/1 B Formation Markers Formation Tops (wp01) MD TVD TVDss Comments TSAD - Zone 4B 8775' 8405' 8344' Hydrocarbon bearing 7.1 ppg EMW SAD - Zone 2 9234' 8651' 8590' Hydrocarbon bearing 7.1 ppg EMW /' Kick Off Point 9350' 8705' 8644' Hydrocarbon bearing 7.1 ppg EMW ~,(p (i~ SAD - Zone 1B 9894' 8853' 8792' Hydrocarbon bearing 7.1 ppg EMW SAD - Zone 1A 10176' 8901' 8840' Hydrocarbon bearing 7.1 ppg EMW TO 12602' 8956' 8895' Hydrocarbon bearing 7.1 ppg EMW TD Criteria: Based on 1000' of perfable sand in horizontal. Geo polygon is hardline. Directional - Sperry wp03 KOP: \9,350' MO Maximum Hole Angle: Close Approach Wells: Survey Program: 15-23A Permit to Drill -900 in 6" horizontal section. Wells 15-04 (currently shut-in) and C-32A (P&A'd) pass BP anti-collision policy when risk based at 1/200. C32B passes Major risk if 15-23A is drilled with IIFR+MS. MWD with IIFR+MS (Casandra) Page 1 ) ) CasinQITubinQ Pro~ram Hole Size CsglTbg WtlFt Grade Conn Length Top Btm O.D. MDITVD MDITVD 6" 4-1/2" 12.6# l-80 IBT-M 3252' 9,350'/8,705' 12,602'/8956" ,,,/ Tubing 4-1/2" 12.6# 13Cr80 VAM ACE 9,322' Gl .~/8,705' quo· ~ 4/r- Mud ProQram Section Milling Mud Properties: Quickdril I Density (PPJ> Viscosity PV VP MBT PH API FI 8.4-8.7 55-65 7-11 30-40 <3 8.5-9.0 N/C Production Mud Properties: Quickdril Density (ppg) Viscosity PV VP MBT pH API FI 8.3- 8.6 45-55 4-7 20 - 28 <3 8.5 - 9.0 N/C LOQQinQ Program 6" Production: Sample Catchers - over entire interval, samples described Drilling: Dir/GR/ABI- Real time; Den/Neu - recorded mode Open Hole: None Cased Hole: None Cement ProQram Casing Size I 4.5" 12.6#, L-80 Production Liner Basis: lead: None Tail: Based on 80' shoe track, 3252' of 4-1/2" X 6" open hole with 400/0 excess, 150' 4-1/2" X 7" Liner lap, and 200' of 7" X 4" DP excess. Tail TOC: 9ð8O" MD (Tal) ./ I Total Cement Volume: (ftoo' lead None ,/,/'"Î","'-j ¡,r.J4¡I- Tail 78 bbls, 437 ft3ß, 7,' v~acks Class G@15.8ppg(1.1ß1t3/sack L¿' c./' 15-23A Permit to Drill Page 2 ) ) Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Oiverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casingn" Liner Test Integrity Test - 6-1/8" hole Planned completion fluids 3285 psi (7.1 ppg @ 8895' TVOss) 2396 psi (.10 psi/ft gas gradient to surface) Infinite with 9.5 ppg FIT /' Rams test to 3,500 psi/250 psi. /' Annular test to 2,500 psi/250 psi" 3500 psi surface pressure / 9.5 ppg EMW FIT 8.4 ppg Seawater / 6.8 ppg ~iesel /' Disposal . No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to 08-04 for injection. Haul all Class I wastes to Pad 3 for disposal. 15-23A Permit to Drill Page 3 ') ) Sidetrack and Complete Procedure Summary Pre-Ria Work 1. Pull tubing plug from nipple at 8526' MD 2. Set Cement Retainer in 3-1/2" tubing at 9600' MD. 3. P&A existing perforations and slotted liner with 45 bbls cement from PBTD to -9600' MD 4. Drift 3-1/2" tubing and tag top of cement retainer~,.,,-] 5. Chemical cut the 3-1/2", 9.3#, L-80 tubing ~. ,"".4'9'37Ç>7'MD. 6. Fluid pack T X IA with seawater and freeze:.p-rQ.tett same. 7. Pressure test T XIA to 3500 psi for 30 mins. 8. Function all lock-down screws. Repair or replace as needed. 9. Remove the well house. If necessary, level the pad. Please provide total well preparation cost on the handover form. RiCl Operations: 1. MIRU N2es. 2. Pull BPV. Circulate out freeze protection and displace well tp.-seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. /' 4. Pull 3-1/2" tubing from above pre-rig cut. 5. Rig up e-line. Make GR/JB run to top of 3-1/2" tubing stub. 6. RIH with 7" Baker bottom trip whipstock assembly. Orient whipstock and set on tubing stub. 7. Swap over to Quickdril milling/drilling fluid. . 8. Mill window in 7", 29# casing at 9350' MD. Perform FIT. POOH /' 9. MU 6" BHA with Dir/GR/ABI/Den/Neu and RIH. 10. Drill the 6" production interval buildjDg at 12°/100' to horizontal, targeting Z1 A Ivishak. Drill ahead to an estimated TD of 12,602' MD. /" 11. Run and cement a 4-1/2" solid liner throughout the 6" wellbore and back into the 7" liner. 12. Displace well to clean seawater. , 13. RIH with DPC perf guns. Perf intervals to be determined from LWD logs. / 14. POOH. LD DP and perf guns. ,..' 15. Run 4-1/2",12.6#, Chrome completion tying into the 4-1/2" liner top. ,/ 16. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 17. Set and test TWC. /' 18. ND BOPE. NU and test the tree to 5000 psi. 19. Freeze protect the well to -2200' and secure the well. 20. RDMO Post-Ria Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. 15-23A Permit to Drill Page 4 ) ) 15-23A Drilling Program Job 1: MIRU Hazards and Contingencies ~ No wells will require well house removal or shut-in for the rig move onto 15-23A. The closest neighboring wells are spaced as follows: 15-02 at -60' and 15-03 at -59'. Care should be taken while moving onto the well. Spotters will be used at all times. ~ Drill Site 15 is not designated as an H2S site. However, Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: #1 Closest SHL #2 Closest SHL #1 Closest BHL #2 Closest BHL Well Name 15-03 15-02A 15-01 A 15-48A H2S Reading No data 12 ppm 8 ppm No data Date N/A 03/30/01 03/04/01 N/A The maximum level recorded of H2S on the pad was 33 ppm at 15-44 in 03/23/96. ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP ;m.I.I,I,a;,:};,\JJ.I,'~m).I'AAI,lm:mm¡,mm,:,:mm,\I"»~},m!mmmmm,¡mm!,:)A»m;'A-.~-;':¡;',:};,-m¡;¡'-,-,IAAI¡.,).r.-!:.wnm;,I,I,-!'-;,Im,l¡m¡¡mm.¡;;ß¡m¡!Jmm¡.)w»mw.wm,',I,I,.w.I,I,D).r!Jm¡.)m~mmmmA:mm!AAŸ»mmmWA:mmAlmmW),I;!¡,I);!!;mmm-,-;;",-mmm,:mmfÇ.AA".-mmwm,ÿ",:,I;J~,!m¡m,I;Jmmmm¡.mw.m.Jm!,\MmK-m.:m¡'J.mAw.-m);.,-,rm.-;mmmmwm.r;m.Im.I!¡"I,I};.-¡,.-,~-m. Job 2: De-complete Well Hazards and Contingencies ~ 15-23 is currently Shut-in with a plug in the 'X' nipple above the production packer. Pre-Rig operations will include P&Aing the original perforations, slotted liner, and a portion of the 3-1/2" tubing with cement. After the cement work and tubing cut, the wellbore will be fluid packed, pressure tested and freeze protected. ~ Note and record required PU weight to pull tubing at cut point. ~ NORM test all retrieved well head and completion equipment. ~ Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP Job 4: Window Mill Hazards and Contingencies ~ The 3-1/2" tubing stub will be used to set the whipstock. ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP 15-23A Permit to Drill Page 5 ) ) Job 7: Drill 6" Production Hole Hazards and Contingencies )0> A pump out sub will be run in the BHA to aid in placing LCM material. )0> There are three (3) fault crossings in the production section. Details are listed below. Lost circulation is considered low risk. There are no LCM restrictions. Follow the lost circulation decision tree should LC become problematic. MD Intersect Est. Throw 10,068' 10 11,081' 15 11,900' 10 Fault #1 Fault #2 Fault #3 Throw Direction East West East Uncertainty 65' 80' 80' )0> There are three (3) close approach wells to be concerned with while drilling the production hole section. 15-04 was risk based at 1/200 to pass BP's anti-collision policy. 15-04 is currently shut- in due to high gas and low oil production. The closest center to center distance for 15-04 is 620'. C-32A was also risk based at 1/200 to pass BP's anti-collision policy. C-32A has been P&A'd. The closest center to center distance for C-32A is 642'. C-32B passes Major Risk when 15-23A is drilled with IIFR+MS (Casandra). The closest center to center distance for C-32B is 759' ~ KICK TOLERANCE: In the worst-case scenario of 8.3 ppg pore pressure in the Ivishak, a fracture gradient of 9.5,.ppg at the 7" casing window, and 8.5 ppg mud in the hole, the kick tolerance is Infinite./' Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP m,~,lm¡¡';,I~Jm,I¡.I~!,m.'AAWmmUAl;..l,lm~,I,vm;,~IAI,I,I.I,I,IÞA:,ø.:¡,:,1,:,1....,:,\1,1.-, .'.:¡!mm.-~,-,~~W,I,I,-,I,-p;'.,lmm¡,I,l,Im.I,'I,;¡,I.;¡,lmm.l..,l,"},Ammm;.-~,:m,:.-~,-,-m,-,I.I¡mmp.:mmm.lI-M¡.}p',:wmm::I,4:,·N.;,.mma,'m,;I,I~,I,I','III.I.I.I',:,I,:.-m,-,:¡,:m'-p'-,~-A-,-.lA-,l,Imm,I,I,:m,-,I,:.ijm~m,IAAlm;I.J.I.IAAI,I.u:;.w,l,lmmmm;"l,rm,:,I.I'¡,IJ,:¡.);.AW¡~-.I.I.I,I,IAWmk¡m,I~';':AAJ.IJ.IAIAW)mm.I,I,I,I,I.I',JJ.-,-;.}AA-!,I,:AI.I.I¡'¡1.l.1;,lmmm,l,lß!,I,I.I.I.I,IAA-A-P,:,:,;,:mm.I,lm.A' Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies )0> Differential sticking is a concern. The 8.6ppg mud will be -650psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. )0> Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate liner. ~ Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. Reference RPs .:. "Production Liner/Casing and Cementing Guidelines" .:. Schlumberger Cement Program 15-23A Permit to Drill Page 6 ) ') Job 10: DPC Perforate Production CasinQ Hazards and Contingencies ~ Observe Halliburton's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. Reference RPs .:. Follow Halliburton perforating practices and recommendations. .:. IIDPC Perforating" RP :1I~11I,1I,1~11,\_"I,II,:I!,I,I;,I!,IL,I__I,I,mllml,IIIII:111,11:,m:II~l:IllIlm;I,I,II-III"I:,I:,mlml;~mlmm,llllmlll1,\'I:II,:lmll,:ml,IIII:ln:lmL~ml:II::,II,',I,I,I,I,mll'1II,I,m,ml,IIIII,",II,UI,I~llc,mml\n,l,m:II:I,:'-:I,:-111,!I,II~ml,m~lImml~WW:I:IT'-,:I~,II:-llUllml,mUml!II~I,111U:I:--nl,mmJ,m,m~III,I:II~I.II~II",IU,_m,lInll"mlmllmll1m:mIIII/:UIII¡-,UI,III,ml,l,mmal\IUIIIII,u'U-I,mIlN-:CJ.m:,III,III,'1-----1\11I.--,:111,11111111,1" Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP hM';;'I~,.,.,,.,.;m~~.-m'~.-,I,-",-.,,-.-mAA-mm,lnmmmmm"mmmmmmmmA"¡~¡!m¡!¡AAI¡¡,I;,WJ.I,I.'m,Iw.W,,D),,:,,'I,:;"!,I,'.-¡m,l.I',1.I.I,IAI,I~Al,IJm,lmm',:,I,I,I,IAI,'ß,-,:AW"I}."'-',lmw.,Iß¡!¡;"!~'¡,1;.J¡~','IJ)f.};.~¡.,;.m:-p;;;;,-:».-~::mmmmm"mmmm»;,lm,I!:A:!!.m.-;-:,I!mmlm!'>,lmm,:m,'Almm.D)l,W,I,I.I.WA~,I,I.l:-.I¡m"':"-',-m:J!c¡'}"OO¡"!ml,,"~AlOO,lm,:,DM;!AA-,-,...-mmM-~MD),I~;AI.'-.I;";mm;,m!!,I;.J,I;,Ç,I;,I¡;.,I!,-" Job 13: ND/NU/Release Ria Hazards and Contingencies ~ No wells will require well house removal or shut-in for the rig move onto 15-23A. The closest neighboring wells are spaced as follows: 15-02 at -60' and 15-03 at -59'. Care should be taken while moving onto the well. Spotters will be used at all times. Reference RP .:. "Freeze Protecting an Inner Annulus" RP 15-23A Permit to Drill Page 7 ) ') 15-23A Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Production Hole Section: · There are three (3) fault crossings expected in the production hole section. Lost circulation risk is low. Use LCM Decision Tree in the event of losses. Fault #1 Fault #2 Fault #3 MD Intersect 10,068' 11,081 ' 11,900' Est. Throw 10 15 10 Throw Direction East West East Uncertainty 65' 80' 80' · There are th ree (3) close approach wells to be concerned with while drilling the production hole section. 15-04 was risk based at 1/200 to pass BP's anti- collision policy. 15-04 is currently shut-in due to high gas and low oil production. The closest center to center distance for 15-04 is 620'. C-32A was also risk based at 1/200 to pass BP's anti-collision policy. C-32A has been P&A'd. The closest center to center distance for C-32A is 642'. C-32B passes Major Risk when 15-23A is drilled with IIFR+MS (Casandra). The closest center to center distance for C-32B is 759'. · Unexpected Faulting could cause drilling out of zone. Monitor drilling trends and cuttings. . Kick tolerance is Infinite. · Differential sticking had been experienced in other long horizontal sections. Keep pipe moving at all times. HYDROGEN SULFIDE - H2S · This drill-site not designated as an H2S drill site. Recent tests indicate a very low concentration of H2S. As a precaution, Standard Operating /' Procedures for H2S precautions should be followed at all times. CONSULT THE DS15 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 15-23A Permit to Drill Page 8 l'REE = WELLHEAD = "AcTUATOR';;'" KB. ELEV = ........,..............,............ "" BF. ELEV = KOP= Max Ångle:: "BaiÙíTi'MÖ';"'^"'" DatumlVD = FMC MCEVOY ········ÖfiS ''''''''''''69:6; .... .", .. ...... ..... ··..·.."".w·.., I, ') 15-23 )AFETY NOTES: 9654-10093', ID=2.70"- (;EMENT SHEATH LEFT AFTER MILLING. HORIZONTAL COMPo 4558' 92 @ 11377' ·············'9788; .............. ............,...."..."..,............ 8800' SS (I) 2161' 1-1 3-1/2" CAMeo TRDP SSSV NIP, ID = 2.81" 1 GAS LIFT MANDRELS ST MD lVD DEV TYPE VLV LATCH PORT DATE .. 1 3145 3145 1 MMG-2 RK · *2 4971 4957 14 MMG-2 RK 3 6355 6258 20 MMG-2 RK 4 7204 7058 21 MMG-2 RK 5 7863 7672 23 MMG-2 RK 6 7986 7786 23 MMG-2 RKP *(RD- scale noted 2/15/96) CHEMICAL MANDRELS ST MD lVD DEV TYPE VLV LATCH PORT DATE 1 8154 28 MMGM-L TS RK 8526' 1-1 3-1/2" PARKER SWN NO-GO NIP, ID = 2.75" 1 13-3/8" CSG, 68#, L-80, ID = 12.415" 1-1 3518' ~ Minimum ID = 2.70" @ 9854' - 10093' L 3-1/2" PARKER SWN NOGO NIP I 3-1/2" TBG, 9.3#, L-80, 0.0087 bpf, ID = 2.992" 1-1 8007' ~c )( c L I TOP OF 7" LNR 1-1 8309' ~ I I ..I 9-5/8" CSG, 47#, L-80, 0.0732 bpf, ID = 8.681" 1-1 8720' ~ 10100' 1-1 3-1/2" TIW OVERSHOT SEAL ASSY, ID = 3.000" 13-1/2" TBG, 9.2#, 13-CR, 0.0087 bpf, ID = 2.992" 1-1 10109' 1- 10109' 7" x 4-1/2" TIW SS HORIZONTAL PKR 1 TOP OF 4-1/2" LNR 1-1 10109' FOR 4-1/2" SLOTTED LNR i TOP OF 4-1/2" LNR - SLOTTED 1-1 10324' 1 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" 1-1 10600' µ .. ~ PERFORA TION SUMMARY REF LOG: HES GR ON 06/22192 ANGLE A T TOP PERF: 86 @ 10026 Note: Refer to Production DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DATE 2-1/2" 6 10026 - 10066 0 05/27/99 2" 4 10150 - 10170 0 02/11/02 2" 4 10225 - 10250 0 02/11/02 2" 4 10260 - 10285 0 02/11/02 -, 1- 2" 4 10320 - 10345 0 02/11/02 10170' PERF GUN BULLNOSE LEFT (02/11/02) 2" 4 10395 - 10420 0 02/11102 (2"X6" w 15/8" THREAD) SLTD SLTD 10324 - 11227 SLTD 12/25/91 -, 11130' 1-1 CIBP 04/14/011 ~ 11200' 1-1 FISH - BOTTOM 1/2 OF HES (CIBP) BOlTOM OF 4-1/2" LNR - SLOTTED, -I 11229' 1 11.6#, L-80, .0155 bpf, ID = 4.000" 11243' 1- 4-1/2" RETRIEVABLE IBP (SET 04/02/95) PUSHED TO T.D. 4-1/2" LNR, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 1-1 11273' I TO 1-1 11500' 2.70" ID CEMENT SHEATH 9654' - 10093' DATE 12/25/91 12/13/00 01/22/01 05/01/01 02/14/02 04/03/02 REV BY COMMENTS ORIGINAL COMPlETION SIS-lsl CONVERTED TO CANVAS SIS-MD FINAL RN/KAK CORRECTIONS DDW/tlh ADD PERF & REMOVECIBP DDW/KK FISH DEPTH DA TE REV BY COMMENTS 02102/03 A TO/TP PERFS IN PKR SQZ PRUDHOE BAY UNIT WELL: 15-23 ÆRMIT No: 1911350 API No: 50-029-22225-00 SEe 22, T11N, R14E. 3641.4' FEL & 2937.84' FNL BP Exploration (Alaska) 3518' 8007' 8309' 8720' 10109' 10324' 10600' 11229' 11213' 11500' 15 3 Pre i9 NOTES: 9654~10093', CEMENT SHEATH lEFT HORIZONTAL COMP, 10100' .. 10170' 11130' 11200' 11243' 8. BP 1 pi II I 14-1/2" 'X' NiPple 3518' ~ 13-3/8", 68#, -~ , 1 1 VAM #4 ø 3200' TVD ø 1-1/2" - SV #3 - 5700' TVD - 4-1/2" X 1-1/2" - DV - 7450' TVD - 4ø1/2" X 1-1/2" - DV #1 - 8500' TVD - 4-1/2" Xi" - DV 8309' of -10' 8720' 4 .. 10600' " 7"X 9350' , 1 9370' 9600' 11 --- tool, ·.~,,'-v 16 2, I I ~ - I ! _I l -f:::f..;. I I -'- I I I . Ã . U' . "\J\Jim t&l"\.U in\..... .....'u..'" faX \.,,¡V'~.--'UU, £UV J.\..hJU '. j - I I -- ~f D -. ". 1. . 1.. 15 ---- 22 NOTES '- --:---- I, Vlf:Uo PO!lTlONS ARE BAS£!) ON RECOItO AS-BUIlT COORDfN,41ES OF wOOUL£ .17-~51 PUNG. 2. COOROtNA T£S SHowÞI ARt AI A~A STA'TT' PLANE ZONE 4. ;\, Rf"F'FRfHCF fIELD BOOK: PI 91-51 (PC. 40-50). ... UA It.$ OF SURIIEY: 10/22" 10/23. 111\11. ;5 - a+ 2 . ~ (' 17. M- 15 - -. =t . .. - 1 - 24 - IJ -I' J.Þ ï ~ DRILL SITE 15 -20 _ 7 . II ..» . , -2:1 - 10 LOGATtO W''n-4IN PRO'MACTtD SEC. 22. T1tN, R1E. I.MoIIAT "C~OIAN. ALAS1<A. \ '\ 26 \ 27 I \ 28 , "v' 29 \30 :> 10/204/9' REV '40. DA T£ WELL A.5.P, NO. COOROS. 5,OðO,1œ.4ð 615,21075 1.3 5.V60,~'.10 818.128.87 5,861.151.18 1I~"7.79 : :i.lð1.273,eð I : 675.1140.JG L I :1.861..332.39 : 67:',"26.711 i . 5.e5v.810J'I¡ ð77,335.38 PLAN, COORDS. GEODETIC POSITION N 1~5.11 1017'.7.726" E 201.27 148'3<4'22.858" N 1.14.82 1017',1,1aa" l ~OI.CJ:¡ 148'34'24.14'" I\ 2334.!I¡ IU17·5e.I~" E 201.11 148")4'2t.222" I N 245-4.41 I 70'17'5;,27ï t ZOO.64 '/148"34'29.142" N 2514.~ 70-17'59.855 E 200.56 146''}<'3O.29i!'' N 714.51 70'17'44.$63- [12JO,7:) 14ð'J3'SO,Z8V' AS-BUlL T 0 NORTH SLOPE R£ViSIONS JAN 7 '92 14:53 C£U.AR 80( "I~V. ,u.4' 31.11' 32.2' 32.3' J'.4' 2e.2' LOCA TlOH IN SECTION 1 3112' fHL 274' 'lit\. 1030' rNL - 202' rM. 3Z'" t'N1. !Ie' rWL 201' F'NL 34' F'WL 14'" INL 22' F"Wl 17'03' FHl 'Jill' "'WI.. TB ùJ ORA~ CHECK .. f'f> ¿,¡ ¿ . I ! .. -¡ l ~ VICINITY MAP N,T.S. SURVEYOR'S CERTIFICATE HEREBY CERTlf'Y THAT AM PRO- PEI?L Y REGIe;¡ I,. h''' f1 ANn I/r.FN~m TO PRACTICE LAND SURVEYING IN "!HE STATE OF ALASKA AND THAT lHlS PlA T REPRESENTS A SIJRV£Y MADE BY ME OR UNDER MY OIRECT supeRVISION AND THAT ALL DIMEN- SIONS AND OTHER DETAILS ARE CORRECT AS Of OCTOBER 24, 1991. ~"""'of)!.1'...~ ..."\ \.......~ " ~ ~.. "-'!t~ · c,.. ~:r =- *l49D:i .\* ~ J -~,..... ..~ ~ ~~..:.. ..................~ ~ \\ "N..~1f'L ~l '= ~.... ~~ e. .. ~ ,,::_.......... "...~ ...""'lSIIOMt.\. \,; I.I\J{(\.'\..~,,' LEGEND . ExISTING WEU.S .. CONOUCTOft5 AS-BuILT '11 M$ ~Rv(Y F. ROBERT BELL & ASSOC. ARCa AI.ske Inc. ~þ DRILL SITE 15 CONDUCTOR AS-BUILT WELLS 23, 26, 27, 28, 29, & 30 1)ftAW«; _, ,.. ""' .......-.., Q4t\:ll' 10/24/91 BARNHART JACOBS ~: ..."", N'#, N.T.S. ;;l>pIÕo~' 'C~A-J751-004 _....rIAL: ~.u.u, PAJ017AA ~~'ar 1 r; 907 6595330 PAGE.002 COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGR.AM )¡;pili Fro Depth TQ Survey/Plan 935GJ)¡} 1:2601.63 PIantW: f5;-Z3A wpm V6 CrJ;1aicd:By: Ken Alloo Checked: Plan: ¡5.,23A wp03 tI5~2j/PkUî 15--Z3A) FORMATION TOr DETAILS No, TYDPaih MDPath Fortlliltío" BP A-moro Too' MWD+IFR+MS Reviewed; II WELL DETiULS - _"" """"" "'"'''''' L{}JWJ~ Slot NIA ¡5~23 J269Jt8 ~56.47 5%0I!ì5A8 61{û!!U5 ]O~J747J26N TARGET DETAiLS N"",""" """'" Ea..4tinz Slmpe II I I JP I I' , I ¡P ¡fliP SECTION DETAJLS +N/·S +EI·W See J 2 3 4 5 6 7 8 9 j(J MD TVD Ine Azj DLeg TF""" ¡ 2 3 4 No. TVD MD g955.00 12601.62 4!12" 84O\r- Stan Dir 121100' , 9350' MD, 8704.6'TVD Start Dir 8/100' , 9370' MD. 87!3.45'TVD 2000 2400 2800 3200 3600 4000 Vertícal Section at 266.84" [400ftlín] .woo 4S00 Date; 5!27!2ü03 D<lte;~ Date:_ vs.c Target 1 5·23A TL2 J 5-23A 12.2 J 5·23A T3.2 CASING DETAILS Name SIze 4.500 4 J12" . 15·23A wp03 ~ I ¡It J I ¡ J ! t i COMPANY DBTAILS REFERENCE iNr"ORMi\ nON SURVEY PROGRAM .tXwili Fm tkpth TI) StlmylP.mn 9350.00 126ùlÆi3 Pbm* lS-23A :wpQ3: V6 W~lIp.aih; {j5~411Pj.an 15-23A) BP Amoco MW(HifR-¡"MS Created By: Ken AJ1en Checked: Date: 5/2712003 Date:_ Reviewed; Date fJ l I' I' See MD Ino Axi 1 .I' 2 3 I 4 5 6 ,I 7 8 9 1fP I() ,I CASING DETAlLS JP No, TYD MD Namn II 8955,90 1260L62 4112" ""'" 'NI.s IS·23 1269$ß ~56A-7 ""'" WELL DETAfL.'ì Northing Eastin£: lJ¡tÜude 5960lO5A% 6162H175 7if11'47,726N LtJIIgiUll'!e Slot NiA TARGET DETAILS No«bi¡¡g Ea$ting S1wpø 59594J5.00 SECTION DETMLS TVD +NI-S +EI-W DLeg TFaco vSee Target 15-2M TL2 15·23A TL2 15·23A T3.2 FORMATION TOP DETAlLS Size No, TVDpath MDPath F<mnation 4.500 I 2 3 4 ·400 Start Dir 121100'; 9350' MD, 8704,6'TVD Start Dír 8/100',9370' MD, 8713AS'TVD :s ¢; ~ +' , '" ~ 1!f ¡¡ '" -800 -5200 ·4800 ·4400 ..¡ooo -3600 Wost(-)fEast(+) [400ft/in] -3200 ·2800 -2400 ~2000 ') BP KW A Planning Report MAP ) Company: BP Amoco Field: Prudhoe Bay Site: PB DS 15 Well: 15-23 Wellpath: Plan 15-23A Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Date: 5/27/2003 Time: 16:50:50 Page: Co-ordinate(NE) Reference: Well: 15-23, True North Vertical (TVD) Reference: 60.9060.9 Section (VS) Reference: Well (0.00N,O.00E,266.84Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5958837.36 ft 676296.98 ft Latitude: Longitude: North Reference: Grid Convergence: 70 17 35.236 N 148 34 21.213 W True 1.34 deg Well: 15-23 Slot Name: 15-23 Well Position: +N/-S 1269.88 ft Northing: 5960105.48 ft Latitude: +E/-W -56.47 ft Easting: 676210.75 ft Longitude: Position Uncertainty: 0.00 ft 70 17 47.726 N 148 34 22.859 W Wellpath: Plan 15-23A 60.90 4/22/2003 57548 nT Depth From (TVD) ft ___ __, ~_,,_____,__.__"_.·__,._..,_..,._·__w__.______,__,___ 0__ ____.______.,,___ 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: Drilled From: Tie-on Depth: Height 60.90 ft Above System Datum: Declination: Mag Dip Angle: +N/-S +E/-W ft ft ___~_,.._._,..____,._._.__..____,__ ___,,_._"____,..~._____..___~~_______M____._ .___._,_ 0.00 0.00 15-23 9350.00 ft Mean Sea Level 25.94 deg 80.84 deg Direction deg 266.84 -"..--..---.-.----.-...----..- Plan: 15-23A wp03 Date Composed: Version: Tied-to: 5/20/2003 6 From: Definitive Path Principal: Yes Casing Points MD TVD Diameter Hole Size Name ft ft in in 12601.62 8955.90 4.500 6.000 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 9233.75 8650.90 TZ2 0.00 0.00 9893.51 8852.90 TZ1B 0.00 0.00 10175.52 8900.90 TZ1A 0.00 0.00 11007.71 8944.90 BSAD 0.00 0.00 Targets Map Map <- Latitude -> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min See Deg Min See Dip. Dir. ft ft ft ft ft 15-23A T1.2 8930.90 -599.16 -3050.83 5959435.00 673175.00 70 17 41.827 N 148 35 51.778 W 15-23A Poly 8930.90 -662.02 -2204.72 5959392.00 674022.30 70 1741.211 N 148 35 27.117 W -Polygon 1 8930.90 -662.02 -2204.72 5959392.00 674022.30 70 17 41.211 N 148 35 27.117 W -Polygon 2 8930.90 -418.43 -2695.58 5959624.00 673525.90 70 17 43.606 N 148 35 41.426 W -Polygon 3 8930.90 -460.20 -3900.26 5959554.00 672322.60 70 17 43.190 N 148 36 16.538 W -Polygon 4 8930.90 -397.66 -4519.51 5959602.00 671702.10 70 17 43.801 N 148 36 34.588 W -Polygon 5 8930.90 -80.35 -5381.06 5959899.00 670833.40 70 17 46.916 N 148 36 59.706 W -Polygon 6 8930.90 -489.38 -5428.37 5959489.00 670795.70 70 17 42.893 N 148 37 1.076 W -Polygon 7 8930.90 -714.90 -4769.83 5959279.00 671459.30 70 17 40.680 N 148 36 41.878 W -Polygon 8 8930.90 -731.79 -3836.41 5959284.00 672392.80 70 17 40.519 N 148 36 14.673 W -Polygon 9 8930.90 -664.66 -3030.56 5959370.00 673196.80 70 17 41.183 N 148 35 51 .187 W -Polygon 10 8930.90 -688.56 -2906.98 5959349.00 673320.90 70 17 40.948 N 148 3547.585 W Company: BP Amoco Field: Prudhoe Bay Site: PB DS 15 Well: 15-23 Wellpath: Plan 15-23A Targets Name 15-23A flt#1 -Polygon 1 -Polygon 2 15-23A flt#2 -Polygon 1 -Polygon 2 15-23A T2.2 15-23A T3.2 15-23A flt#3 -Polygon 1 -Polygon 2 -Polygon 11 BP KW A Planning Report MAP Description TVD Dip. Dir. ft 8930.90 Plan Section Information MD ft 9350.00 9370.00 9734.28 10214.42 10441.91 10611.29 11338.91 11634.30 11885.56 12601.63 Survey MD ft 9233.75 9350.00 9370.00 9400.00 9450.00 9500.00 9550.00 9600.00 9650.00 9700.00 9734.28 9800.00 9893.51 9900.00 10000.00 10100.00 10175.52 10200.00 10214.42 10300.00 Incl deg 63.11 64.33 80.20 80.20 88.00 88.69 88.69 90.00 90.00 90.00 Incl deg 61.90 63.11 64.33 65.48 67.49 Azim deg 251.62 253.93 279.72 279.72 275.00 268.26 268.26 280.00 290.05 290.05 Azim deg 252.30 251.62 253.93 256.25 260.02 69.58 263.69 71.74 267.26 73.97 270.73 76.25 274.13 78.58 277.46 80.20 279.72 80.20 279.72 80.20 279.72 80.20 279.72 80.20 279.72 80.20 279.72 80.20 279.72 80.20 279.72 80.20 279.72 83.13 277.93 10400.00 86.56 275.86 TVD ft 8704.60 8713.45 8825.80 8907.52 8930.90 8935.80 8952.50 8955.90 8955.90 8955.90 TVD ft 8650.90 8704.60 8713.45 8726.18 8746.13 8764.44 8781.00 8795.74 8808.59 8819.49 8825.80 8836.98 8852.90 8854.01 8871.03 8888.05 8900.90 8905.07 8907.52 8919.93 8928.91 8945.90 8945.90 8945.90 8950.90 8950.90 8950.90 8955.90 8955.90 8955.90 8955.90 8955.90 +N/-S ft -687.08 -692.39 -707.89 -628.04 -599.16 -594.35 -616.48 -595.25 -530.20 -284.69 Sys TVD ft 8590.00 8643.70 8652.55 8665.28 8685.23 8703.54 8720.10 8734.84 8747.69 8758.59 8764.90 8776.08 8792.00 8793.11 8810.13 8827.15 8840.00 8844.17 8846.62 8859.03 ) Date: 5/27/2003 Time: 16:50:50 Page: 2 Co-ordinate(NE) Reference: Well: 15-23, True North Vertical (TVD) Reference: 60.9060.9 Section (VS) Reference: Well (0.00N,0.00E,266.84Azi) Survey Calculation Method: Minimum Curvature Db: Oracle +N/-S +E/-W ft ft -794.08 -2331.96 -454.55 -2776.35 -454.55 -2776.35 -809.88 -2596.62 -397.26 -3811.36 -397.26 -3811.36 -722.69 -3541.90 -595.25 -4241.15 -284.69 -5156.18 -279.56 -4649.88 -279.56 -4649.88 -761.10 -4335.06 +E/-W ft -2001.11 -2018.24 -2360.30 -2826.64 -3050.83 -3219.97 -3947.06 -4241.15 -4483.51 -5156.18 MapN ft 5959406.01 5959371.71 5959366.01 5959358.41 5959347.95 5959340.29 5959335.47 5959333.52 5959334.45 5959338.24 5959342.49 5959351.92 5959365.34 5959366.27 5959380.62 5959394.96 5959405.80 5959409.31 5959411.38 5959422.39 8868.01 5959432.02 Map Map Northing Easting ft ft 5959257.00 673898.20 5959586.00 673446.00 5959586.00 673446.00 5959235.00 673634.00 5959619.00 672410.00 5959619.00 672410.00 5959300.00 672687.00 5959411.00 671985.00 5959700.00 671063.00 5959717.00 671569.00 5959717.00 671569.00 5959243.00 671895.00 <- Latitude -> <-- Longitude -> Deg Min Sec Deg Min See 70 17 39.912 N 148 35 30.824 W 70 17 43.250 N 70 17 43.250 N 70 17 39.756 N 70 17 43.809 N 70 17 43.809 N 70 17 40.610 N 70 17 41.860 N 70 17 44.908 N 70 17 44.962 N 70 17 44.962 N 70 17 40.228 N DLS Build Turn deg/100ft deg/100ft deg/100ft 0.00 0.00 0.00 12.00 6.09 11.53 8.00 4.36 7.08 0.00 0.00 0.00 4.00 3.43 -2.07 4.00 0.40 -3.98 0.00 0.00 0.00 4.00 0.45 3.98 4.00 0.00 4.00 0.00 0.00 0.00 MapE ft 674323.64 674226.43 674209.43 674183.35 674138.73 674092.85 674045.93 673998.21 673949.91 673901.27 673867.85 673803.79 673712.63 673706.30 673608.82 673511.34 673437.72 673413.85 673399.80 673315.86 VS ft 1936.33 2035.95 2053.34 2079.94 2125.25 2171.59 8.00 2218.74 8.00 2266.47 8.00 2314.55 8.00 2362.75 8.00 2395.73 8.00 2458.86 0.00 2548.69 0.00 2554.93 0.00 2650.99 0.00 2747.05 0.00 2819.60 0.00 2843.11 0.00 2856.96 0.00 2939.79 4.00 TFO deg 0.00 60.00 61.68 0.00 -31.30 -84.30 0.00 83.70 90.00 0.00 DLS TFO deg/100ft deg 0.00 0.00 1.16 333.22 12.00 60.00 8.00 61.68 8.00 60.70 148 35 43.780 W 148 3543.780 W 148 35 38.538 W 148 36 13.948 W 148 36 13.948 W 148 36 6.089 W 148 36 26.471 W 148 36 53.147 W 148 36 38.390 W 148 36 38.390 W 148 36 29.206 W Target 15-23A T1.2 15-23A T2.2 15-23A T3.2 Tool/Comment TZ2 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS 59.19 MWD+IFR+MS 57.85 MWD+IFR+MS 56.67 MWD+IFR+MS 55.64 MWD+IFR+MS 54.77 MWD+IFR+MS 54.04 MWD+IFR+MS 180.00 MWD+IFR+MS 180.00 TZ1B 180.00 MWD+IFR+MS 180.00 MWD+IFR+MS 180.00 MWD+IFR+MS 180.00 TZ1A 180.00 MWD+IFR+MS 180.00 MWD+IFR+MS 328.70 MWD+IFR+MS 673216.75 3037.83 4.00 328.96 MWD+IFR+MS ) ) BP KW A Planning Report MAP Company: BP Amoco Date: 5/27/2003 Time: 16:50:50 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 15-23, True North Site: PB DS 15 Vertical (TVD) Reference: 60.90 60.9 Well: 15-23 Section (VS) Reference: Well (0.00N,0.00E,266.84Azi) Wellpath: Plan 15-23A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO TooVComment ft deg deg ft ft ft ft ft deg/100ft deg 10441.91 88.00 275.00 8930.90 8870.00 5959435.00 673175.00 3079.23 4.00 329.15 15-23A T1.2 10500.00 88.23 272.69 8932.81 8871.91 5959437.53 673117.00 3136.85 4.00 275.70 MWD+IFR+MS 10600.00 88.64 268.71 8935.54 8874.64 5959436.40 673017.08 3236.56 4.00 275.78 MWD+IFR+MS 10611.29 88.69 268.26 8935.80 8874.90 5959435.84 673005.80 3247.85 4.00 275.89 MWD+IFR+MS 10700.00 88.69 268.26 8937.84 8876.94 5959431.06 672917.25 3336.50 0.00 0.00 MWD+IFR+MS 10800.00 88.69 268.26 8940.13 8879.23 5959425.68 672817.43 3436.45 0.00 0.00 MWD+IFR+MS 10900.00 88.69 268.26 8942.43 8881.53 5959420.30 672717.61 3536.39 0.00 0.00 MWD+IFR+MS 11000.00 88.69 268.26 8944.72 8883.82 5959414.91 672617.78 3636.33 0.00 0.00 MWD+IFR+MS 11007.71 88.69 268.26 8944.90 8884.00 5959414.50 672610.09 3644.04 0.00 0.00 BSAD 11100.00 88.69 268.26 8947.02 8886.12 5959409.53 672517.96 3736.28 0.00 0.00 MWD+IFR+MS 11200.00 88.69 268.26 8949.31 8888.41 5959404.15 672418.14 3836.22 0.00 0.00 MWD+IFR+MS 11300.00 88.69 268.26 8951.61 8890.71 5959398.76 672318.32 3936.16 0.00 0.00 MWD+IFR+MS 11338.91 88.69 268.26 8952.50 8891.60 5959396.67 672279.48 3975.05 0.00 0.00 MWD+IFR+MS 11400.00 88.95 270.69 8953.76 8892.86 5959394.67 672218.44 4036.06 4.00 83.70 MWD+IFR+MS 11500.00 89.40 274.66 8955.20 8894.30 5959397.00 672118.51 4135.51 4.00 83.65 MWD+IFR+MS 11600.00 89.85 278.64 8955.85 8894.95 5959406.24 672018.96 4234.03 4.00 83.59 MWD+IFR+MS 11634.30 90.00 280.00 8955.90 8895.00 5959411.00 671985.00 4267.51 4.00 83.57 15-23A T2.2 11700.00 90.00 282.63 8955.90 8895.00 5959422.37 671920.30 4331.12 4.00 90.00 MWD+IFR+MS 11800.00 90.00 286.63 8955.90 8895.00 5959445.34 671823.00 4426.32 4.00 90.00 MWD+IFR+MS 11885.56 90.00 290.05 8955.90 8895.00 5959470.35 671741.20 4505.92 4.00 90.00 MWD+IFR+MS 11900.00 90.00 290.05 8955.90 8895.00 5959474.98 671727.52 4519.19 0.00 0.00 MWD+IFR+MS 12000.00 90.00 290.05 8955.90 8895.00 5959507.05 671632.81 4611.10 0.00 0.00 MWD+IFR+MS 12100.00 90.00 290.05 8955.90 8895.00 5959539.12 671538.10 4703.00 0.00 0.00 MWD+IFR+MS 12200.00 90.00 290.05 8955.90 8895.00 5959571.19 671443.39 4794.91 0.00 0.00 MWD+IFR+MS 12300.00 90.00 290.05 8955.90 8895.00 5959603.26 671348.68 4886.81 0.00 0.00 MWD+IFR+MS 12400.00 90.00 290.05 8955.90 8895.00 5959635.33 671253.96 4978.72 0.00 0.00 MWD+IFR+MS 12500.00 /90.00 290.05 8955.90 8895.00 5959667.40 671159.25 5070.63 0.00 0.00 MWD+IFR+MS 12601.63 90.00 290.05 8955.90 8895.00 5959700.00 671063.00 5164.03 0.00 0.00 15-23A T3.2 NOTVALlD¿.~~!?::.?:??:;~~:.S ..... ¥.ß:. " ..'~.. .~ ~':::::, ':'::' ;':::;i.:.;,: :::::~/:.:~;..s::; ¡.~.;:;,\:;;. .:: . .. "'f.1,,,M .... .....\ ...... ...... .....' ..... 1;\r?~}'~{~2:Ù:~;;¿;~,~::;;;::·i.T;2 *******$1 00.00******* AMOUNT CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 055080 No.P H NET VENDOR DISCOUNT CHECK NO. 055080 DATE 6/9/2003 II- 0 5 SOB 0 II- I: 0 a.. . 2 0 :i Btj S. ~ 0 ¡. 2 ? B Ii b liD DATE June 9, ..20Q3 ALí\$KA (QIL &GJ\S CONSE&\f.ÄTION CQMMISSION 333 W 7Tf;f AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 B.·n,:p, ·r;_eì·~"'. ff~,HI!I/'HU,. ,¡("1'.(.. ".) I'll! '.n. ~ .:J..¡('1J¡¡jiJ,uu" ..::::,':::,. .E. NATlONAL'CITY BANK Ashland. Ohio yS,25+1 GROSS TO THE ORDER OF: - . PAY: BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK99519-6612 TOTAL ~ THE ATIACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. PERMIT TO DRILL INV# CK060403 DESCRIPTION INVOICE I CREDIT MEMO ,.-. 6/9/2003 DATE p055080 Rev: 07/10/02 C\jody\templates ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMtTTAL LETTER CHECK WHAT APPLIES WELL NAME PTD# ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to· be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number, (50 70/80) from records, data and logs acquired for well (name on permit). paOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to fuD compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. PTD#: 2031110 Administration D D Appr Date RPC 6/19/2003 Engineering Appr Date WGA 6/19/2003 Geology Appr RPC Geologic Commissioner: r51&' Date 6/19/2003 Company __6E_EX_~L.QRA TlQtL(8LA~KAU~.c Well Name: PRUDHOE SAY UNIT 15-23A Program .I2E_V Well bore seg Field & Pool _eR.UIlliQf BAY I- PRUDHQ£QlL - 640150 Initial ClassfType DFV 1 1-01L GeoArea 890 Unit .11.6.5..~ On/Off Shore _QIL-- Annular Disposal 1 p~(rnit fe~ attache.d _ _ _ _ . . _ _ . _ _ . _ . _ _ . . _ . _ _ _ _ _ _ _ _ _ _ . . _ . _ _ _ . _ . _ _ _ _ _ Y ~s _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ . . _ _ _ . . . . . . . . . . . . . . . . . . . . . . . . _ . _ . . . . . 2 .Leas~.nUlJ1b~r _apP'ropri~t~_ _ _ _ . . . _ . _ . . . . . . _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . Y~s . _ _ _ _ _ _ _ _ _ _ . . _ . . . . _ _ _ _ _ . _ _ _ _ . . _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ . . . _ . _ . . . . . . _ . . . . . . . _ _ . 3 .U.nique well. n_am~ _and ou.mb.er . . . . . . _ . . . _ _ . . . _ _ _ _ _ _ _ . _ _ _ . _ _ _ . _ _ _ _ _ _ _ .Y~s . _ _ _ _ _ _ _ _ _ . . _ . . . . . . _ _ _ _ _ _ _ _ _ _ . . . . _ _ _ _ _ _ _ _ . _ _ _ _ . . . _ . _ . _ _ . _ . . _ . . _ _ . _ _ _ _ _ . . _ . _ 4 W~IIJocat~Q in_a.d_efil1e.d_ppoL . . . _ _ _ _ . . . . _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ . . _ _ _ . _ _ _ _ _ . . _ _ _ _ _ _ . _ . . . . 5 .W~IUocated pr.op~r _distance. from drijling unitb.ound.ary. _ . _ _ _ _ _ . . _ _ _ _ . _ _ . _ . _ . _ _ Yes _ . . _ _ _ _ _ _ _ _ . . _ . _ _ _ . . . _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ . _ . . . . . . _ _ . . . . _ _ _ . . . . _ . _ 6 .W~IIJocateQ pr_op~r _distance. from otb~r welJs. . . . . . . _ . . . . . _ . . _ _ . _ _ _ _ _ . . _ . . . _Y_es _ _ _ . _ _ _ _ . . _ _ . . _ _ . _ . . _ _ _ _ . . . _ . _ . . _ . _ _ _ _ _ . . . . _ . . _ _ . _ _ _ . _ _ _ . . _ _ _ _ _ _ . . . _ _ _ . 7 _SJ,lffiçiel1t.açrea9.e_aYail~ble in.d.ritli09 un_it _ _ . . _ _ _ . _ _ . . _ _ . _ . . _ . _ _ . _ _ _ . . . _ _ . Y~s _ . _ . _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ . . _ _ . . _ _ _ _ _ _ _ . . . . _ . . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . . . . _ . . _ _ . . _ _ . . _ . _ _ 8 Jf.d~viated. .is. weJlbore plat.il1c.lu_ded _ _ _ _ . _ . . . _ . . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ Y~s _ . _ _ . . . . _ _ _ _ _ _ _ . _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ _ . _ . _ . . . . . . _ _ . _ _ _ _ _ . . _ _ . _ . . _ . _ . . _ _ _ _ . . _ . _ 9 _Operator OI1Iy- aft.eçted party _ . _ _ _ _ _ _ _ _ . . . . _ . . . . . . . . . . . . . . _ _ _ . . . . . . . . Y~s _ _ _ _ . . . _ . . . . . . . . _ . . . _ . . . . . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ . 10 .Operator bas.apprppriate_ Qond i.nJQrce. . _ . . . . _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ Y~s . . . . . . . . _ _ _ _ _ _ _ . _ _ _ _ _ . . . _ . . . _ _ _ _ _ . _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . _ _ . _ _ _ _ _ _ . . _ _ _ _ _ 11 P~(mit c.ao be i_ssued wjtbout co_n$~rva.tiOI1 order _ . . . _ _ _ _ _ _ _ _ _ _ . _ _ _ . . . . _ . _ _ _ _ Y ~s . . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . . _ _ . _ _ _ _ _ . . _ . _ . _ _ . _ . _ _ . _ . . . . _ . . _ . _ _ _ _ . . . _ _ . . . _ _ _ _ _ . 12 P~lJ11it c_ao be issu.ed wjtbout ad.milJist(ati\le.apprpvaJ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ . . . . _ _ _ _ _ Y~s . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ . _ _ _ _ _ _ . . . . . . . . . . . . _ _ _ _ _ . . . . . . . . . . . . . . . _ . . . . . . _ . _ 13 Can permit be approved before 15-day wait Yes 14 _We.IUocatedwithinarea an.d_strata.authorizedby_lojectiplJOr d~(#(putIO#in_cpr:nm_eot$).(For_ _NA _ _ _ _ _ _ _ _.... _. _ _ _..... _ _ _ _.... _ _. _ _ _ _ _ _ _ _. _... _ _ _ _ _ _ _. _. _...... _. _ _ _ _.. _ _ __ 15 _AJI welJs.witÞtn.1l4_l1Jite_are.a.of (eyiew jd~otified (Fpr. ~erv.ic_e.w.eU Only). _ _ _ _ _ . . _ . _ . . . . _NA . _ _ _ _ . . _ . _ _ _ _ _ _ _ _ . _ _ _ . . . . . _ . _ . _ . . _ _ _ _ . _ . . _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ 16 Pre.-produçed.injector; .dur~tiQn_ofpre-pro.ductiOIJ l~s$.tÞan.3IJ1ol1tbs.(For.ser:.vicewellon)y). _ _NA _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . . . . . . . _ _ _ _ _ . . _ _ _ _ 17 .ACMP. F:il1djng .of Con.si~teocy_ h_as bee_n J$.sued_ for_ tbis pr_olect _ _ _ _ _ _ _ . _ _ . . . _ _ _ _ _ _ NA. . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . _ . . . _ . _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ 18 _C_ooduçtor str.il1.g_PJovided _ _ _ _ . _ _ _ _ _ . _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ . _ . _ _ . . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . 19 _S_udac~ .ca$.ing_ pJotec_t$. alLknown. USDWs _ _ . . . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ . NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ .. . . . _ _ _ _ _ _ _ _ _ _ _ _ . _ . . _ _ _ . _ _ _ _ _ . 20 _CMT.v_oladequ.ate.to circ_ulate.on.cOlJd_uctor.& su.rf.csg . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _. . _ _ _ _ . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _. _ . _ _ _ _ 21 .CMT. v_ol adequate.to tie-in Jong .string to.s!JrJ Ç4g_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ 22 _CMT.wil! coyer_a)! klJo.w.n_pro_ductiYe bori~on.s_ _ _ _ . _ _ _ . _ . _ _ _ _ _ . _ . _ _ _ . _ _ _ _ _ . _ Y~s _ _ _ . _ _ _ _ _ _ _ _ . _ . _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ . . _ _ _ 23 _C_asiog de.signs adecuat~ fp( C,T. B _&_ perruafr_ost. _ _ _ _ _ . _ _ _ . . _ . _ . _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ . _ _ . _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . . _ _ __ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ 24 _A.dequ~te.tan.kage_oJ re.seI'Ye pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ . . _ _ Yes _ _ _ _ _ _ _ ~ab.ors_2_ES, _ _ _ _ _ _ _ . _ . _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 25 Jf.a.re-.dr.ilt l1as_a_ 1.0:-4.03 for ~bandon.me.nt be~o apPJoved _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ . _ _ _ _ _ . _ _ _ _ . . _ _ . . . . . . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ . _ _ 26 A.dequatewellbore. ~epªratjo_n_propo~e.d _ _ . . _ . _ _ . _ _ . . . . . _ _ . _ . . . _ _ _ _ _ . . _ _ . _Y~s _ . _ _ . _ _ . . _ . . . _ _ _ _ _ _ _ _ . . _ _ _ . _ . _ _ _ _ _ _ _ . _ _ . . _ _ _ _ _ _ _ . . . _ . _ . _ _ _ _ . _ . _ _ . . . _ _ . _ _ . _ _ 27 Jf..djver:t~r J~q_uiJ~d. does jt me~t reguJatiolJs_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ NA _ _ . _ . _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ __ _ _ _ . _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ . . _ _ _ . . _ _ 28 .DJillio9 fJujd_prQQraru sc.hematic_&eq_uipJist.adequate. . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s. _ . _ . _ _ MaxMW_8,Ip'pg~ . . _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ . . _ . _ _ _ _ _ . . . . . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ 29 _BOP.!=s,_ dp .they meet reguJatiOIJ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . . _ . _ . . _ _ _ _ _ Y ~s . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . . . __ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . . . . _ _ _ _ _ _ _ . _ . _ _ _ _ . . . _ _ _ 30 _SOP.!=_pre.ss ra!iog appropriate;.t~st to_(pu.t psig tn_comments). _ _ _ _ _ _ _ _ _ _ . _ . _ . _ . _ . Yes _ _ _ _ _ _ _ Te.st lo_3500_psi. _MS~ 2.3_96 P$i.. _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . . _ . _ _ _ _ _ . _ . . . _ _ _ _ _ _ _ 31 _C_hoke_l1J~njfold CQrnpJies_ w/AP'-R~-53 (May 84)_ _ _ _ _ _ _ _ _ _ _ _ . . . . . _ . _ . . _ _ . _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . . _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ . . _ _ . _ . _ _ _ _ _ . _ _ _ _ . _ _ _ _ . . . 32 .Work will pçc.U( withput.operatjon _sl1utdown_ _ _ _ . _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ . . . _ _ . _ _ _ .Y~$ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . . . . _ _ . _ _ _ _ _ . . _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ . _ _ _ _ _ _ _ _ . .. _ _ . ._ _ _ _ _ _ _ _ _ _ . 33 J$. pre$.ence_ of H2S gas_ prOQable _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ No_ _ _ _ _ _ _ _ _ _ . . . _ _ . _ _ . . . _ _ . . _ _ _ _ _ . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . . . _ _ _ _ _ _ _ _ _ . _ . . 34 Meçba_nlcaLcpodJtion p{ we.lI$ within AOR yerified. (fpr_s_ervjce w~1J on.ly) _ _ _ _ _ _ _ _ _ _ _ . . . .NA . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . . _ . _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . _ _ 35 Pe(rnil c.an be issu.ed w/o_ hydr.ogen_ s_ulfide meas_uœs _ . _ _ . _ _ . . _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . _ _ _ _ _ . . _ _ _ _ . 36 .D_ata_PJe.seoted. on. p.ote_nti~1 PveJp-re$.sur~ _zone.s. _ _ _ _ . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ . . . _ . . . . . . _ . _ _ . . _ _ _ _ _ _ _ _ . . _ . . _ _ _ _ _ _ _ _ . _ . . _ _ . _ . _ _ _ _ _ _ _ . . _ _ _ _ _ . _ _ . _ _ _ . _ . . 37 _S.eisr:nic_analys.is_ of .shallow gas_zpoe.s_ _ _ _ . . _ _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ NA. . _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . . . _ _ _ _ _ _ . . _ _ _ _ _ _ _ . . . _ _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ 38 _S~abe.d .col1djtipo survey.(if Off-$hp(e) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ . _ _ _ _ . . _ _ . . _ NA_ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ . _ . . _ _ _ _ _ _ _ _ . _ _ . . _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ 39 _ Contact nam.elphon.eJor_weekly pr9gre~s_report$ [exploratpry _only]. _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ . _ _ _ _ . _ _ . _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ . _ ( ( Date: Engineering Commissioner: Date Public Commissioner ~ate ~9/ð3 G~\~/Q3 ') ) Well ¡-¡¡story 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. '. ) ) 903- I} ) ) /93 ~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Sep 02 13:25:03 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/09/02 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. . . . . . . . . . . . . . . . . . . . .03/09/02 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 15-23A 500292222501 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 02-SEP-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW2548429 T. GALVIN J. RALL / D. MWD RUN 2 AK-MW2548429 J. BOBBITT J. RALL / D. MWD RUN 3 AK-MW2548429 J. BOBBITT J. RALL / D. # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 22 llN 14E 1382 274 60.90 32.40 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 4074.0 6.125 7.000 8985.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY F<ECEIVED S'1'") 16 ,..007. c. t t... 'v ~~~~'\~ Aiaska ü;i & Ga~~ Cens. Cmnmi3eton /\nchor~~ , . ) ') (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). THERE IS A 3' DIFFERENCE BETWEEN LOGGER'S TD AND DRILLER'S TD FOR RUN 1 DUE THE FACT THAT 3 ADDITIONAL FEET WERE DRILLED AFTER THE SPERRY CREW WERE TOL THAT TD HAD BEEN REACHED. 4. MWD RUN 2 COMPRISED DIRECTIONAL WITH GAMMA MODULE (GM) UTILIZING GEIGER- MUELLER TUBE DETECTORS; COMPENSATED THERMAL NEUTRON POROSITY (CTN); AND STABILIZED LITHO-DENSITY (SLD). 5. MWD RUN 3 COMPRISED DIRECTIONAL WITH GM. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 8/26/03. MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1 - 3 REPRESENT WELL 15-23A WITH API#: 50-029-22225-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12268'MD/8966'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.125" MUD WEIGHT: 8.5 PPG MUD SALINITY: 1000 PPM CHLORIDES FORMATION WATER SALINITY: 10994 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.. .... .03/09/02 Maximum Physical Record. .65535 File Type................ LO Previous File Name.... ...STSLIB.OOO Corrunent 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 FET RPD RPM RPS RPX ROP NCNT FCNT NPHI PEF DRHO RHOB $ ) .5000 START DEPTH 4070.5 4074.0 4074.0 4074.0 4074.0 4074.0 4101.0 8902.0 8903.0 8903.0 8915.5 8988.5 8988.5 ) STOP DEPTH 12218.5 8942.0 8942.0 8942.0 8942.0 8942.0 12268.5 10055.0 10055.0 10055.0 10068.5 10068.5 10068.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 MERGED MAIN PASS. $ MERGE TOP 4070.5 8985.0 10137.0 MERGE BASE 8985.0 10137.0 12268.5 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O 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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 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 CNT/ 4 1 68 36 10 NCNT MWD CNT/ 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4070.5 12268.5 8169.5 16397 4070.5 12268.5 ROP MWD FT/H 0.1 542.08 147.646 16336 4101 12268.5 GR MWD API 5.45 598.2 84.1211 16297 4070.5 12218.5 RPX MWD OHMM 0.51 27.02 2.78916 9737 4074 8942 RPS MWD OHMM 0.49 23.74 2.7613 9737 4074 8942 RPM MWD OHMM 0.46 22.45 2.73795 9737 4074 8942 RPD MWD OHMM 0.44 23.9 2.7844 9737 4074 8942 FET MWD HOUR 0.13 5.79 0.56635 9737 4074 8942 NPHI MWD PU-S 6.06 78.56 21.5508 2305 8903 10055 ") ) FCNT MWD NCNT MWD RHOB MWD DRHO MWD PEF MWD CNT/ CNT/ G/CM G/CM BARN 95.7 13793.1 1. 97 -0.148 0.67 2611.9 47025.9 4.062 1. 639 14.85 908.796 31463.4 2.28229 0.0339958 2.45017 2305 2307 2161 2161 2307 8903 8902 8988.5 8988.5 8915.5 10055 10055 10068.5 10068.5 10068.5 First Reading For Entire File.... .... ..4070.5 Last Reading For Entire File.......... .12268.5 File Trailer Service name.... ........ .STSLIB.OOl Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..03/09/02 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..... ..03/09/02 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 4070.5 4074.0 4074.0 4074.0 4074.0 4074.0 4101.0 STOP DEPTH 8949.5 8942.0 8942.0 8942.0 8942.0 8942.0 8982.0 # 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: 18-JUL-03 Insite 66.37 Memory 8985.0 4074.0 8982.0 .5 36.7 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 164580 134760 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 4074.0 # ) ) 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: LSND 9.20 39.0 9.0 1000 7.4 1. 930 1. 040 2.000 1. 970 70.0 136.0 70.0 70.0 # 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.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing.............. ..... ..60 .1IN Max frames per record.... ...... ...Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order 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 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4070.5 8982 6526.25 9824 4070.5 8982 ROP MWD010 FT/H 1.19 542.08 166.357 9763 4101 8982 GR MWD010 API 5.45 405.47 104.935 9759 4070.5 8949.5 RPX MWD010 OHMM 0.51 27.02 2.78916 9737 4074 8942 RPS MWD010 OHMM 0.49 23.74 2.7613 9737 4074 8942 RPM MWD010 OHMM 0.46 22.45 2.73795 9737 4074 8942 RPD MWD010 OHMM 0.44 23.9 2.7844 9737 4074 8942 FET MWD010 HOUR 0.13 5.79 0.56635 9737 4074 8942 First Reading For Entire File........ ..4070.5 Last Reading For Entire File.......... .8982 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/09/02 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...... .03/09/02 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI PEF GR ROP DRHO RHOB $ 3 ) header data for each bit run in separate files. 2 .5000 START DEPTH 8902.0 8903.0 8903.0 8915.5 8950.0 8982.5 8988.5 8988.5 STOP DEPTH 10055.0 10055.0 10055.0 10068.5 10092.5 10137.0 10068.5 10068.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE SLD CTN GM $ BOTTOM) TOOL TYPE STABILIZED LITHO DEN COMP THERMAL NEUTRON Dual GR # 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): # 22-JUL-03 Insite 66.37 Memory 10137.0 8982.0 10137.0 29.2 87.3 TOOL NUMBER 150253 113413 69706 6.125 8985.0 QuikDril-N 8.50 39.0 9.4 1000 6.6 .000 .000 .000 .000 .0 124.0 .0 .0 , . ) ) 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 .1IN 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 NPHI MWD020 PU-S 4 1 68 12 4 FCNT MWD020 CNTS 4 1 68 16 5 NCNT MWD020 CNTS 4 1 68 20 6 RHOB MWD020 G/CM 4 1 68 24 7 DRHO MWD020 G/CM 4 1 68 28 8 PEF MWD020 BARN 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8902 10137 9519.5 2471 8902 10137 ROP MWD020 FT/H 1.8 189.4 58.7756 2310 8982.5 10137 GR MWD020 API 10.44 598.2 50.8346 2286 8950 10092.5 NPHI MWD020 PU-S 6.06 78.56 21. 5508 2305 8903 10055 FCNT MWD020 CNTS 95.7 2611.9 908.796 2305 8903 10055 NCNT MWD020 CNTS 13793.1 47025.9 31463.4 2307 8902 10055 RHOB MWD020 G/CM 1. 97 4.062 2.28229 2161 8988.5 10068.5 DRHO MWD020 G/CM -0.148 1. 639 0.0339958 2161 8988.5 10068.5 PEF MWD020 BARN 0.67 14.85 2.45017 2307 8915.5 10068.5 First Reading For Entire File......... .8902 Last Reading For Entire File.......... .10137 File Trailer Service name.... ........ .STSLIB.003 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation...... .03/09/02 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header S~rvice name............ .STSLIB.004 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation.... ...03/09/02 Maximum Physical Record. .65535 File Type............... .LO Previous File Name... ... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY 4 header data for each bit run in separate files. 3 .5000 · " ) VENDOR TOOL CODE GR ROP $ START DEPTH 10093.0 10137.5 STOP DEPTH 12218.5 12268.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # 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.....O Logging Direction................ . Down Optical log depth units..... .... ..Feet Data Reference Point............. .Undefined Frame Spacing..... .... .... ...... ..60 .1IN Max frames per record..... ...... ..Undefined Absent value............. ....... ..-999 Depth Units....................... Datum Specification Block sub-type. ..0 Name Service Order DEPT ROP MWD030 GR MWD030 24-JUL-03 Insite 4.3 Memory 12268.0 10137.0 12268.0 84.6 90.9 TOOL NUMBER 69706 6.125 8985.0 QuikDril-N 8.50 39.0 9.4 800 6.5 .000 .000 .000 .000 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 ) .0 141.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10093 12268.5 11180.8 4352 10093 12268.5 ROP MWD030 FT/H 0.1 394.15 152.952 4263 10137.5 12268.5 GR MWD030 API 31 125.89 54.246 4252 10093 12218.5 ) ) First Reading For Entire File...... ....10093 Last Reading For Entire File.. ........ .12268.5 File Trailer Service name. .......... ..STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/09/02 Maximum Physical Record. .65535 File Type.. ............. .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/09/02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name... ............ . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/09/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name......... ...... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File