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Home My WebLink About203-115Originated: Delivered to:18-Jun-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1B-20 50-029-23164-00 910026681 Kuparuk River Packer Setting Record Field- Final 7-May-25 0 12 1D-117 50-029-22844-00 910027101 Kuparuk River Plug Setting Record Field- Final 8-May-25 0 13 1D-133 50-029-22827-00 910010225 Kuparuk River Multi Finger Caliper Field & Processed 25-May-25 0 14 1G-02 50-029-20813-00 910036496 Kuparuk River Multi Finger Caliper Field & Processed 21-May-25 0 15 1H-08 50-029-20763-00 910080713 Kuparuk River Multi Finger Caliper Field & Processed 22-May-25 0 16 1H-08 50-029-20763-00 910080713 Kuparuk River Plug Setting Record Field- Final 22-May-25 0 17 1Q-04 50-029-21250-00 910027200 Kuparuk River Tubing Cut Record Field- Final 14-May-25 0 18 1Q-04 50-029-21250-00 910027200 Kuparuk River Tubing Cut Record Field- Final 15-May-25 0 19 1Q-22 50-029-22595-00 910027102 Kuparuk River Plug Setting Record Field- Final 16-May-25 0 110 2B-02A 50-029-21154-01 910106459 Kuparuk River Leak Detect Log Field- Final 14-Jun-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:203-115197-237197-206182-138182-093184-234195-140216-087T40582T40583T40584T40585T40586T40586T40587T40587T40588T405896/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.20 08:37:34 -08'00'203-1151B-2050-029-23164-00 910026681Kuparuk RiverPackerSetting RecordField- Final7-May-2501 Originated: Delivered to:17-Jan-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1A-26 50-029-22115-00 909678321 Kuparuk River Packer Setting Record Field- Final 14-Nov-24 0 12 1A-26 50-029-22115-00 909619342 Kuparuk River Packer Setting Record Field- Final 21-Oct-24 0 13 1A-27 50-029-22124-00 909781603 Kuparuk River Multi Finger Caliper Field & Processed 25-Dec-24 0 14 1B-19 50-029-22475-00 909619036 Kuparuk River Packer Setting Record Field- Final 17-Oct-24 0 15 1B-20 50-029-23164-00 909619415 Kuparuk River Plug Setting Record Field- Final 8-Oct-24 0 16 1B-20 50-029-23164-00 909678322 Kuparuk River Plug Setting Record Field- Final 13-Nov-24 0 17 1C-04A 50-029-20547-01 909677469 Kuparuk River Packer Setting Record Field- Final 23-Nov-24 0 18 1C-158 50-029-23761-00 909810535 Kuparuk River Injection Profile Field & Processed 11-Jan-25 0 19 1D-05 50-029-20417-00 909607635 Kuparuk River Correlation Record Field- Final 9-Oct-24 0 110 1D-14 50-029-22950-00 909677466 Kuparuk River Packer Setting Record Field- Final 26-Nov-24 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T39991T39991T39992T39993T39994T39994T39995T39996T39997T39998190-166190-180194-064203-115217-078223-056179-095199-0891/23/202551B-2050-029-23164-00909619415Kuparuk RiverPlug Setting RecordField- Final8-Oct-240161B-2050-029-23164-00909678322Kuparuk RiverPlug Setting RecordField- Final13-Nov-2401194 064203-115217 078Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.01.23 15:06:40 -09'00' Originated: Delivered to:9ͲOctͲ24Halliburton Alaska Oil and Gas Conservation Comm.Wireline & PerforatingAttn.:Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska99501Anchorage, Alaska 99518Office: 907Ͳ275Ͳ2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#11AͲ08 50Ͳ029Ͳ20313Ͳ00 909572342 Kuparuk River Leak Detect Log with ACXField & Processed 13ͲSepͲ24 0 121BͲ20 50Ͳ029Ͳ23164Ͳ00 909462416 Kuparuk River Multi Finger CaliperField & Processed 15ͲAugͲ24 0 131CͲ24 50Ͳ029Ͳ23063Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 25ͲAugͲ24 0 141CͲ24 50Ͳ029Ͳ23063Ͳ00 n/a Kuparuk River Multi Finger CaliperField & Processed 25ͲAugͲ24 0 151CͲ24 50Ͳ029Ͳ23063Ͳ00 ALSL764Ͳ002 Kuparuk River Packer Setting Record FieldͲFinal 15ͲSepͲ24 0 161DͲ32 50Ͳ029Ͳ22982Ͳ00 909582494 Kuparuk River Multi Finger CaliperField & Processed 6ͲSepͲ24 0 171EͲ29 50Ͳ029Ͳ20828Ͳ00 909524908 Kuparuk River Leak Detect Log FieldͲFinal 8ͲSepͲ24 0 181EͲ29 50Ͳ029Ͳ20828Ͳ00 909524908 Kuparuk River Packer Setting Record FieldͲFinal 7ͲSepͲ24 0 191HͲ01 50Ͳ029Ͳ22330Ͳ00 909524903 Kuparuk River Multi Finger CaliperField & Processed 29ͲAugͲ24 0 110 1HͲ01 50Ͳ029Ͳ22330Ͳ00 909593144 Kuparuk River Plug Setting Record FieldͲFinal 23ͲSepͲ24 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T39678T39679T39680T39680T39680T39681T39682T39682T39683T39683178-040203-115201-248200-173182-154193-00610/21/2024Gavin GluyasDigitally signed by Gavin Gluyas Date: 2024.10.21 10:33:37 -08'00'1BͲ2050Ͳ029Ͳ23164Ͳ00 909462416KuparukRiverMultiFingerCaliperField&Processed15ͲAugͲ2401T39679178 040203-115201 248 ') ) 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 res can activity or are viewable by direct inspection of the file. ~ Q3 - ~ L5 Well History File Identifier Organizing (done) ¡TWO-Sided I1II1I11II1I1111111 o Rescan Needed 1111111111111111111 RJSCAN .\15 Color Items: o Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Diskettes, No. D Other, No/Type: o Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: o Logs of various kinds: NOTES: BY: ( Maria") D Other:: Date: , d- j:J- 05' /5/ rr1~ 1111111111111111111 n1P Project Proofing BY: ~é Maria ) Date: Id- ia- 05 /5/ Scanning Preparation BY: ( Maria""") Lf X 30 =; ¡;to Date: jà I~ 05 + ICó = TOTAL PAGES t.3 Z3' (Count does not include cover sheet) IAA ..p /5/ r J t 11111111111111111 Production Scanning Stage 1 Page Count from Scanned File: 131 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: \_ Maria ) Date: j.;}.. · IJ-! os- Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO mP /5/ NO BY: Maria Date: /5/ 1IIII1I1I1111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • ConocoP hiff~ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 17, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • RECE~V~~ AUG 2 ~ 2008 Alaska Oil & Gas Cons.. ~'O~r~;,,;S~On AnchoT~Oe a0~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped August 2-17, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Kle _ ~ ~ Z ~~~ ~ ConocoPhillips Well Integrity Projects Supervisor i~Cs' ~'`~~~1~~ AtIG ~ 20(l~ • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) f---7 Date Kuparuk Field if/7 //LUUtf Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date 2H-05 185-168 ft SF bbls ft al 2H-17 200-019 6" N/A SF N/A 5.10 8/2/2007 2K-27 201-169 10" N/A 6" N/A 1.27 8/2/2007 2M-03 191-141 16" N/A 10" N/A 8.92 8/2/2007 1 B-14 194-030 SF N/A 16" N/A 2.13 8/2/2007 1 B-18 194-061 9" N/A SF " N/A 1.70 8/13/2008 1 B-19 194-064 SF N/A 9 N/A 8.07 8!13/2008 1 B-20 203-115 21" N/A SF N/A 5.10 8/13/2008 1 B-101 203-133 3" N/A 21" " N/A 5.95 8/13/2008 1 B-102 203-122 4" N/A 3 " N/A 1.00 8/17/2008 1Y-05 183-087 6" N/A 4 N/A 1.00 8/17/2008 1Y-07 183-068 6" N/A 6" N!A 1.27 8/13/2008 1Y-17 193-068 SF N/A 6" N/A 1.27 8/13/2008 1Y-22 193-070 SF N/A SF N/A 1.27 8/13/2008 1Y-26a 188-116 SF N/A SF N/A 2.12 8/13/2008 1Y-30 188-090 SF N/A SF N/A 3.83 8/13/2008 1 E-112 204-091 14" N/A SF N/A 3.83 8/13/2008 1 E-119 204-031 14" N/A 14" N/A 5.95 8/17/2008 1 E-121 204-246 6" N/A 14" " N/A 4.67 8/17/2008 1 E-123 204-074 5" N/A 6 " N/A 1.00 8/17/2008 N/A 5 N/A 1.00 8/17/2008 • • °,~;~ _- ~ '• ~ 03/01 !2008 DO NOT PLACE `° ~' e;-• ~~,,:. ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm_Marker.doc 'l ì ,Lî c:^-- I ,~ v,~ DATA SUBMITTAL COMPLIANCE REPORT 8/1/2005 Permit to Drill 2031150 Well Name/No. KUPARUK RIV UNIT 18-20 Operator CONOCOPHILLlPS ALASKA INC 5~J..., l t j ""1 ~ t'\ ~ API No. 50-029-23164-00-00 MD 8636 /' TVD 6592 / Completion Date 7/27/2003"/ Completion Status 1-01L Current Status 1-01L UIC N - -- ------- REQUIRED INFORMATION Mud Log No Samples No Directional su~ ~------ -- -- -.--------- ---------- DATA INFORMATION Types Electric or Other Logs Run: GRlRes Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No Interval OH / Start Stop CH -- Received Comments - ------ -- ~ Directional Survey 0 8636 Open 8/13/2003 ED C Tf 12060 ~I£ Vr::,lflcatlorr'" ¡ "",è. ~ . 138 8636 Open 8/26/2003 ;:/C LIS Verification 138 8636 Open 8/26/2003 Pdt 12060 Neutron 25 138 8636 Open 8/26/2003 Caliper Corrected Neutron, t~ Optimized Density - MD C Pdt 12060 Neutron 25 138 8636 Open 8/26/2003 Caliper Corrected Neutron, It/ Optimized Density TVD Neutron 25 Blu 138 8636 Open 8/26/2003 Caliper Corrected Neutron, ~ Optimized Density - MD Neutron 25 Blu 138 8636 Open 8/26/2003 Caliper Corrected Neutron, ¡~ Optimized Density - TVD C Pdt 12060 Induction/Resistivity 25 138 8636 Open 8/26/2003 Multiple Propagation ~ Resistivity, Gamma Ray - IjD MD C Pdt 12060 I nd uction/Resistivity 25 138 8636 Open 8/26/2003 Multiple Propagation Resistivity, Gamma Ray - I TVD ~ Induction/Resistivity 25 Blu 138 8636 Open 8/26/2003 Multiple Propagation Resistivity, Gamma Ray- : MD ~g I nd uction/Resistivity 25 Blu 138 8636 Open 8/26/2003 Multiple Propagation Resistivity, Gamma Ray- ~ TVD Perforation 5 Blu 7629 8533 Case 11/7/2003 2" HSD Gun Perforating Record Static Survey DATA SUBMITTAL COMPLIANCE REPORT 8/1/2005 Permit to Drill 2031150 Well Name/No. KUPARUK RIV UNIT 18-20 Operator CONOCOPHILLlPS ALASKA INC MD 8636 TVD 6592 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? ~ Chips Received? -Y / N - Analysis Received? ~ --_._.~-------- ----- -- ----~ Comments: ._---~ Compliance Reviewed By: Completion Date 7/27/2003 Completion Status 1-01L ~ Interval Start Stop Sent Received Daily History Received? Formation Tops Current Status 1-01L Sample Set Number Comments ~N ð/N Date: API No. 50-029-23164-00-00 UIC N -~ c.t No ú ^,Ò 'fJ)- ~- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAGD GINJ D WINJ D WDSPL D Sa. Sundry number: 5b. Sundry approval date: D or Final 0 303-204 / 303-257 7/30/2003 (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number ot fluids and drill rig approved substances (include days domestic waste water descriptions in block 12) disposal occurred P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added ~, Previous totals (bbls): 2003 / 3rd 36655 100 2003 / 4th 0 0 2004 / 1st 0 0 2004 / 2nd 0 0 ---~ Total Ending Volume 36655 100 (bbls): 6. Permit to Drill Number: 7. Well Name: 8. API Number: 203-115 18-20 50-029-23164-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: 0 36755 39 7/31/2003 9/1/2003 1 B-1 02, 1 B-1 01 0 0 0 0 0 0 0 0 0 o 36755 39 11. Attach: Disposal Performance Data: Pressure vs. Time D Other (Explain) D 12. Remarks and Approved Substances Description(s ): Step Rate Test D I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~~ Printed Name: Randy Thomas Title: Date: Kuparuk Drilling Team Leader Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. \C(Cer fó'1 Phone Number: (907) 265-6830 Submit in Duplicate ) ') Mike Mooney Wells Group Team Leader Drilling & Wells ConocJPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 July 14, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 18-20 (APD # 203-115) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 1 8-20. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, I4J J(~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad A~,iG ('I , ", r) /U04: I . ORIGINAL 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 28' / 89' AMSL 8. Property Designation: ADL 25647 & 25648 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION LINER Perforation depth: ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RepairWell D Pull Tubing D Operat. ShutdownD Stimulate 0 Waiver D Other D D D Plug Per1orations D Per10rate New Pool D Per10rate D 4. Current Well Status: Development _ 0 Stratigraphic D Time Extension Re-enter Suspended Well 5. Permit to Drill Number: 203-115/ 6. API Number: 50-029-23164-00 Exploratory Service D D 9. Well Name and Number: 1 B-20 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool measured 8636' feet true vertical 6592' feet measured 8448' feet true vertical 6276' feet Length Size MD 138' 16" 138' 5194' 9-5/8" 5222' 7978' 7" 8005' 795' 5-1/2" 8636' Plugs (measured) Junk (measured) 8536' TVD Burst Collapse 138' 4009' 6023' 6592' Measured depth: 8143'-8193',8356'-8386',8332'-8352' true vertical depth: 6147'-6192',6339'-6367',6317'-6336' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8261' MD. Packers & SSSV (type & measured depth) Baker perm. Pkr, Baker SABL-3 pkr 7765',8242' SSSV= 1820' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 8332'-8386' 128,000# of 16/20, 7.8 ppa @ perfs Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation 430 1322 20 127 Subsequent to operation 889 1240 141 130 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ D WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Mike Mooney @ 263-4574 Mike fy100ney I/rJ J1~ Form 10-404 Revised 04/2004 Printed Name Signature Title Wells Group Team Leader Phono R Date «;J'Â /Of I I GIN A L Pæpa'ed bv ;/.ron ',(,':"<>-D"'. 263-4612 RiBD!M1S ¡aiF:l AUG 0 4 200~ Submit Original Only ) 1 B-20 Well Events Summary ') Date Summary 06/20104 PUMP BREAKDOWN, SCOUR STAGE, DATAFRAC FOLLOWED WITH FRAC TREATMENT CONSISTING OF PUMPING 550 BBLS PAD @ 20 BPM TP=4854. 127681# 16/20 IN PERFS, 7.8 PPA, 146458# PUMPED. 06/22/04 CLEANED OUT WELL TO 8455' CTM UTILIZING SW AND BIOZAN SWEEPS. CLEANED-UP GLM'S WHILE POOH. FREEZE PROTECTED WI DIESEL.O [FCO] STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAGD GINJ D WINJ D WDSPL D Sa. Sundry number: 5b. Sundry approval date: 6. Permit to Drill Number: 7. Well Name: 8. API Number: 203-115 1 B-20 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: 50-029-23164-00 9. Field: o or Final D (h)(2) drill rig wash fluids and drill rig domestic waste water 303-204 I 303-257 (h)(3) Other Commission approved substances (include descriptions in block 12) 7/30/2003 Volume (bbls): Number of days disposal occurred Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~ Previous totals (bbls): 2003 14th o 100 0 36755 39 7/31/2003 9/1/2003 1 B-1 02, 1 B-1 01 0 0 0 0 0 0 0 0 0 0 0 0 --- 100 0 36755 39 Report ;s due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, Pressure vs. Time D Step Rate Test D October 20 for the third quarter, and January 20 for the fourth quarter. 2003 1 3rd 36655 2004/1st o 2004 1 2nd o Total Ending Volume (bbls): 36655 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ \ ~ Printed Name: Randy Thomas Title: Date: ?f'B/o y Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 36655 100 0 36755 39 7/31/2003 9/1/2003 18-102,18-101 0 0 0 0 0 0 0 0 0 0 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAGD GINJ D WINJ D WDSPL D Sa. Sundry number: 5b. Sundry approval date: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added o or Final D (h)(2) drill rig wash fluids and drill rig domestic waste water 303-204 I 303-257 (h)(3) Other Commission approved substances (include descriptions in block 12) 7/30/2003 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 2003 1 3rd 2003 14th 2004 /1 st 2004 1 2nd Total Ending Volume (bbls): 36655 100 o 36755 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Pressure vs. Time D Step Rate Test D I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~~~. \ ~ 1"'<-~~ ') ~Q -..c< J Date: \) r- ~ t-ê~__ G-"",---' Signature: --- Printed Name: Title: Form 10-423 Rev. 9/2003 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 203-115 1 8-20 50-029-23164-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~ .~. 39 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. '-1/16/0'1 Phone Number: 2~ ç- ,-6 >0 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation of Disposal 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 / 3rd 36655 100 2003 / 4th 2004/1st 2004 1 2nd Total Ending Volume (bbls): 36655 100 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Pressure vs. Time D 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas D WAGD GINJ D WINJ D WDSPL D Sa. Sundry number: 5b. Sundry approval date: 303-204 I 303-257 (h)(3) Other Commission approved substances (include descriptions in block 12) 7/30/2003 Volume (bbls): Number ot days disposal occurred o 36755 39 o 36755 39 Step Rate Test D Signature: I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: Printed Name: \ \ ~~ ~--l) ,,",-c:. (""0"\. c.. ~ Title: ~~(.t((0 \e--. Le--( Form 10-423 Rev. 9/2003 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 203-115 1 8-20 50-029-23164-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: / -" 7/31/2003 9/1/2003 18-102, 18-101 "---- Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. , (2.{.. (ð V Phone Number: ~ Gi ~Ö Submit in Duplicate ) ConocóP'hillips Randy Thomas Kuparuk Drilling Team Leader ..! Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 December 3, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 18-20 (APD # 203-115) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 18-20. If you have any questions regarding this matter, please contact me at 265-6830 or Shane Cloninger at 265-6829. Sincerely, ,-- ~~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad RECEIVED DEC - 5 2003 Alaska Oil & Gas Cons. Commission Anchorage ORIGiNAL ) STATE OF ALASKA '\ ALAS,'r\ OIL AND GAS CONSERVATION COMM. .lION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U WINJ D WDSPL D GINJ D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Plugged D Abandohed D 20AAC 25.105 No. of Completions _ P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 497' FNL, 820' FEL, Sec. 9, T11N, R10E, UM At Top Productive Horizon: 2563' FNL, 192' FWL, Sec. 9, T11 N, R10E, UM Total Depth: 2683' FNL, 15' FWL, Sec. 9, T11N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 549619 y- TPI: x- 545370 y- Total Depth: x- 545194 . y- 18. Directional Survey: Yes 0 NoU 21. Logs Run: GR/Res 22. CASING SIZE WT. PER FT. 62.5# 40# 26# 15.5# GRADE B L-80 L-80 L-80 16" 9.625" 7" 5.5" CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 138' Surface 5222' Surface 8006' 7841' 8636' Zone-4 Zone-4 Zone- 4 5969647 5967555 5967433 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 8143' - 81931 MD 8356' - 8386' MD 83321 - 8352' MD 6147' - 6192' TVD 6339' - 6367' TVD 6317' - 6336' TVD 4.5spf 6spf 5spf - - .1. ·7·.z 7t~-3: A.. Form 10-407 Revised 2/2003 AØSBfL DEC NONE , .'--'. .'-, ""'-"....., Suspended D WAG D 20AAC 25.110 Other _ 5. Date Comp., Susp., or Aband.: July 27, 2003 6. Date Spudded: July 11,2003 7. Date TD Reached: July 22,2003 ' 8. KB Elevation (ft): RKB 28' / 89' AMSL 9. Plug Back Depth (MD + TVD): 8539' MD 1 6505' TVD 10. Total Depth (MD + TVD): 8636' MD / 6592' TVD 11. Depth where SSSV set: SSSV @ 1820' 19. Water Depth, if Offshore: N/A feet MSL HOLE SIZE 1b. Well Class: Development 0 Exploratory D Service D Stratigraphic Test D 12. Permit to Drill Number: 203-115/ 13. API Number: 50-029-23164-00 14. Well Name and Number: 1 B-20 15. Field/Pool(s): Kuparuk River Field Kupruk River Oil Pool 16. Property Designation: ADL 25647 & 25648 17. Land Use Permit: ALK 466 & 465 20. Thickness of Permafrost: 1686' MD 42" CEMENTING RECORD AMOUNT PULLED 12.25" 874 sx AS 1 670 sx AS III Lite, 348 sx LiteCrete 201 sx Class G 126 sx Class G 8.5" 7" 24. SIZE 3.5" TUBING RECORD DEPTH SET (MD) 8261' PACKER SET (MD) 8242' & 7784' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 25. WATER-BBl 199 W A TER-BBL 398 ~ Wll3 CONTINUED ON REVERSE SIDE ( o R t G t N A L \3Y CHOKE SIZE 50 bean OIL GRAVITY - API (corr) 24° GAS-Oil RATIO 851 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) October 6, 2003 Gas lift Oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF 10/6/2003 12 hours Test Period n> 30 402 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF press. 143 psi 982 24-Hour Rate -> 56 808 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessaryk I:: C I:: I V I::: U Submit core chips; if none, state "none". DEC - 5 2003 Alaska Oil & Gas Cons. Commission Anchorage Submit in duplicate GEOLOGIC MARKERS ) 29. ) FORMATION TESTS 28. NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 B-20 Kuparuk C Kuparuk D 8141' 8126' 6145' 6132' N/A RECEIVED DEC - 5 2003 Alaska Oil & Gas Cons. Commission Anchorage 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Shane Cloninger @ 265-6829 Printed Nam~~. R. Thomas Title: Signature \. <-~ ~ '^--~Phone Kuparuk Drilling Team Leader '¿.f:; ç ~ biJs () Date , ¿( ~5 (0 "5 Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This torm is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1 a: 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 abour 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 tor 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, 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 OR1G\~\J¡~L Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ... ·:[)åte 7/1 0/2003 7/11/2003 7/12/2003 7/13/2003 7/14/2003 1 8-20 1 8-20 ROT - DRILLING n1334@ppco.com Doyon 141 ~QlJt$ COCJä8ôU:e Phasß 03:00 - 03:30 03:30 - 04:30 04:30 - 07:30 07:30 - 08:30 08:30 - 10:30 10:30 - 11 :30 11 :30 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 18:00 18:00 - 22:50 22:50 - 23:00 23:00 - 00:00 00:00 - 01 :00 01 :00 - 03:00 03:00 - 03:30 03:30 - 06:00 06:00 - 09:00 09:00 - 09:30 09:30 - 17:45 17:45 - 19:00 19:00 - 20:00 20:00 - 20:30 20:30 - 00:00 00:00 - 12:00 12:00 - 00:00 00:00 - 15:15 15:15 - 16:30 16:30 - 18:00 18:00 - 18:30 18:30 - 21 :00 21 :00 - 00:00 00:00 - 02:30 02:30 - 03:30 0.50 MOVE 1.00 MOVE 3.00 MOVE 1.00 MOVE 2.00 MOVE 1.00 MOVE 0.50 MOVE 1.00 MOVE 1.00 MOVE 4.00 DRILL 4.83 DRILL 0.17 DRILL 1.00 DRILL 1.00 DRILL 2.00 DRILL 0.50 DRILL 2.50 DRILL 3.00 DRILL 0.50 DRILL 8.25 DRILL 1.25 DRILL 1.00 DRILL 0.50 DRILL 3.50 DRILL 12.00 DRILL 12.00 DRILL 15.25 DRILL 1.25 DRILL 1.50 DRILL 0.50 DRILL 2.50 DRILL 3.00 DRILL 2.50 DRILL 1.00 CASE MOVE MOVE MOVE MOVE MOVE MOVE MOVE MOVE MOVE MOVE MOVE MOVE MOVE MOVE RURD RIGUP RURD RIGUP RIRD RIGUP PULD RIGUP OTHR RIGUP PULD RIGUP PULD SURFAC PULD SURFAC CIRC SURFAC OTHR SURFAC PULD SURFAC OTHR SURFAC DRLG SURFAC TRIP SURFAC PULD SURFAC TRIP SURFAC DRLG SURFAC DRLG SURFAC DRLG SURFAC DRLG SURFAC CIRC SURFAC WIPR SURFAC WIPR SURFAC CIRC SURFAC TRIP SURFAC PULD SURFAC RURD SURFAC Start: 7/10/2003 Rig Release: 7/27/2003 Rig Number: Spud Date: 7/10/2003 End: Group: ...". ...... ..... ... . . ... b.···øsþriptiqh9fqþßr.~tiþrïS ..... ... .. ........ .. Move pipe shed and rock washer. Move modules and sub oft well. Move modules and sub to 1 B pad. Move sub over well, level and shim. Spod modules, level and shim. Move pipe shed and rock washer to 1 B pad. Spot pipe shed and rock washer. Take on water to pits and nippled up. Rig accepted on 1 B-20 @ 1200 hrs 7/10/03. Spot rock washer and berm around same. (mix spud mud). extend diverter line beyond flow lines. Move camp. (mix spud mud) Hook up pipe skate, install riser pipe on stack. (mix spud mud) Go through pre spud check list. Load pipe shed w/150 joints 5" DP and PU same. Diverter and koomey test. Witness waived by John Spaulding (AOGCC). PU HWDP. Pick up HWDP & 1 Stand DC's, Stand back in derrick Make up BHA #1 & Oreint same Fill conductor & diverter with mud Observe leak at FMC riser connector & attempt to repair same - No Good, Remove end section ot diverter line to modify same. (Note; Riser connector in bind, Due to diverter line going under Pad flow lines.) Stand back BHA & Pick up 28 stands drill pipe. (While modifying diverter line) Wait on orders to proceed by AOGCC Tom Maunder for verble approval on modifcation to diverter line -OK. Spud @ 0930 hrs. Drill f/ 138' to 915' ART = 2.9 hrs AST = 1.4 hrs 10-15 WOB, 80 RPM, 506 GPM @ 1200 PSI, UP 90K, DN 90K, ROT 90K, TO 2500, MWD Failed @ 915' - Would not switch over from Magnetic to High side. POOH to MWD Change out MWD, Orient new MWD, Check bit -OK RIH (Test MWD -OK) to 915' Drill f/ 915' to 1259' ART = .9 hrs AST = .8 hrs 15-20 WOB, 80 RPM, 506 GPM @ 1250 PSI, UP 90K, DN 90K, ROT 90K, TO 2500. Drill fl 1259' to 2744' (2438' TVD) AST= 5.5 hrs ART= 2.4 hrs UP 115K DN 96K ROT = 105K, TO ON BTM= 4,000 ft/lb, TO OFF BTM= 3,000 ft/lb, 590 GPM @ 1600 PSI, WOB 20K, RPM 100 Drill f/ 2744' to 4137' (3321' TVD) AST = 1.8 hrs ART = 5.2 hrs UP 140K DN 105K ROT= 120K, TO ON BTM= 9,000 ft/lb, TO OFF BTM= 7,000 ft/lb, 590 GPM @ 1800 PSI, WOB 25K, RPM 100 Drill fl 4137' to 5230' (4014' TVD) AST = 1.9 hrs ART = 9.1 hrs, UP 155K, DN 120K, ROT 132K, 590 GPM @ 2150 PSI, 100 RPM, 20-30K WOB Pump Hi-Vis weighted sweep & circ for wiper trip Precautionary back ream out to 4137', Slight packing off. RIH to 5230' no problems Pump Hi-Vis weighted sweep & Circ hole clean total of 3.5 btm's up, 590 GPM @ 2150 PSI 100 RPM wI 7,000 ft/lb TO POOH to BHA (Hole in very good shape- Pulled 30K over f/ 1800' to 1700', wiped out very good) Lay down BHA, Clear rig floor Rig up GBR 9-5/8" Fill up tool & Doyon casing tools. Printed: 8/14/2003 4:13:54 PM 3.50 CASE RUNC SURFAC PJSM, Run 9-5/8", 40#, L-80, BTC casing to 2955' with no problems. 1.00 CASE CIRC SURFAC Circ. btm's up @ 2955' stage rate up to 6 bpm @ 500 psi, No mud loss 2.00 CASE RUNC SURFAC Run 9-5/8" csg to 5139' - Hit tight spot 0.50 CASE RUNC SURFAC Work thru tight spot & run csg. to 5190' 0.50 CASE RUNC SURFAC Make up hanger & landing joint, Land csg. at 5221' 1.00 CASE RURD SURFAC Lay down GBR fill up tool, Make up Dowell cement head. 4.7S CEMENTCIRC SURFAC Circ. & condo mud for cement job 7 bpm @ 370 psi. No mud loss. 4.25 CEMENT PUMP SURFAC Held PJSM, Switch to Dowell, Mix & pump 5 bbls CW1 00, Pressure test lines to 3500 psi, Mix & pump 45 more bbls of 8.3 ppg CW100 at rate of 4.5 bpm @ 350 psi, Shut down, Drop btm plug, Mix & pump 50 bbls MudPUSH wI Red dye added at 10.5 ppg at rate of 4.5 bpm @ 280 psi, Followed by 670 sxs (511.0 bbls) ARCTICSET Lead cmt. mixed at 10.7 ppg w/1.5%D79, 1.5%S001, .6%046, .5%D65, 43.1 %0124, 30.0%D53, 9.0%D44 at rate of 6.3 bpm @ 300 psi, Followed by 348 sxs (141.0 bbls) LiteCRETE Tail cmt. mixed at 12.0 ppg wI .8%065, .6%D46, .3%079 at rate of 5 bpm @ 250 psi, Pumped 2 bbls fresh water, Shut down, Drop top plug, Displace cmt. w/ 20 bbls fresh water followed by 370.5 bbls 9.4 ppg mud at rate of 6.5 bpm @ 400 psi, Had red dye to surface after 94.0 bbls of displacement, Slowed rate down to 2.6 bpm @ 800 psi for last 20 bbls of displacement, Bumped plug w/1300 psi, C.I.P @ 2045 hrs 7/14/03, Had good circ. thru out job, Floats held -OK, Worked csg. until started pumping tail cmt, Had 191.0 bbls cement returns to surface. Rig down Dowell cmt. head, Lay down landing joint, Flush out diverter system. Nipple down Diverter system. Nipple up FMC Gen 5 Wellhead & test to 1000 psi -OK. Nipple up BOPE. Install test plug, Test all valves & BOPE to 5000 psi & Hydril to 3500 psi, Test waived by AOGCC Jeff Jones, Remove test plug, Install wear bushing. Derrick Inspection, Service top drive. Make up & Program BHA #3, Surface test same. RIH & tag tloat collar @ 5139' Circ. fl casing test Test 9-5/8" casing to 3500 psi f/30 -OK, Record test on chart. Drill out float collar @ 5139', Cmt, Shoe @ 5221',20' of new hole to 5250' Circ & Balance mud weight to 9.3 ppg Perform F.I.T wI 9.3 ppg mud, 1450 psi, 4010' TVD = 16.3 ppg EMW Drill fl 5250' to 5850' (TVD 4406'), ART = 4.4 hrs AST = 0.3 hrs, UP 190K, DN 1 07K, ROT 131 K, TO 150n/140ff Drill f/5850' to 6930' (TVD 5132') AST= 0.9 hrs. ART= 7.9 hrs, UP 210K, DN 116K, ROT 148K, TO 10-15 on /16-18 off, 10-20 WOB, 100 RPM, 506 GPM @ 2400 psi, Pump Hi-vis sweeps as needed Drill fl 6930' to 7487' (TVD 5565') AST = 1.7 hrs. ART = 7.2 hrs, UP 215K, DN 126K, ROT 158K, TO 11-18 on I 12-17 off, 5-10 WOB, 100-110 RPM, 523 GPM @ 2450 psi, Pump Hi-vis sweeps as needed Drill f/7487' to 7974' AST = 1.0 hrs ART = 3.4 hrs, WOB 15K, RPM 110, 523 GPM @ 2850 psi, UP 230K, DN 133K, ROT 169K, TO 13-19 off 112-18 on. Circ tor Geologist & E-mail logs to office. Drill fl 7974' to 8015' AST = 0 hrs ART = .S hrs, WOB 15K, RPM 110, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-20 1 8-20 ROT - DRILLING n1334@ppco.com Doyon 141 .... Déîte··.· ... ... FrOm"·[6! ·..hlÒUrs ·CödØ .cfd~ePhå$é; 7/14/2003 03:30 - 07:00 07:00 - 08:00 08:00 - 10:00 10:00 - 10:30 10:30 - 11 :00 11 :00 - 12:00 12:00 - 16:45 16:4S - 21 :00 21 :00 - 22:00 1.00 CEMENT PULD SURFAC 22:00 - 00:00 2.00 WELCTL NUND SURFAC 7/15/2003 00:00 - 00:30 0.50 WELCTL NUND INTRM1 00:30 - 02:30 2.00 WELCTL NUND INTRM1 02:30 - 07:30 5.00 WELCTL BOPE INTRM1 07:30 - 08:00 0.50 RIGMNT RSRV INTRM1 08:00 - 10:00 2.00 DRILL PULD INTRM1 10:00 - 12:00 2.00 DRILL TRIP INTRM1 12:00 - 12:30 0.50 DRILL CIRC INTRM1 12:30 - 13:30 1.00 DRILL DEOT INTRM1 13:30 - 14:45 1.25 DRILL DRLG INTRM1 14:45 - 15:45 1.00 DRILL CIRC INTRM1 15:45 - 16:30 0.75 DRILL FIT INTRM1 16:30 - 00:00 7.50 DRILL DRLG INTRM1 7/16/2003 00:00 - 12:00 12.00 DRILL DRLG INTRM1 12:00 - 00:00 12.00 DRILL DRLG INTRM1 7/17/2003 00:00 - 06:15 6.25 DRILL DRLG INTRM1 06:15 - 06:30 0.25 DRILL CIRC INTRM1 06:30 - 07:00 0.50 DRILL DRLG INTRM1 Start: 7/10/2003 Rig Release: 7/27/2003 Rig Number: Spud Date: 7/10/2003 End: Group: .. .. .. ......... ·..·""0 .. .... .. ..... .. ... ... .. .. .... "." . . . . . .. . '" . . !·Døs¢r¡ptidh¡ÞfOp~få.HQH$· ... Printed: 8/14/2003 4:13:54 PM ') ') . . . . .. .. ". .... ".."."." ".". . . ..... .. .... ..... ...... ........ .. .. .:. ".. . > ... .i.·..'ÇQ9'qêºPhiIHp§¡~I~~k~: . .,....i i' .. ...'. .. ... ·.··I~p¡ë~~ti()n~$,~.p!H1~~y@~p~rt.~.· ¡.' 523 GPM @ 2850 psi, UP 230K, ON 133K, ROT 169K, TQ 13-19 off I 12-18 on. Pump Hi-vis weighted sweep, Circ 3 btm's up & hole clean at rate of 530 GPM @ 2700 psi, Monitor well, Pump dry job. Wipe hole to shoe @ 5222' - Hole in very good shape, Precautionary ream btm 60' - No fill. Circ. btm's up - trip gas 437 units, Pump Hi-vis weighted sweep, Raise mud weight to 10.1 ppg. Wipe hole to 7100', Observe well- OK, RIH to 8015' Circ. btm's up - trip gas 70 units. Monitor well, Dry pipe, POOH to BHA (Hole in good shape) Lay down 2 jts HWDP, Jars, 3 jts CSDP, Break bit, Down load MWD, Lay down BHA Clear rig floor of drilling tools. Change top pipe BOP rams to 7", Test rams to 250 low & 5000 high. Rig up Frank's fill up tool & 7" casing tools. PJSM, Run 7", 26#, L-80, BTCM casing to 2500' at rate of 50/60 ftImin.- no problems. Break circ. @ 2500' at 4 bpm @ 300 psi. Run 7", 26#, L-80, BTCM casing to 5221' at rate of 50/60 ftlmin.- no problems. Circ. casing volume @ 5221' at 5 bpm @ 600 psi circ total of 241 bbls, No mud lost. Run 7", 26#, L-80, BTCM casing to 8005' (Total of 194 jts.) at rate of 4S ftImin.- no problems, Make up landing joint, Land casing in hanger & shoe @ 8005.65'. Rig down Frank's fill up tool, Rig up Dowell cement head. UP 237K, DN 122K Work pipe & circ. (Had trouble staging pump rate up), Slowly stage rate up from 1 bpm @ 550 psi to 6 bpm @ 550 psi, Condition mud from MW 10.4 ppg, vis 71, PV 25, YP 34, gels 20/41, FL 3.2, PH 9.3, Condition mud to MW 10.0, vis 42, PV 12, YP 14, gels 6/11, FL 3.8, PH 8.9, Held PJSM for cmt job. 1.50 CEMENT PUMP INTRM1 Switch to Dowell, Mix & pump 10 bbls CW1 00, Pressure test lines to 3500 psi, Continue mix & pump 20 more bbls of 8.3 ppg CW100 at rate of 5.1 bpm @ 530 psi, Followed by 30 bbls 11.2 ppg MudPUSH at rate of 5.0 bpm @ 530 psi, Shut down, Drop btm plug, Mix & pump 201 sxs (41.7 bbls) Class 'G' cmt. w/.200%D46, .300%065, .350%0167, .050%B155 mixed at 15.8 ppg at rate of 5.0 bpm @ 675 psi, Shut down, Drop top plug, Displace cmt. wI 10 bbls fresh water tollowed by total of 290.9 bbls 10.0 ppg mud at rate of 6.0 bpm @ 700 psi, Slowed rate to 3.0 bpm @ 550 psi for last 16 bbls of displacement, Bumped plug w/1200 psi, CIP @ 2000 hrs. 7/18/03, Had good circ. thru out job, Floats held -OK, Worked csg. through out job, No noticeable mud loss, Well static. Rig down Dowell cmt. head, Landing joint, Csg. tools. Install FMC 11" x 7" Pack off, Test same to 5000 psi f/ min.- OK Slip & cut drilling line 78', Adjust brakes on drawworks, Start changing rams on BOP to 4", Load pipe shed w/ 246 jts 4" drill pipe. Test top & btm 4" BOP rams to 250 psi low & 5000 psi high. Change saver sub to 4" on top drive, Clear rig floor. Lay down 5" drill pipe from derrick in mouse hole. Change over to 4" handling tools. Legal Well Name: 1 8-20 Common Well Name: 1 8-20 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 :':':" . Sub·, ~··[)at~ F=rômHfÖ HöUrs'.Cöde ÇOde. Phase .'.'¡ 7/17/2003 06:30 - 07:00 0.50 DRILL DRLG INTRM1 07:00 - 09:30 2.50 DRILL CIRC INTRM1 09:30 - 12:30 3.00 DRILL WIPR INTRM1 12:30 - 14:45 2.25 DRILL CIRC INTRM1 14:4S - 16:1S 1.S0 DRILL WIPR INTRM1 16:1S -17:30 1.25 DRILL CIRC INTRM1 17:30 - 23:00 5.50 DRILL TRIP INTRM1 23:00 - 00:00 1.00 DRILL PULD INTRM1 7/18/2003 00:00 - 00:30 0.50 DRILL PULD INTRM1 00:30 - 01 :30 1.00 WELCTL EaRP INTRM1 01 :30 - 03:00 1.50 CASE RURD INTRM1 03:00 - 05:45 2.75 CASE RUNC INTRM1 05:45 - 06:00 0.25 CASE CIRC INTRM1 06:00 - 09:00 3.00 CASE RUNC INTRM1 09:00 - 10:00 1.00 CASE CIRC INTRM1 10:00 - 13:45 3.75 CASE RUNC INTRM1 13:45 - 14:15 0.50 CASE RURD INTRM1 14:15 - 18:30 4.2S CEMENTCIRC INTRM1 18:30 - 20:00 20:00 - 21 :30 1.50 CEMENT PULD INTRM1 21 :30 - 22:30 1.00 WELCTL NUND INTRM1 22:30 - 00:00 1.50 RIGMNT RSRV PROD 7/19/2003 00:00 - 01 :00 1.00 WELCTL BOPE PROD 01 :00 - 03:00 2.00 DRILL OTHR PROD 03:00 - 09:30 6.50 DRILL PULD PROD 09:30 - 10:00 0.50 DRILL OTHR PROD Start: 7/1 0/2003 Rig Release: 7/27/2003 Rig Number: Spud Date: 7/10/2003 End: Group: ØØ$criptiÞn ()rpþér~tiqn$'; Printed: 8/14/2003 4: 13:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-20 1 8-20 ROT - DRILLING n1334@ppco.com Doyon 141 Frö/"T1'+TbHÞLlts' ¡Oodß ièfd~e phase 7/19/2003 10:00 - 11 :00 1.00 DRILL PULD PROD 11 :00 - 11 :30 0.50 RIGMNT RSRV PROD 11 :30 - 13:00 1.50 DRILL PULD PROD 13:00 - 15:30 2.50 DRILL PULD PROD 1S:30 - 17:30 2.00 DRILL PULD PROD 17:30 - 18:15 0.75 DRILL PULD PROD 18:15 - 19:30 1.25 DRILL PULD PROD 19:30 - 23:45 4.25 DRILL PULD PROD 23:45 - 00:00 0.25 DRILL CIRC PROD 00:00 - 00:30 0.50 DRILL OTHR PROD 00:30 - 01 :00 0.50 DRILL CIRC PROD 01 :00 - 01 :45 0.75 DRILL DEOT PROD 01 :45 - 03:45 2.00 DRILL OTHR PROD 03:45 - 10:00 6.25 DRILL CIRC PROD 7/20/2003 10:00 - 11 :30 1.S0 DRILL DRLG PROD 11 :30 - 12:30 1.00 DRILL CIRC PROD 12:30 - 13:15 0.75 DRILL FIT PROD 13:15 - 14:00 0.75 DRILL CIRC PROD 14:00 - 00:00 10.00 DRILL DRLG PROD 7/21/2003 00:00 - 12:00 12.00 DRILL DRLG PROD 12:00 - 00:00 12.00 DRILL DRLG PROD 7/22/2003 00:00 - 18:30 18.50 DRILL DRLG PROD 18:30 - 20:00 CIRC PROD 1.50 DRILL 20:00 - 21:15 1.25 DRILL REAM PROD 21 :15 - 21 :30 21 :30 - 22:00 22:00 - 00:00 0.25 DRILL 0.50 DRILL 2.00 DRILL OBSV PROD TRI P PROD CIRC PROD Start: 7/1 0/2003 Rig Release: 7/27/2003 Rig Number: Spud Date: 7/10/2003 End: Group: . ...... .... . ,".. .' .." ,". "., ,",. . . ...... ". .. ..' .... ..... .. ..... .... ..... .. "IJ~$ºtiþtiÞn'()fOPßrï:1tions; Pick up 8 stands 4",14#, S-135, XT-39 drill pipe & stand back in derrick. Service rig & top drive Pick up 10 stands 4",14#, S-135, XT-39 drill pipe & stand back in derrick. Make up BHA #4, 6"x7" Bi-Center bit, Set motor to 1.2 AKO, Stab, MWD, Program MWD. Change out 2 of 6 blades on density tool due to over sized stand off & would not fit in 7" casing. PJSM, Load R.A. Sources Pick up 29 jts HWDP, Jars, RIH & Shallow test MWD @ 1200' Pick up 4", 14#, S-135, XT-39 drill pipe to 7852' Circ & wash fl 7852 to 7888' (Tag hard cmt), 200 GPM @ 1600 psi Clean out cmt to float collar @ 7918' Circ. btm's up wI 200 GPM @ 1550 psi Rig & test 7" casing to 3500 psi tl 30 min. -OK Drill out float collar @ 7918', Cmt, Shoe @ 8005' and clean out to TD @ 8015' Circ & treat out cement contamination, Raise mud weight to 12.2 ppg using sack material. (Note; Unable to receive weighted spike fluid tor raising mud weight due to Nordic #2 stuck in road between Kuparuk and Kuparuk river.) Drill fl 8015' to 8035' (TVD 6051') ART = 1.5 hrs, WOB 14K, RPM 80, 200 GPM @ 22S0 psi, PU 175K, DN 92K, ROT 118K, TO off 1 OK! on 8K Circ btm's up for Leak off test Perform F.I.T to 16.0 ppg EMW wI 1200 psi, 6024' TVD, 12.2 ppg mud Perform PWD base line tests for ECD clean hole = 13.7 ppg. Drill fl 8035' to 8105' (6114' TVD) ART= 9.6 hrs, WOB 12K, RPM 100, 220 GPM @ 2150 psi, UP 172K, DN 97K, ROT 122K, TO off 7K! on 7K, Max ECD's 13.85 ppg Drill fl 8105' to 8270' (TVD 6261') ART= 7.4 hrs AST= 2.9 hrs UP 170K, DN 103K, ROT 130K, TO 8K offl 9K on Drill fl 8270' to 8465' (TVD 6438') ART = 10.9 hrs AST = 0 hrs, WOB 15K, RPM 120, GPM 233 @ 2130 psi, UP 158K, ON 110K, ROT 126K, TQ 7K offl 8K on, Max ECD's 14.2 ppg, Gas 0-20 units, Mud weight 12.2 ppg in & out. Drill 6" x 7" Hole from 8,46S' to 8,636' MOl 6,592' TVD (171') (T.D.) ART 17.5 Hrs, AST -0-, 10-1SK WOB, 120 rpm's, 52 spm, 220 gpm, off btm press 2,200 psi, on btm 2,450 psi, off btm torque 11 K ft-Ibs, on btm 8.5K ft-Ibs, Rot wt 131 K, Pu wt 168K, Dn wt 111 K, 12.2 ppg mw, ave ECD 14.0 ppg, ave bgg 1-2 units, no mud loss while drlg KUP. NOTE: Chuck Scheve with AOGCC Approved testing of BOPS after setting & Cementing of 5 1/2" liner Pumped 20 bbl wt'd hi vis sweep (2# over mw) and circ out, had 30% increase in cuttings with sweep, circ add btms up, circ at 220 gpm at 2,100 psi and 120 rpm's Monitored well-static, backreamed out @ drlg rate from 8,636' to 7,980'. (Csg shoe @ 8,005') Pull15K over at 8,465', worked thru sevaral times & ck ok, no other problems POOH to shoe. Monitored well at shoe-static TIH, washed 36' to btm with no problems Pumped 20 bbl wt'd hi vis sweep & circ hole clean, at btms up max gas Printed: 8/14/2003 4: 13:54 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-20 1 8-20 ROT - DRILLING n1334@ppco.com Doyon 141 Date F:röt~l+TÖ · HóúrsGódè" ¿,ci£ê: I : Phase 7/22/2003 22:00 - 00:00 2.00 DRILL CIRC PROD 7/23/2003 00:00 - 01 :00 1.00 DRILL REAM PROD 01 :00 - 01 :30 0.50 DRILL OBSV PROD 01 :30 - 05:00 3.50 DRILL TRIP PROD 05:00 - 05: 15 0.25 DRILL SFTY PROD 05:15 - 08:30 3.25 DRILL PULD PROD 08:30 - 09:00 0.50 CASE RURD PROD 09:00 - 11 :00 2.00 CASE PULR PROD 11 :00 - 13:00 2.00 CASE PULR PROD 13:00 - 13:30 0.50 CASE PULR PROD 13:30 - 21 :00 7.50 CASE RUNL PROD 21 :00 - 22:00 1.00 CASE CIRC PROD 22:00 - 23:00 1.00 CASE RUNL PROD 23:00 - 00:00 1.00 CEMENT PROD 7/24/2003 00:00 - 01 :30 1.50 CEMENTCIRC PROD 01 :30 - 02:15 0.75 CEMENT PUMP PROD 02:15 - 03:00 0.75 CEMENTDISP PROD 03:00 - 03:30 0.50 CEMENTOTHR PROD 03:30 - 04:15 0.75 CEMENTCIRC PROD 04: 15 - 04:45 04:4S - OS:30 05:30 - 08:30 0.50 CEMENT OTHR PROD 0.75 CEMENT RURD PROD 3.00 CASE RUNL PROD Start: 7/10/2003 Rig Release: 7/27/2003 Rig Number: Spud Date: 7/10/2003 End: Group: D~$çr¡ptiqn()ft)Þßr~tiQn$·. ... 4 units, had 30% increase in cuttings at btms up, cont to circ hole clean, circ a total of 3 btms up, circ at 235 gpm at 2,200 psi at 120 rpm's, 12.2 ppg mw in & out, ave ECD 14.0 ppg, max ECD 14.4, final ECD 13.95 ppg with 1 unit bgg, Rot wt 131 K, Pu wt 168K, On wt 111 K Precautioanary backreamed out at drlg rate 220 gpm 2,100 psi & 100 rpm's from 8,636' to 7,927' with no problems Monitored well at shoe-static, pumped dry job and dropped 1 7/8" rabbit on 120' of wire POOH & stood back hwdp, retrieved rabbit & wire, slm, no corr Held PJSM on removing radioactive sources Removed radioactive sources, down loaded MWD/LWD and LD BHA, cleared rig floor RU to run 5 1/2" Liner and held PJSM PU Float Shoe Jt and set down at 26', POOH and found centralizer set screws too long, ground down set screws on centralizers to clear 7" csg MU Baker 51/2" Insert Fit Shoe, 1 Jt 5 1/2" 15.5# L-80 Hydril511 liner, 5 1/2" Insert Fit Collar, 1 Jt 5 1/2" Liner, Insert Landing Collar, then ran 16 jts of 5 1/2" 15.5# L-80 Hydril 511 Liner, Ran a total of 18 Jts 775.62', ran 32 close tolerance bowspring centralizers per well program MU Baker 5 1/2" x 7" "HMC" Liner hanger with "CPH" Liner top pkr with XO & RIH to 794' Total length of Hanger/Pkr assembly 18.88' RIH slow with 51/2" liner on 4" DP to 7,960' Circ 1 DP cap at shoe at 3 bpm at 1,200 psi, up wt 145K, dn wt 8SK Ran in open hole with liner, MU Cmt head & est eire, washed down and tagged btm at 8,636' with no problems Circ & cond mud for cementing liner, Lowering YP from 30 to 18, 12.2 ppg mw in & out, circ at 3 bpm at 1,050 psi and reciprocated pipe, max gas at btms up 265 units, no mud loss, up wt 152K, dn wt 90K Fin circ & cond mud for cmtg liner, lowered YP from 30 to 17 with 12.2 ppg mud in & out, reciprocated pipe & circ at 3 bpm and 700 psi, up wt 152K, dn wt 90K, held PJSM with Dowell & rig crew on cementing liner, batch mixed cement while circ. Turned over to Dowell, pumped 5 bbls ot CW100 @ 8.3 ppg, press tested lines to 4,500 psi, pumped 5 more bbls CW 100 and 30 bbls of 12.5 ppg Mudpush, followed with 26 bbls, 126 sxs of 15.8 ppg 1.16 yield cmt with additives, ave 3 bpm, ICP 900 psi, FCP 665 psi shut down and washed up lines and dropped wiper plug. Displaced cement with Dowell, displaced with 8.5 ppg 3% KCL at 3 bpm, ICP 830 psi, didn't see LWP shear, slowed rate to 2-1/2 bpm, pumped calc displacement of 99.2 bbls plus 1 add bbl and plug didn't bump, final circ press 2,500 psi, reciprocated pipe through out job with tull returns, checked floats & held, CIP @ 03:00 hrs Set Liner on Btm and Set Baker 5 1/2" x 7" "CHP" Liner top pkr with shoe at 8,636', landing collar at 8,552' and TOL at 7,841', set 50K wt down on TOL (Unable to set hanger) PU out of Liner, pumped 20 bbl HEC hi vis sweep & circ hole displacing out 12.2 ppg mud with 8.5 ppg 3% KCL, at btms up had +1- 10 bbls of contaminated cmt back, max wt 13.7 ppg, circ out sweep and fin displacement, initial rate of 330 gpm at 2,SOO psi, final rate 470 gpm at 2,SOO psi, up wt 130K, dn wt 105K Monitored well-static, cleaned out valves on stand pipe manifold LD 1 jt of 4" DP, LD plug dropping head POOH & LD Liner setting tool Printed: 8/14/2003 4:13:54 PM 0.50 WELCTL OTHR PROD Pulled wear bushing & Installed test plug 4.00 WELCTL BOPE PROD RU & tested BOPE, rams, choke and floor valves to 250 psi low and 5,000 psi high, tested annular to 250 psi and 3,500 psi, performed accumulator test, RD NOTE: John Crisp with AOGCC waived witnessing ot test Installed wear bushing RU HES Slickline, MU 4.7" gauge ring RIH with 4.7" gauge ring, set down at 8,330', worked down to 8,365', unable to work deeper, POOH & RD slickline Serviced rig & top drive TIH with 10 stds of 4" HWDP, POOH LD 29 Jts DP and jars Changed out lower 4" rams to 2 7/8" rams Pulled wear bushing & Installed test plug RU & Tested Lower 27/8" pipe rams to 250 psi and 5,000 psi, RD & Installed wear bushing RU Doyon's 2 7/8" handling tools, held PJSM and MU BHA #5, 4 3/4" 5 bladed mill, 12-31/8" DC's, & 12 jts of 2 7/8" PAC DP & RIH to 725' TIH with cleanout assembly on 4" DP to 3,526' Cont TIH with cleanout assembly from 3,526' and set down at 8,365' with 5K wt Est circ at 280 gpm at 2,000 psi, 60 rpms, 6K ft-Ibs torque, rot wt 123k, up wt 145K, dn 120K, washed down to 8,381' & set down with 5K wt, increased pump to 32S gpm, 2,500 psi and drilled up wiper plug, cont washing down to landing collar at 8,552' with no wt, at btms up had only recovered rubber from plug and no cement Pumped 30 bbl HEC sweep & circ hole clean, no cement back from btms up, circ at 325 psi, final press 2,250 psi, spotted 40 bbls of clean 8.5 ppg 3% KCL in liner Pressure tested 5 1/2" liner & packer to 2,500 psi for 15 min, good test POOH with cleanout assembly to 725' @ BHA LD BHA #5,12 jts 27/8" PAC DP, 12- 31/8" Dc's and 4 3/4" mill Changed out btm set of rams from 27/8" back to 4" Pulled wear bushing, RU & tested both sets of pipe rams to 250 psi low, 5,000 psi high, tested annular to 250 psi and 3,500 psi, RD & installed wear bushing RU Doyons 2 7/8" Handling tools and brought Schlumbergers TCP perf guns to rig floor Held PJSM on MU TCP guns & RIH PU & MU 102' of 3 3/8" Perf Guns with 50' of loaded and 52' of blank guns, MU 11 jts of 2 7/8" L-80 hydril 511 tbg with XO to DP TI H with TCP assembly, tagged TOL locator with 5 1/16" XO at 7,849', PU 62' to put guns on depth, installed safety valve and est SPR's prior to perf Held PJSM with Schlumberger & rig crew on perf well & circ well out on choke Closed annular preventer, press up to 2,900 psi for 2 min, bled oft press and guns fired after 10 min. perf KUP "C" sands from 8,143' to 8,193' (50') per well plan with 3 3/8" guns, 60 deg phasing and 215 shots total, had good indication guns fired 1.00 WELCTL OBSV CMPL TN Monitored well at choke, after 1 hr SIDPP 140 psi, SICP 170 psi 1.25 WELCTL KILL CMPL TN Killed well thru choke by displacing out 8.5 ppg 3% KCL with 9.5 ppg brine and 40 spm, ICP 440 psi, FCP 316 psi, had 9.5 ppg brine back after 2,693 stks, (calc strokes surface to surface), at btms up did not Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-20 1 8-20 ROT - DRILLING n1334@ppco.com Doyon 141 ·I:;)~tê Ftörh-ltö¡ . Hqurs¡ ¡(JQdø ¿dU:e. phášè. 7/24/2003 08:30 - 09:00 09:00 - 13:00 13:00 - 13:30 0.50 WELCTL OTHR PROD 13:30 - 15:00 1.50 CMPL TN SLlN PROD 15:00 - 16:00 1.00 CMPL TN SlIN PROD 16:00 - 16:30 0.50 RIGMNT RSRV PROD 16:30 - 18:30 2.00 DRILL PULD PROD 18:30 - 19:30 1.00 WELCTL OTHR PROD 19:30 - 20:00 0.50 WELCTL OTHR PROD 20:00 - 21 :00 1.00 WELCTL BOPE PROD 21 :00 - 23:00 2.00 CMPL TN PULD PROD 23:00 - 00:00 1.00 CMPL TN TRIP PROD 7/25/2003 00:00 - 02:30 2.50 CMPLTN TRIP PROD 02:30 - 04:30 2.00 CMPL TN FCO PROD 04:30 - 05:30 1.00 CMPL TN CIRC PROD 05:30 - 06:00 0.50 CMPL TN DEQT PROD 06:00 - 09:00 3.00 CMPL TN TRIP PROD 09:00 - 11 :00 2.00 CMPL TN PULD PROD 11 :00 - 12:00 1.00 WELCTL OTHR PROD 12:00 - 13:45 1.75 WELCTL BOPE PROD 13:45 - 15:15 1.50 CMPL TN RURD CMPL TN 15:15 - 15:30 0.25 CMPLTN SFTY CMPL TN 15:30 - 16:15 0.75 CMPL TN PULD CMPL TN 16:15 - 20:1S 4.00 CMPL TN TRIP CMPL TN 20: 15 - 20:30 0.25 CMPL TN SFTY CMPL TN 20:30 - 21 :00 0.50 CMPL TN PERF CMPL TN 21 :00 - 22:00 22:00 - 23:1S Start: 7/10/2003 Rig Release: 7/27/2003 Rig Number: Spud Date: 7/10/2003 End: Group: . ,"." .... ..", . . ... ..¡... ···b~s¢riPtiÓhqf ()Pßråt¡PD~ ... Printed: 8/14/2003 4: 13:54 PM . . ":".":, . .... ... .... .. ....... . . .. . .. . . . , ,ConocoPhillips Alaska "';!:¡:::9perations¡:~,gmmary Report' ' have any show of gas or oil, circ a total of 3,000 stks, had full returns while circ well Monitored well at choke 10 min and had no press build up, opened choke and had no flow, opened annular and monitored well add. 15 min and well static Began circ add. hole volume prior to POOH, circ at 250 gpm at 800 psi with full returns, up wt 155K, dn wt 97K Fin circ 1 complete circ after perf and monitoring well, circ at 250 gpm at 800 psi, no shows at btms up Monitored well-static POOH to TCP assembly to 432' Monitored well-static Held PJSM on LD 2 7/8" Tbg & 3 3/8' TCP guns POOH LD 11 jts 2 7/8" Tbg and 3 3/8" TCP guns, all 215 shots fired Pulled wear bushing & installed test plug, changed out btm set of 4" rams to 31/2" RU & tested lower 3 1/2' rams to 250 psi low and 5,000 psi high, RD & pUlled test plug RU Doyons 31/2" tbg handling tools Held PJSM on PU & Running 3 1/2" completion assembly & 3 1/2' tbg MU 3 1/2" Completion assembly per well plan and RIH PU 3 1/2" tbg to 6,425' RU Schlumberger control line reel and MU 3 1/2" TRM-4E SSSV and tested to 5,000 psi for 10 min Cont to RIH with 3 1/2" completion assembly, Ran a total of 253 jts of 3 1/2" 9.3 ppf L-80 EUE 8rd Mod Tbg, 6 GLM's and Baker's completion assembly per well plan (8,261.39'), PU landing Jt #254 and placed string on depth 1.00 CMPL TN PCKR CMPL TN Dropped 1-5/16" RHC ball and rod, RU to pump down tbg, pressured up and PBR hydraulically set at 3,500 psi, cont to pressure up to 4,500 psi for 10 min and set both SABL-3, 3-1/2' x 5-1/2', & Premier 3-1/2" x 7' permenant pkrs. 1.25 CMPL TN PULD CMPL TN PU and PBR had sheared, PU wt 95K. MU tbg hanger, connected SSSV control line to hanger and tested line to 5,000 psi for 10 min. Landed hanger and RILDS. Landed completion string with WLEG at 8,261',3-1/2' x 5-1/2' SABL-3 pkr at 8,242', "CMD" sliding sleeve at 8,225', blast jts with 60' of blast rings from 8,138' to 8,198',3-1/2" x 7" Premier perm pkr set at 7,784', PBR at 7,764', DCK shear valve at 7,742', SSSV at 1,822' and 5 GLM's per well plan. 0.25 CMPL TN RURD CMPL TN LD landing jt and RD contolline reel 0.50 CMPL TN NUND CMPL TN Installed TWC and began ND BOP's 1.50 CMPL TN NUND CMPL TN ND BOP stack 3.50 CMPL TN NUND CMPL TN Orient & NU FMC Gen V 5M Tree, Connected control line, Closed SSSV and tested packott and tree to 5,000 psi. Pulled TWC and opened SSSV 1.00 CMPL TN DEQT CMPL TN Pressured up on 3 1/2" Tbg and seal assembly to 3,500 psi for 5 min & ck ok, bled tbg down to 1,500 psi and Press up on 3 1/2" x 7" Ann to 3,500 psi and tested same for 30 min, good test 1.00 CMPL TN DEQT CMPL TN Bled tbg press down to -0- to shear DCK valve at 7,740', valve did not shear, attempted to shear valve press up on tbg and ann and bleeding down with no success, press up on ann to 4,500 psi while attempting to shear valve 0.25 CMPL TN OTHR CMPL TN Installed BPV in tree Legal Well Name: 1 8-20 Common Well Name: 1 8-20 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours: Code ! Sub Phase . . Code 7/25/2003 22:00 - 23:15 1.25 WELCTL KILL CMPL TN 23:15 - 23:45 0.50 WELCTL OBSV CMPL TN 23:45 - 00:00 0.25 CMPL TN CIRC CMPL TN 7/26/2003 00:00 - 00:30 0.50 CMPL TN CIRC CMPL TN 00:30 - 00:45 0.25 CMPL TN OBSV CMPL TN 00:45 - 04:15 3.50 CMPL TN TRIP CMPL TN 04:15 - 04:30 0.25 CMPL TN OBSV CMPL TN 04:30 - 04:45 0.25 CMPL TN SFTY CMPL TN 04:45 - 06:30 1.75 CMPL TN PULD CMPL TN 06:30 - 08:00 1.50 WELCTL OTHR CMPL TN 08:00 - 09:00 1.00 WELCTL BOPE CMPL TN 09:00 - 09:30 0.50 CMPL TN RURD CMPL TN 09:30 - 09:45 0.25 CMPL TN SFTY CMPL TN 09:45 - 17:30 7.75 CMPL TN RUNT CMPL TN 17:30 - 18:30 1.00 CMPL TN RURD CMPL TN 18:30 - 21 :00 2.50 CMPL TN RUNT CMPL TN 21 :00 - 22:00 22:00 - 23: 15 7/27/2003 23: 15 - 23:30 23:30 - 00:00 00:00 - 01 :30 01 :30 - 05:00 05:00 - 06:00 06:00 - 07:00 07:00 - 07:15 Pªge 7 018: Start: 7/10/2003 Rig Release: 7/27/2003 Rig Number: Spud Date: 7/10/2003 End: Group: Description of Operations . .. ..-...- - . Printed: 8/14/2003 4: 13:54 PM ..... . ConocoPhillips AlaskEl". . Operations SummarY~~~C)rt> Legal Well Name: 18-20 Common Well Name: 18-20 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 ..,..'.,.........'.....'.... Sub Date From - To: Hours Code Code Phase 7/27/2003 07:15 - 14:00 14:00 - 16:00 ..:..:...::.......:..: /....: .................... .. Sta rt: 7/1 0/2003 Rig Release: 7/27/2003 Rig Number: Påge ß oL8 .... ... .. Spud Date: 7/10/2003 End: Group: Description of Operations 6.75 CMPL TN PULD CMPL TN LD 83 stds of 4" DP from derrick, attemted to flush & freeze protect 7" x 9 5/8" annulus, was unable to flush, freeze protected with 118 bbls diesel 2.00 CMPL TN RURD CMPL TN RD test lines in cellar, closed SSSV safety valve and secured well. RELEASED RIG AT 16:00 Hrs 7/27/03 to move to 1B-102 Printed: 8/14/2003 4:13:54 PM Date 10/27/03 10/28/03 10/29/03 1 0/30/03 11/02/03 11/05/03 11/06/03 11/07/03 11/08/03 11/29/03 . 18-20 Event History . Comment CLOSED BAKER CMD SLIDING SLEEVE AT 8205' WLM / 8226' RKB. SET 2.81 XX PLUG AT 7755' RKB / 7736' WLM. SET CATCHER ON TOP OF PLUG. PULLED STA 5. 7740 RKB / 7724' WLM. 1 1/2" OV. 1/4" PORT. RK LATCH. IN PROGRESS. PULLED GLVS FROM STATIONS 1, 2, 3, & 4. REPLACED WITH DVS. IN PROGRESS. LOADED I/A W/ SEA WATER. SET 1 1/2" DGLV(RK LATCH) @ STA # 5(7740' RKB). TEST TBG TO 3500 PSI W/1550 PSI ON IA.. GOOD TEST. BLEED DOWN TBG TO 1500 PSI. TEST IA TO 3500 PSI. TBG HOLDING @ 1500. GOOD TEST. BLEED IA TO 500 PSI. LDFN. PERFORATE INTERVAL 8356'-8376' USING 2" HSD GUNS LOADED WITH 2006 UL TRAPACK HMX (BIG HOLE) CHARGES, 6 SPF, 60 DEG PHASING, RANDOM ORIENTATION. PULL CATCHER. NO DGLV IN CATCHER. HAVE 3 PCS OF RUBBER 2.5" - 4" LONG. PULL XX PLUG @ 7755' RKB. RMDO SET ISO SLEEVE ACROSS SSSV @ 1820' RKB. [SSSV WORK] PUMP BREAKDOWN STAGE AND SEEN HIGH NEAR WELLBORE FRICTION. PUMP SCOUR STAGE USING 30# X-LINKED GEL AND 1 PPA 16/20 PROPPANT AND SCREENED OUT WITH PROP ON FORMATION. PUMP 15 BBLS DOWN WELL FOR FREEZE PROTECTION. fCOOF "SCOUR STAGE SAND" FROM FRAC ATTEMPT. CLEAN OUT SAND F/8459' RKB TO T/8551, RKB. [FCO] PERFORATED 8356'-8386', 6 SPF 2006 HYPERJET, PENT= 9.6", EH= 0.33" [PERF] ATTEMPT FRACTURE TREATMENT. SEËNHfGH TREATING PRESSURES DURING INITIAL BREAKDOWN AND DECIDED TO PUMP 50 BBLS OF 15% HCL. LET ACID SOAK FOR 20 MINUTES THEN FRAC IT AWAY. DID NOT SEE MUCH DECREASE IN TREATING PRESSURE. FREEZE PROTECT WELL AND ABORT JOB. DRIFT WELL WITH 2.5" SLlCKLlNE CENTRALIZER, TAG TD AT 8539'. PERFORATE INTERVAL 8332'·8352' USING 2.5" POWER SPIRAL ENERJET "STRIP" GUNS. LOADED 5 SPF, 45 DEG 'PENDULUM' PHASING. Page 1 of 1 12/2/2003 . . ConocoPhillips Alaska, Inc. Pad IB 20 slot #20 Kuparuk River Unit North Slope, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref Our ref License MWD <0-8636'> svy6930 Date printed Date created Last revised 25-Jul-2003 13-Jul-2003 24-Jul-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 35 27.418 Slot location is n70 19 40.285,w149 35 51.339 Slot Grid coordinates are N 5969647.300, E 549618.970 Slot local coordinates are 496.96 S 819.43 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North . ConocoPhillips Alaska, Inc. Pad 1B,20 Kuparuk River Unit, North Slope, Alaska Measured Inclin Depth Degrees 0.00 138.00 283.56 375.01 467.01 556.33 647.90 737.35 829.31 918.88 1010.68 1109.04 1203.20 1295.83 1388.74 8.57 10.06 11.66 13.42 15.16 1481.78 1574.22 1666.51 1760.19 1851.71 16.45 18.30 22.53 26.87 30.40 1945.21 2037.56 2128.08 2222.42 2314.57 34.73 39.08 42.57 44.96 46.45 2407.77 2502.08 2595.19 2687.67 2778.30 47.28 49.80 51.11 51.91 51.44 2871. 53 2963.75 3057.54 3148.32 3242.65 50.49 52.01 50.87 49.63 50.77 3336.25 3428.51 3522.84 3617.40 3709.27 50.87 49.97 49.76 49.49 50.98 3802.33 3893.75 3986.29 4081. 37 4175.20 50.42 51. 48 51.56 50.99 50.56 4267.59 4359.63 4452.08 4546.07 4637.01 50.24 50.03 49.08 50.80 51.00 Azimuth Degrees 0.00 0.00 0.89 0.72 0.52 0.00 0.00 322.70 298.60 265.74 True Vert Depth 0.00 138.00 283.55 375.00 466.99 556.30 647.83 737.17 828.82 917 . 68 1008.46 1105.52 1197.99 1288.41 1378.44 1467.97 1556.19 1642.66 1727.75 1808.06 1886.85 1960.68 2029.17 2097.29 2161.65 2225.37 2287.81 2347.09 2404.65 2460.85 2519.57 2577.29 2635.75 2693.80 2754.18 2813.31 2872 .10 2932.90 2994.18 3052.94 3111.89 3169.48 3227.07 3286.55 3345.88 3404.78 3463.78 3523.75 3584.25 3641. 60 5URVEY LI5TING Your ref Last revised R E C TAN G U L A R Dogleg Vert COO R DIN ATE 5 Deg/100ft 5ect O.OON O.OON 0.90N 1.74N 1.99N 1. 36N 0.525 3.935 9.785 18.295 28.235 39.125 50.885 64.785 80.965 97.915 115.505 135.395 158.755 183.885 211. 485 240.295 270.845 304.795 339.315 376.265 414.775 454.395 494.755 533.755 573.455 612.655 651.785 688.605 727.145 765.375 802.715 839.775 872.865 901. 975 931.175 959.725 987.485 1014.395 1041.135 1069.555 1099.665 1129.055 1156.975 1181. 935 O.OOE O.OOE 0.69W 1.62W 2.54W 3.59W 5.53W 8.36W 12.92W 20. 18W 29.54W 41. 15W 54.43W 68.94W 85.18W 104.01W 125.28W 150.58W 181.98W 217.90W 259.97W 307.33W 357.99W 413.71W 469.91W 527.00W 586.26W 646.13W 706.22W 765.66W 826.23W 886.53W 948.55W 1007.84W 1069.22W 1130.88W 1191. 40W 1253.25W 1317.20W 1381. 53W 1447.36W 1512.36W 1579.27W 1648.39W 1715.98W 1781. 23W 1845.14W 1909.06W 1975.35W 2041.35W 0.00 0.00 0.61 0.41 0.43 0.88 1. 26 1. 40 2.62 3.05 2.64 5.21 9.24 15.88 26.12 . G RID Easting 0.00 0.00 0.23 0.70 1.43 549618.97 549618.97 549618.28 549617 . 34 549616.41 Page 1 MWD <0-8636'> 24-Jul-2003 COORD5 Northing 5969647.30 5969647.30 5969648.19 5969649.03 5969649.27 5969648.63 5969646.74 5969643.31 5969637.43 5969628.87 5969618.88 5969607.91 5969596.06 5969582.06 5969565.77 5969548.70 5969530.97 5969510.91 5969487.35 5969461. 97 5969434.10 5969404.98 5969374.08 5969339.77 5969304.87 5969267.54 5969228.64 5969188.62 5969147.87 5969108.46 5969068.37 5969028.76 5968989.22 5968952.00 5968913.06 5968874.42 5968836.68 5968799.21 5968765.69 5968736.15 5968706.52 5968677.53 5968649.33 5968621.95 5968594.76 5968565.90 5968535.37 5968505.55 5968477.19 5968451.79 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #20 and TVD from RKB (Doyon 141) (88.90 Ft above mean sea level). Bottom hole distance is 4947.58 on azimuth 243.80 degrees from wellhead. Vertical section is from wellhead on azimuth 244.29 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 1.12 2.27 3.43 5.82 8.54 226.87 225.59 215.75 219.18 221.39 225.17 228.26 228.63 224.14 225.97 229.89 230.89 232.57 234.03 235.91 237.46 239.81 238.06 239.21 237.68 236.51 237.44 235.59 236.63 236.82 236.70 237.23 238.29 238.02 237.74 238.66 237.98 240.17 245.12 246.17 246.00 246.56 248.38 249.08 247.74 245.18 244.37 246.25 248.06 250.50 0.61 1. 60 1. 70 2.17 1. 93 38.86 54.05 71.11 90.22 111.88 1. 80 2.03 4.63 4.68 3.98 136.19 162 . 99 194.41 232.83 276.11 4.72 4.95 4.06 2.67 2.01 325.98 381.15 440.05 504.99 570.59 1.28 2.77 2.08 1.23 0.54 638.07 708.16 779.30 850.94 921 . 42 1. 02 1. 71 1. 50 1.38 1.23 993.22 1064.55 1137.41 1206.81 1278.82 0.77 1.13 1. 79 4.00 1. 84 1350.97 1421.69 1493.50 1565.47 1636.06 0.62 1.25 1. 54 0.83 1. 20 1708.04 1778.99 1851.32 1925.27 1997.77 2.16 0.71 1. 86 2.35 2.09 2068.89 2139.53 2209.87 2281.71 2352.01 549615.38 549613.44 549610.63 549606.12 549598.91 549589.62 549578.09 549564.89 549550.47 549534.34 549515.63 549494.48 549469.32 549438.08 549402.33 549360.45 549313.29 549262.84 549207.35 549151. 40 549094.56 549035.57 548975.97 548916.16 548856.99 548796.69 548736.67 548674.91 548615.88 548554.77 548493.37 548433.11 548371. 51 548307.80 548243.67 548178.04 548113.24 548046.53 547977.60 547910.20 547845.14 547781. 44 547717.73 547651. 64 547585.81 . . ConocoPhillips Alaska, Inc. SURVEY LISTING Page 2 Pad 1B,20 Your ref MWD <0-8636'> Kuparuk River Unit,North Slope, Alaska Last revised 24-Jul-2003 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C o 0 R D S Depth Degrees Degrees Depth COO R D I N A T E S Deg/100ft Sect Easting Northing 4729.29 50.72 250.88 3699.85 1205.60S 2108.89W 0.44 2423.13 547518.43 5968427.67 4823.27 50.76 250.26 3759.33 1229.80S 2177.52W 0.51 2495.46 547449.98 5968403.01 4914.64 51.13 248.56 3816.90 1254.76S 2243.93W 1. 50 2566.13 547383.74 5968377.61 5008.97 51.18 248.41 3876.06 1281.70S 2312.28W 0.13 2639.40 547315.58 5968350.21 5100.54 51. 30 249.45 3933.39 1307.37S 2378.91W 0.90 2710.57 547249.13 5968324.09 5173.61 51. 65 248.60 3978.91 1327.83S 2432.29W 1. 03 2767.54 547195.90 5968303.28 5285.55 51.44 250.59 4048.53 1358.40S 2514.44W 1. 40 2854.81 547113.97 5968272 .16 5380.22 51.06 248.95 4107.78 1383.92S 2583.71W 1. 41 2928.30 547044.87 5968246.18 5472.49 50.68 249.60 4166.01 1409.25S 2650.65W 0.68 2999.61 546978.11 5968220.40 5565.43 50.96 246.20 4224.74 1436.35S 2717.38W 2.85 3071.49 546911.57 5968192.85 5658.67 50.68 246.83 4283.65 1465.16S 2783.67W 0.60 3143.71 546845.48 5968163.61 5751.51 50.26 246.41 4342.74 1493.57S 2849.40W 0.57 3215.26 546779.95 5968134.75 5843.99 50.08 247.57 4401.97 1521.33S 2914.77W 0.98 3286.19 546714.78 5968106.56 5936.78 48.88 247.21 4462.26 1548.45S 2979.88W 1.33 3356.63 546649.85 5968079.01 6029.49 48.51 247.69 4523.45 1575.16S 3044.20W 0.56 3426.16 546585.72 5968051.87 6122.64 48.17 247.04 4585.37 1601.94S 3108.43W 0.64 3495.65 546521.68 5968024.66 6215.22 47.90 245.99 4647.28 1629.37S 3171. 57W 0.89 3564.44 546458.73 5967996.81 6307.10 47.56 246.80 4709.08 1656.60S 3233.87W 0.75 3632.38 546396.63 5967969.16 6400.14 48.53 246.68 4771.28 1683.92S 3297.43W 1. 05 3701.51 546333.25 5967941.42 6491.98 48.32 247.55 4832.23 1710.64S 3360.73W 0.74 3770.13 546270.14 5967914.28 6586.65 47.76 246.31 4895.52 1738.22S 3425.49W 1.14 3840.45 546205.57 5967886.26 6678.83 46.71 250.41 4958.13 1763.18S 3488.36W 3.46 3907.92 546142.88 5967860.88 6771. 30 46.40 251.37 5021.72 1785.16S 3551.80W 0.82 3974.61 546079.60 5967838.47 6864.37 45.03 250.94 5086.70 1806.68S 3614.85W 1. 51 4040.76 546016.69 5967816.54 6957.97 43.54 250.51 5153.70 1828.25S 3676.54W 1. 62 4105.70 545955.16 5967794.55 7050.28 42.14 250.32 5221. 39 1849.29S 3735.68W 1.52 4168.10 545896 .17 5967773.12 7143.14 40.25 250.20 5291.26 1869.94S 3793.24W 2.04 4228.93 545838.75 5967752.08 7236.84 38.52 249.50 5363.68 1890.42S 3849.06W 1. 91 4288.10 545783.08 5967731.24 7329.13 36.83 248.35 5436.72 1910.69S 3901. 69W 1. 98 4344.32 545730.59 5967710.61 7421.84 34.93 246.67 5511. 84 1931.45S 3951.89W 2.31 4398.56 545680.53 5967689.51 7514.28 32.53 "248.70 5588.72 1950.97S 3999.36W 2.87 4449.79 545633.20 5967669.68 7606.43 30.05 248.78 5667.46 1968.32S 4043.96W 2.69 4497.50 545588.73 5967652.03 7699.96 28.43 248.71 5749.07 1984.88S 4086.54W 1. 73 4543.05 545546.27 5967635.19 7792.55 26.13 248.33 5831.35 2000.42S 4126.03W 2.49 4585.37 545506.89 5967619.39 7885.68 25.36 247.57 5915.24 2015.60S 4163.52W 0.90 4625.74 545469.50 5967603.96 7947.76 24.57 246.74 5971. 52 2025.77S 4187.67W 1.39 4651. 90 545445.42 5967593.63 8015.00 25.29 246.11 6032.49 2037.11S 4213.64W 1.14 4680.23 545419.53 5967582.11 8037.88 25.53 245.90 6053.16 2041.10S 4222.61W 1.12 4690.04 545410.58 5967578.06 8131.15 27.59 236.34 6136.62 2061.29S 4258.96W 5.08 4731.55 545374.38 5967557.63 8224.29 25.76 236.72 6219.84 2084.35S 4293.83W 1. 97 4772.97 545339.66 5967534.34 8318.28 24.68 237.37 6304.87 2106.14S 4327.43W 1.19 4812.70 545306.21 5967512.32 8412.19 24.23 238.36 6390.36 2126.82S 4360.35W 0.65 4851. 33 545273.44 5967491.42 8545.81 26.61 232.27 6511 .05 2159.53S 4407.38W 2.64 4907.89 545226.64 5967458.41 8636.00 26.61 232.27 6591. 69 2184.25S 4439.33W 0.00 4947.40 545194.86 5967433.47 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #20 and TVD from RKB (Doyon 141) (88.90 Ft above mean sea level). Bottom hole distance is 4947.58 on azimuth 243.80 degrees from wellhead. Vertical section is from wellhead on azimuth 244.29 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ . ConocoPhillips Alaska, Inc. Pad IB,20 Kuparuk River Unit, North Slope, Alaska Top MD Top TVD Rectangular Coords. . SURVEY LISTING Page 3 Your ref MWD <0-8636'> Last revised : 24-Jul-2003 Casing positions in string 'A' --------------------~--------- ------------------------------ Bot MD Bot TVD Rectangular Coords. ----------------------------------------------------------------------------------------------------------- Casing 0.00 0.00 0.00 0.00 0.00 0.00 Target name O.OON O.OON O.OON O.OOE O.OOE O.OOE 5222.00 8005.00 8636.00 4008.96 6023.45 6591.69 1341. 41S 2035.38S 2184.25S Targets associated with this wellpath ------------------------------------- ------------------------------------- Geographic Location T.V.D. 2467.70W 4209.74W 4439.33W 2094.30S 1897.39S Rectangular Coordinates 4351. 57W 4185.23W 9 5/8 CSG 7" CSG 5 1/2 Liner Revised IB-SW A4 TGT 14 May IB-SW C4 TGT 14 May ----------------------------------------------------------------------------------------------------------- 3-Mar-2003 3-Mar-2003 545282.000,5967524.000,0.0000 545447.000,5967722.000,0.0000 6326.90 6149.90 g conOCOPhilliPs,~~ka, API: 500292316400 SSSV Type: TRDP Annular Fluid: Depth TVD Type Description ID 23 23 HANGER 3.5" FMC GEN 5 TUBING HANGER 3.500 1820 1780 SSSV CAMCO TRM-4E 2.812 7755 5798 NIP OTIS X NIPPLE WITH X-PROFILE 2.813 7765 5807 PBR BAKER 3.5" 80-40 PBR 2.990 7784 5824 PACKER BAKER PREMIER PERMANENT PACKER 2.875 Blast Rings 8138 6143 Blast Rings HYDRIL 3.5" BLAST RINGS, 60' OF BLAST RINGS START @ 8138' ON 90' 3.500 (8138-8198, TUBING JOINT OD:4.ooo) 8226 6221 SLEEVE-C BAKER CMD SLIDING SLEEVE W/OTlS 2.813" X NIPPLE PROFILE- 2.813 CLOSED 10/27/2003 8242 6236 PACKER BAKER SABL·3 PACKER 2.780 8247 6240 BUSHING XO BUSHING 3.500 8254 6247 NIP OTIS 'XN' NIPPLE W/2.63" NO GO ID W/RHC VALVE 2.630 8261 6253 WLEG BAKER WIRELlNE GUIDE 3.000 Date Note 7/26/2003 FMC I GEN 5 I 5M CAP CONNECTION: TOP 5.75" ACME W/3.5" EUE 8RD THREAD Perf (8356-8376) ~ . KRU 18-20 Well Type: PROD Orig Completion: 7/27/2003 Last W/O: Angle @ TS: 27 deg @ 8141 Angle @ TD: 27 deg @ 8636 Rev Reason: GLV DESIGN, TAG, PERF Last Update: 10/31/2003 Reference Log: 28' RKB Last Tag: 8534 Last Tag Date: 10/30/2003 Casing String· ALL STRINGS Description PRODUCTION SURFACE CONDUCTOR LINER Tubing String· TUBING Size Top 3.500 23 Ref Log Date: TD: 8636 ftKB Max Hole Angle: 52 deg @ 2964 Size Top Bottom TVD Wt Grade Thread 7.000 27 8005 6023 26.00 L-80 BTCM 9.625 28 5222 4009 40.00 L-80 BTCM 16.000 28 138 138 62.50 H-40 WELD 5.500 7841 8636 8636 15.50 L-80 Hydril 511 TVD 6253 Interval TVD Zone Status Ft SPF Date Type Comment 8143 - 8193 6147 - 6192 -4,C-3,C-2,C 50 4 7/26/2003 IPERF 3 3/8" Guns w/60 deg 1/2 phasing, 215 holes 8356 - 8376 6339 - 6357 A-4 20 6 10/30/2003 APERF 2. HSD, 60 deg ph, 2006 Ultrapack Charges Gas Lift MandrelslValves St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2838 2498 CAMCO MMG DMY 1.5 RK 0.000 0 10/28/2003 2 4862 3784 CAMCO MMG DMY 1.5 RK 0.000 0 10/28/2003 3 6355 4741 CAMCO MMG DMY 1.5 RK 0.000 0 10/28/2003 4 7281 5399 CAMCO MMG DMY 1.5 RK 0.000 0 10/28/2003 5 7740 5785 CAMCO MMG DMY 1.5 RK 0.000 0 10/29/2003 Production MandrelslValves St MD TVD Man Man Type V Mfr Vlv Mfr Cmnt 6115 CAMCO KBG-2-9 +-- ... Scblulnbepgep NO. 3024 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth 10/31/03 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL Color 1Y-19 \ ~~-IOT- PROOUCTlON PROFILE/DEFT 10/09/03 1 3A-04 , > ðn-:c INJECTION PROFILE 10/11/03 1 3B-03 \ c- ~RODUCTlON PROFILE/DEFT 10/13/03 1 3B-08 .~- RODUCTION PROFILE 10/14/03 1 3A-05 I' - PRODUCTION PROFilE 10/15/03 1 3B-06 \ t::?-n~ PRODUCTION PROFILE 10/16/03 1 2T-21 \ 1'5 -Q¡ <>,LEAK DETECTION LOG 10/17/03 1 3B-04 . ?F?-ci 0 ( PRODUCTION PROFILE/DEFT 10/18/03 1 1 E-20 %4 ~ SBHP SURVEY 10/20/03 1 31-11 -O~ LEAK DETECTION LOG 10/25/03 1 3G-09 "~O-CYo PRODUCTION PROFilE 1 0/25/03 1 3G-11 I 0-0 PRODUCTION PROFILE 10/27/03 1 1 B-20 ~~~ PERF RECORD/STATIC SURVEY 10/30/03 1 SIGNE~\~ ~I.O ~~Jl'~ DATE: Please sign and return one copy of this transmittal tó Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk e CD e ,,'-1\ \ :.::i \,:~ ::::: --""" ,....,.. ·'-"......A j ,¡ 4.....L )10\1 ^ '1 ,~ 'I 1;1 . '.. -- ",- 81 Gss CGns~ GC~f";;i.s:;,~;; /~, Annular Disposal during the third quarter of2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-41 19560 100 0 19660 377 4000 24037 June 2003 July 2003 CD2-20, CD2-55 3S-17A 2133 100 0 2233 361 4659 7253 June 2003 July 2003 3S-19 Hansen 1 2498 100 0 2598 0 115278 117876 January July 2003 Hansen 1, Hansen 1 A 2002 :l03- CD2-38 29522 100 0 29622 389 0 30011 July 2003 Sept 2003 CD2-40, CD2-30, CD2-55 \\5 JB.2t 36655 100 0 36755 0 0 36755 July 2003 Sept 2003 IB-102, IB-101 . CD2-23 22140 100 0 22240 377 0 22617 Sept 2003 Sept 2003 CD2-18, CD2-55 Total Volumes into Annulifor which Disposal Authorization Expired during the third quarter 2003: Freeze Protect Total Volume Fluids Injected Volume 371 380 Start Date Well Name CD2-46 CD2-22 Total h(l) Volume 31393 30773 31864 31253 Total h(2) Volume 100 100 Total h(3) Volume o o Status of Annulus Open, Freeze Protected Open, Freeze Protected April 2003 February 2003 December 2002 CD2-48 Open, Freeze Protected 31525 100 o 375 32000 End Date May 2003 March 2003 February 2003 Source Wells CD2-51, CD2-l2 CD2-08, CD2-36, CD2- 51 CD2-45, CD2-35, CD2- 08, CD2-28 . RECEIVE OCT 2 3 2003 Alaska Oil & Gas Cons. Gommissicn e . ,;203·- liS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage AK 99501 Re: THE APPLICATION OF ConocoPhillips Alaska, Inc, for an order granting an exception to spacing requirements of Rule 3, Conservation Order 432B to provide for the drilling and regular production of the Kuparuk River Unit 1B-20 oil development well. IT APPEARING THAT: Conservation Order No. 497 Kuparuk River Field Kuparuk River Unit Kuparuk River Oil Pool Kuparuk River Unit Well 1B-20 September 10, 2003 1. ConocoPhillips Alaska, Inc. ("ConocoPhillips"), by letter dated June 25, 2003 and received by the Alaska Oil and Gas Conservation Commission ("Commission") on June 30, 2003, requests exception to the well spacing provisions of Rule 3, Conservation Order 432B to allow drilling and regular production of the Kuparuk River Unit ("KRU") 1B-20 oil development well to a location which is within the same governmental quarter section as an existing oil production well. 2. Notice of opportunity for public hearing was published in the Anchorage Daily News on July 7, 2003 pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: 1. The KRU 1B-20 oil development well will be drilled as a deviated hole with a surface location 497 feet from the north line ("FNL") and 820 feet from the east line ("FEL") of Section 9, T11N, R10E, Umiat Meridian ("UM") to a bottomhole location 2639 feet FNL and 12 feet from the FEL of Section 8, T11N, R10E, UM. 2. The location of the KRU 1B-20 well was selected as the most favorable structural position to recover fault-isolated oil reserves in Conservation orde~o. Page 2 of 3 September 10, 2003 497 e the Kuparuk River Formation that are not recoverable with the current well pattern. 3. The KRU IB-20 well bore will open the Kuparuk River Oil Pool to production in the NW 1/4 of Section 9 and the NE 1/4 of Section 8, TIIN, RI0E, UM. 4. The anticipated productive portion of the KRU IB-20 well bore that lies in Section 9, TIIN, RI0E, UM is within the same governmental quarter section as the KRU IB-13 oil production well. Drilling of, and production from, this portion of the KRU IB-20 well bore requires an exception to the spacing provisions of Rule 3, Conservation Order 432B. 5. The anticipated productive portion of the KRU IB-20 well bore that lies in Section 8, TIIN, RI0E, UM does not require an exception because, per Rule 3 of Conservation Order 432B, an unrestricted number of wells may be drilled in that section. 6. Offset landowners, owners and operators within 3,000 feet of the anticipated productive interval of the KRU IB-20 well have been notified. 7. No protests to the spacing exception application were received. CONCLUSIONS: 1. An exception to the well spacing provisions of Rule 3, Conservation Order 432B is necessary to allow the drilling and production of the KRU IB-20 oil development well. 2. Granting the requested spacing exception for the KRU IB-20 well will promote more efficient recovery of oil reserves and will not result in waste or jeopardize the correlative rights of adjoining or nearby owners. NOW, THEREFORE, IT IS ORDERED: 1. ConocoPhillips' application for exception to the well spacing provision of Rule 3, Conservation Order 432B to allow the drilling and production of the KRU IB-20 oil development well is approved. Conservation Page 3 of 3 September 10, 2003 order'o. 497 e DONE at Ançh()r~g~2_Alaska and dated September 10, 2003. . . '.,..... Daniel T. Seamou t, Jr., Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may fùe with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely fùed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 3D-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was fùed). e NOTE TO FILE e 18-20...203-115...303-257 Request to Increase Annular Disposal Volume Summary ConocoPhillips (CPA) was granted approval for annular disposal (AD) on the subject well on July 20, 2003 (303-204). Since this is the 15t well to be drilled on 1 B pad since 1994 and has the only approved disposal annulus, CPA has requested to increase the allowable disposal volume to 50,000 bbis. This document analyzes CPA's request and recommends approving it. Well 1 8-20 Information An analysis according to the requirements of 25.080 was conducted in mid July and approval was given to conduct AD operations in KRU 18-20 (203-115 and 303-204). In support of this request to increase the allowable volume, CPA has submitted graphical summaries of the measured pressures experienced while conducting the approved operations and the cumulative disposed volume versus time. This additional information complies with 20 AAC 25.080 (b)(15) and (16). When the original "pump in" test was conducted, CPA experienced problems initiating injection. When injection was established, the surface pressure was between 1300 and 1400 psi at Y2 bpm. The measured injection pressure while conducting disposal operations is variable and ranges from a low of 840 psi to a high value of 1390 psi. The pressure presentation appears to have "groupings" that would indicate that different "areas" in the earth are accepting the waste. Similar performance has been seen in Class II disposal wells (RU 01) and demonstrates the "disposal domain" concept where a portion of the disposal interval accepts the pumped wastes until it essentially plugs and then another portion of the interval begins accepting the waste. The recorded pressure information indicates that the disposed waste is being contained. CPA further states in their application that the continued ability to use 1 B-20 will only be necessary to allow completion of 1 B-1 01, which is the 3rd of the 3 planned wells to be drilled on the pad. The only alternate available to CPA is to truck the waste approximately 7 miles to the 1 R-18 Class II disposal well. While trucking the waste is possible, there are environmental risks associated with that activity with no commensurate benefit. CPA's drilling operations incorporate waste handling and AD as a normal part of the process. The increased waste volume should be satisfactorily contained given the well performance information provided and continued similar operating practices. Recommendation Based on the presented information, I recommend that ConocoPhillips' request to increase the allowable annular disposal volume in KRU 1 B-20 (203-115) be increased to 50,000 bbls. ~'h?~ Tom Maunder, PE ( Sr. Petroleum Engineer ~. M:\tornmaunder\Well Information\By Subject\Annular Disposal\030902 _Increase AD--KRU _lB-20.doc 'Y e . ConocòPhi I lips Post Office Box 100360 Anchorage, Alaska 99510-0360 Steve McKeever Phone (907) 265-6826 Email: Steve.McKeever@conocophillips.com August 29, 2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Sundry Application for Waiver of Volume Requirement for Annular Disposal, WelllB-20 Dear Commissioners: With the attached Application for Sundry Approvals, ConocoPhillips Alaska, Inc. hereby applies for a waiver to the volume limitation of the regulations for annular disposal for disposal into the annulus of well 18-20. ConocoPhillips has a valid, current Sundry Permit for annular disposal in this well (Sundry # 303- 204, issued July 30, 2003) and has thus far disposed of +/- 33,000 barrels in this well. We would like authority to continue to dispose of additional fluids (up to 50,000 barrels) to avoid the expense and additional environmental risk of hauling and disposing of fluids at the 1 R-18 Class II disposal well. The additional 15,000 barrels of requested volume will likely enable us to complete drilling operations on 1B-101. For data on the integrity of 18-20 for annular disposal, please refer to the original Application for Sundry Approvals, submitted on July 22, 2003. Attached to this application please find two graphs for the annular disposal to date in Well 1 8-20. One graph is of total fluid disposed in 18-20 over time, and the other graph is disposal pressures over time. Thank you for your consideration of this request. If you have any questions or require any further information, please contact me at 265-6826. :ø~ Steve McKeever Senior Drilling Engineer OR1G1NAI- e e ... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown D D D 1. Type of Request: Perforate D D D Repair well D D D Alter casing D D Abandon Suspend Plug Perforations Stimulate Change approved program Pull Tubing Perforate New Pool 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99515 7. KB Elevation (ft): 28' RKB 8. Property Designation: ADL 25647 & 25648 I ALK 466 & 465 4. Current Well Class: Development 0 Stratigraphic D Exploratory D Service D ~~I % ~... ~ Variance D Annular Dispos.D Time Extension D Other 0 Re-enter Suspended We Increase annular disoosFJllimit 5. Permit to Drill Number: 203-115 6. API Number: 50-029-23164-00 9. Well Name and Number: 18-20 10. Field/Pools(s): Kuparuk River Field 1 Kuparuk River Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) Junk (measured): 6554' MD TVD Burst Collapse Perforation Depth TVD (ft): NIA Packers and SSSV MD (ft): SSSVat 1820', packer at 8242' and 7784' 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 GasD WAG D GINJ D 11. Total Depth MD (ft): 8636' Casing Structural Conductor Surface Total Depth TVD (ft): Effective Depth MD (It): 6592' 8594' Length Size 138' 5194' 7978' 16" 138' 5221.7' 8005.7' 138' 4015' 6033' 9.625" Intermediate Production 7" Liner Perforation Depth MD (ft): NIA Packers and SSSV Type: Tubing Size: 3.5" Baker Premier perm. packer, Baker SABL-3 prk, Cameo TRM-4E SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 8/29/2003 Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ;/ J~mas ~/ Title Signature ÆI1:!þLÞ1 R:1!ohC ç Phone Contact Kuparuk Drilling Team Leader 265-6830 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D Mechanical Integrity Test D Location Clearance D BOP Test D Other: Subsequent Form Required: ~ ~..\ Oç- 0... ~0 \0 S;:;J\ c:; \"ð ~~\ Approved by: ~lA-. ~ BY ORDER OF THE COMMISSION L e.Â- -i9MMISSIONER URiGINAL Form 10-403 Revised 2/2003 A ,V\/~ Tubing Grade: L-80 Tubing MD (ft): 8261' Service D Plugged D WINJD Abandoned D WDSPL D Steve McKeever at 265-6826 Date ?/C;ft3 Sundry Number: 303-').57 Date: ~~ SUBMIT IN DUPLICATE by Steve ----------------1 prepared by Steve McKeever 8/29/2003 . Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: IB-20 .' .. .. ....... .,....-......... .. Contains the tj)lIowing: . cÝ'-. I I ' ,r' , .J.Jv I LDWG Compact Disc \ ]" (Includes Graphic Image files) I LDWG lister summary I blueline - MPR \1casured Depth I.og 1 blueline - MPR TVD Log 1 blueline - CCN-ORD Measured Depth Log 1 blueline - CCN-ORD TVD Log LAC Job#: 512497 . 8-C!,-~-IÞ "ill BAKER HUGHES Anchorage GEOScience Center .. ,..,n,. ...... . . Sent By: Glen Borel Date: Aug 22, 2003 ~'" ,~ Received BY:~ Ô ~~/V'l~ "C ~/v'-- Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 'K~~",\~ t:~E.CE'VED AUG 26 2003 . "\"" ,,", C', ,.'- "nmì-'nn Aiaska vi', Ct; ud$ \"011&. '....0. ¡~. Anchorage i':ì IIPkTM-1!1O-lOOIIWTgcw . .-..... . :;,¡;,-,,::;o:;:,::-~;.;.,-;;:; _'OF _ .. ,.." .....:, " ~. ~ ... . .. - .. -"" - .., ,.~ """: ~." , "" --.'-----.'-------".--.-----.--. --~ - ... ,~'~..',.".. ...·-.n....... -.- ~._._-,_.~-~~ a: _ j-.... ~e ConocoPhillips e Post Office Box 100360 Anchorage, Alaska 99510-0360 Steve Shultz Phone (907) 263-4620 Fax: (907) 265-1535 Email: steven.m.Shultz@conocophillips.com July 22, 2003 Alaska Oil and Gas Conservation Commission 222 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on WelllB-20 Dear Sir: ConocoPhillips Alaska, Inc. hereby requests that IB-20 be permitted for annular pumping of fluids occurring as a result of drilling operation, per regulation 20 ACC 25.080. It is intended to begin annular disposal operation on IB-102 as soon as possible. Please see the attached form 10-403 and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report and Daily Drilling Reports during cement ops 5. Casing and Formation Integrity Report (LOT at surface casing shoe) 6. Production Casing Description 7. Production Casing Cementing Report and Daily Drilling Report during cement ops 8. Plan View of Existing Adjacent Wells 9. Plan View of Existing and Planned Adjacent Wells 10. Pressure Integrity Test If you have any questions or require further information, please contact Steve Shultz at 263- 4620 in the Conoco/Phillips office. :¥...J£t- Steve S~:: . ~~ Drilling Consultant ~~ JUL OR\G\N~L STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown D D D - 1. Type of Request: D Repair well D D D Alter casing D D Abandon Suspend Change approved program Pull Tubing 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99515 7. KB Elevation (ft): 28' RKB 8. Property Designation: ADL 25647 & 25648 I ALK 466 & 465 11. Total Depth MD (ft): 8465' Casing Structural Total Depth TVD (ft): Effective Depth MD (It): 6438' Length Size Conductor 138' 5221' 8006' 16" Surface 9.625" Intermediate Production 7" Liner Perforation Depth MD (ft): N/A Packers and SSSV Type: NIA 12. Attachments: Description Summary of Proposal [2] Detailed Operations Program [2] BOP Sketch D e %.Á¡ ~ ~Jì. ¿7 r 7/?:i1 -G. ï-(ò 3 0 Variance D Annular DiSPos.[2] Time Extension D Other D Re-enter Suspended Well D 5. Permit to Drill Number: Plug Perforations Perforate D D Stimulate Perforate New Pool 4. Current Well Class: Development [2] Stratigraphic D Exploratory D Service D 203-115 6. API Number: 50-029-23164-00 9. Well Name and Number: 1 B-20 10. Field/Pools(s): Kuparuk River Field 1 Kuparuk River Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) Junk (measured): MD TVD Burst Collapse 138' 138' 5221.7' 4015' 8005.7' 6033' Perforation Depth TVD (ft): N/A Packers and SSSV MD (ft): 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 7/25/2003 Date: Tubing Size: N/A Tubing Grade: N/A Tubing MD (ft): N/A NIA 13. Well Class after proposed work: Exploratory D Development [2] 15. Well Status after proposed work: Oil [2] Gas D WAG D GINJ D Service D Plugged D WINJ D Abandoned D WDSPL D Contact Steve Shultz @ 263-4620 Printed Name R. Thomas Title Kuparuk Drilling Team Leader Signature .~_ ~ Phone 265-6830 . - -t COMMISSION USE ONLY Date 7 lu.fo 'S Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D S"M~3;~." Other: f1L\>'ð\\-ð\- 6."''''-~ \.~~\~~~.A Subsequent Form Required: .... 8Ft Original Signed By o~*i1II8By Sarah Palin Approved by: Form 1 0-403 Revised 2/2003 JUL 2 :t JU~ 3 1 lOn,? COMMISSIONER BY ORDER OF THE COMMISSION Data 7 ~I!'ß ORIGiNAL SUBMIT IN DUPLICATE e e Table of Contents Annular Disposal Transmittal Form-Well IB-20.......................................2 Calculation Sheet for ADTF. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3 Horizontal Plane Clearance Report............. ....................................... ....4 Mud Summary Report for IB-20....................................................... ...8 Casing Report for 95/8" Casing on IB-20. .., ....................................... ....9 Cementing Report for 95/8" Casing on IB-20..................................... .....11 Formation Integrity Test on 95/8" Casing for IB-20............................... ...14 Casing Report for 7" Casing on IB-20................................................. ..15 Cementing Report for 7" Casing on IB-20.... ........................................ ..17 Formation Integrity Test on 9 5/8" Casing for IB-20............................... ...20 Morning Reports for 1 B-20. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .21 Well Schematics for WS-lO, IB-13, IB-I........................................... ....22 -/- e e Annular Disposal Transmittal Form- WelllB-20 A. B. Designation of well to receive drilling wastes: The depth to the base of freshwater aquifers and permafrost, if present. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. A list of all publicly recorded wells within one- quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. c. D. E. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry. F. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operations and calculations showing how this value was determined. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation: Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: Any addition data required by the Commission to confirm containment of drilling wastes: G. H. I. IB-20 No Aquifers/Base of Permafrost=±1686' MD/1651 'TVD From the 9 5/8" shoe to the Cement top all that is open is interbedded claystone, siltstone and shale with occasional minor non- hydrocarbon bearing sands. See attached horizontal plane clearance report and plot indicating that there are no wells within a quarter of a rile in the same horizontal plane as the 9 5/8" surface casing shoe on IB-20. IB-l and IB-13 both have been drilled with surface casing set outside of the quarter mile reference and production casing is within the limit but below the horizontal datum of the shoe of IB-20. One water well (WS-I0) is within the quarter mile reference but production casing was set on this well at 3465' TVD well above the 4008' TVD of IB-20. Types of waste can be drilling mud, drilling cuttings, cement -contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, domestic waste water, and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 35,000 bbls. Maximum anticipated differential pressure at casing shoe during disposal operation is 2473 psi. See attached calculation page. See Attached: cementing reports, LOT/FIT reports and casing reports. See attached casing summary sheet and calculation pages. .0Jt- ~ 5,221' MD 4,010' TVD TOC Est. @ 7,025' MD 5,198' TVD Well: IB-20 Date: 7/21/03 ~ 95/8" Surface Csg ------------------------- 8005' MD 6,024' TVD ~~ 3 V2" 7" Tbg Production Csg e e Assumptions Maximum surface injection pressure of 1500 psi Maximum density of the injection fluid is 13.0 ppg Pressure Gradient at the 9 5/8" casing shoe is .433 psilft Gas Lift Pressure = 0.11 psilft+ 1350 psi header pressure Maximum Differential Pressure at Surface Shoe Max Disposal MW 13.0 ppg Max. Pressure @ 9 5/8" Shoe 2473 psi (Max Differential Pressure=Max Disposal Press + (Max Disposal MW)(.052)(TVD)-(Fluid Wt. On Backside)(.052)(TVD» (LOT performed on surface casing shoe to 16.0 PPG MWE or 3336 psi) Production Casing Size Wt. Grade Collapse @ 100% Collapse @ 91.7% Gas Depth (TVD of bottom GLM) Gas Gradient Max Disposal Pressure with 13.0 ppg Gas Lift header Pressure Maximum Mud Weight 7.000 In. 26.00 lbs. L-80 5410 psi 4598 psi 5400 ft. 0.11 ppg 1500 psi 1350 psi 17.96 ppg MMW= Pc@85%+(Gas Gradient)(Gas TVD)-Max.Disposal Pressure (TVD) (.052) Surface Casing Size Wt. Grade Burst @ 100% Burst @ 85% Fluid Weight on Backside Max Disposal Pressure Maximum Mud Weight 9.625 In. 40.00 lbs. L-80 5750 psi 4887 psi 8.33 ppg 1500 psi 24.58 ppg MMW= Pb@ 85% +(Fluid Wei~ht on Backside)(.052)(TVD)-Max Disposal Press (.052)(TVD) -3-- e e ConocoPhillips Alaska, Inc. Pad IB 20 slot #20 Kuparuk River Unit North Slope, Alaska H 0 R I Z 0 N TAL P LAN E C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref Our ref License MWD <O-???'> svy6930 Date printed Date created Last revised 21-Jul-2003 13-Jul-2003 21-Jul-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 35 27.418 Slot location is n70 19 40.285,w149 35 51.339 Slot Grid coordinates are N 5969647.300, E 549618.970 Slot local coordinates are 496.96 S 819.43 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 2000 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* -I- e e ConocoPhillips Alaska, Inc. Pad IB,20 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 3 Your ref MWD <O-???'> Last revised : 21-Jul-2003 Reference wellpath Object wellpath GMS <0-8585' >" 1., Pad 1B M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Minim Dist 5221.7 4008.8 1341. 3S 2467.5W 4918.7 4008.8 2022.3S 1588.4W 127.8 111.2.0 1111.5 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #20 and TVD from RKB (Doyon 141) (88.90 Ft above mean sea level). Vertical section is from wellhead on azimuth 244.29 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ -5'"- e e ConocoPhillips Alaska, Inc. Pad IB,20 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 2 Your ref MWD <O-???'> Last revised : 21-Jul-2003 Reference wellpath Object wellpath MWD <0-7900'>,,13,Pad lE M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Bearing Horiz Dist Min'm Dist 5221.7 4008.8 1341. 3S 2467.5W 4482.3 4008.8 343.7S 1327.4W 48.8 1514.9 1320.7 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #20 and TVD from RKB (Doyon 141) (88.90 Ft above mean sea level). Vertical section is from wellhead on azimuth 244.29 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ - G,.- Conoe Structure Field: 3500 3400 3.3OQ 3200 ~JI» 3Ø(X1 :t¡¡OO ~ , , , , , , , , , , , , , 1320 ft ~() Pad 18 River Unit s Alaska, Inc. Well 20 ~J ConccoPhmips <- Wes! (teet) 2100 21'\00 250D uoo ž3úO ~ Scale 1 1nch = 100 ft 1300 1~ 1100 H}OO "" -"" _,00 U! g 5' ! -1Mm J V ~J$(I(! ~11QU -1(11,I(1 -"', ~2.4a\1 -"" -,." -,'" -- Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Däy TriAD Hole Sz. (ft) (in) .. 1:1) \ 1 2 3 4 6 7 8 9 10 11 1,259.0 4,137.0 5,230.0 5,850.0 7,487.0 8,015.0 8,015.0 8,015.0 8,105.0 1 8-20 1 8-20 ROT - DRILLING n1334@ppco.com Doyon 141 Mud Type' Spud Mud Spud Mud 12.250 Spud Mud 12.250 Spud Mud 8.500 Non-Disp. LS 8.500 LSND 8.500 LSND 8.500 LSND 8.500 LSND 7.000 LSND ConocoPhillipsAlaska .. . . . Mud Summary Report ___R__._.... Start: 7/10/2003 Rig Release: Rig Number: PV . yp GE¡ls10S/10rn/30m API WL-ITHP WL HTHP T pH (cp) (1b/1001t2) (lb/10Oft2) (ccI30min) ;cc/30mln:(cp) MW Vise. , (ppg) ( s/qt) 8.70 192 8.90 190 9.30 111 9.55 96 9.50 55 9.70 62 10.20 66 10.10 42 10.00 53 12.20 54 23 24 30 33 15 19 22 12 14 20 36 17/42/0 49 34/58/66 31 12/24/31 36 14/34/51 22 12/24/31 29 16/35/53 29 16/26/39 14 6/11/15 18 8/24/38 27 12/22/30 13.6 11.2 7.2 5.6 4.6 3.6 3.6 3.8 3.4 3.6 10 10.0 24 9.0 8 9.0 8 9.0 7 10.0 9.0 9.0 9.0 8.0 10.0 CI- () Sand (%) Page 1 of 1 Spud Date: 7/1012003 End: TS LGS () :,(%) 3.00 3.50 6.50 8.00 7.00 8.00 10.00 9.00 9.00 10.00 '-···'--"---1 MBT Oil TotHard. Tot Vol. (Iblbbl) (%) () (bbl) 22.5--0._ 25.0 0.0 22.5 0.0 25.0 0.0 17.5 0.0 22.5 3 0.0 22.5 3 0.0 17.5 2 0.0 17.5 1 0.0 20.0 2 0.0 e Printed: 7/21/2003 1 :48:36 PM Legal Well Name: 18-20 Common Well Name: 18-20 Event Name: ROT - DRILLING String Type: Surface Casing Hole TVD: 4,015.0 (ft) Ground Level: 61.00 (ft) Circ Hours: 2.50 (hr) Manufacturer: FMC Hanger Model: Actual TMD Set: 5,221.70 (ft) I ~ Item Size I (in.) Casing Hanger 9.625 Casing 9.625 Float Collar 9.625 Casing 9.625 Float Shoe 9.625 Accessory Bowspring Centralizer Rigid straight blade Permanent Datum: KB-Datum: CF Elevation: Mud Lost: Weight Grade (Iblft) Drift (in) Threads . ... ConocoPhillips Alaska " ' C'asing Report Report #: Start: 1 7/10/2003 Page 1 of 2 Spud Date: 7/10/2003 Report Date: 7/14/2003 End: Generallnfärmation _....~_...._..~--~-~-_.._-_.._---_.... -.-.....-.--...---..-......- Kelly Bushing 89.00 (ft) (ft) (bbl) Hole Size: Water TMD: Liner Overlap: KB to Cutoff: 12.250 (in) (ft) (ft) 28.30 (ft) Hole TMD: Str Wt on Slips: Max Hole Angle: Days From Spud: 5,230.0 (ft) 177,514 (Ibs) 52.01 n 4.00 (days) e 40.00 L-80 40.00 L-80 40.00 L-80 40.00 L-80 8.679 BTC 8.679 BTC 8.679 BTC 8.679 BTC . . Casing Flange I Wellhead Model: Gen V Packoff Model: JTS Integral Casing Detail Length , (ft) 121 2.54 5,108.21 1.55 79.37 1.73 ....... Top .. '(ft) MU Torq: THD Manufacturer (ft-Ibf) Top Hub/Flange: (in) 15,000 (psi) BTM Hub/Flange: (in) 15,000 (psi) .-----".." .". - ----- Model Condo Max OD Min IDComp. Name (in) (in>, Manufacturer WEATHERFORD WEATHERFORD 2 28.30 30.84 5,139.05 5,140.60 5,219.97 5,221.70 Non-Integral Casing Accessories Number Spacing (ft) 3 11 Remarks \JEW Casing Hanger 9518" 40# L-80 Float Collar 95/8" 40# L-80 .. Float Shoe . NEW Interval How Fixed Top (ft) 5,134.0 4,686.0 Bottom (ft) 5,216.0 Clamped 5,134.0 Slid On Held PJSM with crew, Ran Float shoe, 2 jts, Float collar, Placed bowspring centralizers 3' above shoe & float collar and on middle jt., Checked float equip.- OK, Placed Rigid straight blade Printed: 7/21/2003 1 :42:46 PM Con()coPhillips Alaska Casing Report Page 2 of 2 Legal Well Name: 18-20 Common Well Name: 18-20 Event Name: ROT - DRILLING Report #: Start: 1 7/10/2003 Spud Date: 7/10/2003 Report Date: 7/14/2003 End: _.~.__.._-_._. Remarks centralizers on every joint for the next 11 joints, Ran to 2955' with no problems and circulated btm's up, Finish running a total of 123 joints to 5221.70', had to work thru tight spot @ 5139', casing had good displacement going in hole, No mud lost while running casing. e I ~ " e Printed: 7/21/2003 1 :42:46 PM - ConocoPhillips Alaska Cel11:énting Report Legal Well Name: 18-20 Common Well Name: 18-20 Event Name: ROT - DRILLING Primary Hole Size: 12.250 (in) TMD Set: 5,222 (ft) Date Set: 7/14/2003 Csg Type: Surface Casing Csg Size: 9.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger Rot Time Start: Rec Time Start: Time End: Time End: Type: Cement Casing Volume Excess %: Meas. From: 191.0 Time Circ Prior To Cementing: Mud Circ Rate: 194 (gpm) Mud Circ Press: 800 (psi) Report #: Start: 1 7/10/2003 .. . . ,. . . Cement Job Type: Primary Squeeze Open Hole',·' Hole Size: sa TMD: (ft) SQ Date: sa Type: Cmtd. Csg: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: SQ TMD: SQ Date: Cmtd. Csg: Page 1 of 3 Spud Date: 7/10/2003 Report Date: 7/14/2003 End: Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement Pipe Movement: Reciprocating Cementer: Dennis Davis RPM: SPM: Init Torque: Stroke Length: (ft-Ibf) (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) ~tage No: 1 of 1 Start Mix Cmt: 17:00 Start Slurry Displ: 17:15 Start Displ: 20:19 End Pumping: 21 :45 End Pump Date: 7/14/2003 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 4.70 (bbl/min) 4.70 (bbl/min) Y 800 (psi) 1 ,300 (psi) 5 (min) Y Max Torque: (ft-Ibf) Drag Down: (Ibs) Returns: Full Total Mud Lost: Cmt Vol to Surf: (bbl) 191.00 (bbl) Mud Data Ann Flow After: N Mixing Method: Density Meas By: Densometer Type: Spud Mud Density: 9.4 (ppg) Vise: 44 (s/qt) Bottom Hole Circulating Temperature:86 (OF) Displacement Fluid Type:Mud PVNP: 16 (cp)/15 (lb/100ft2) Gels 10 see: 4 (lb/100ft2) Gels 10 min: 7 (lb/10Qft2) Bottom Hole Static Temperature: 91 (OF) Density: 9.4 (ppg) Volume: 390.50 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Stage No: 1 Slurry No: 1 of.-:fI To: (ft) Description: CW100 Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: CF) Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft'3/sk) Other Vol:50 0 Time Compressive Strength 1: Compressive Strength 2: ~/I- Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 7/21/2003 1 :43:07 PM e Legal Well Name: 18-20 Common Well Name: 18-20 Event Name: ROT - DRILLING Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) -......................... .. ......... Slurry Data Fluid Type: LEAD Slurry Interval: (ft) Water Source: ConocoPhillips Alaska, Cementing Report ':Page 2 of 3 Report #: Start: 1 7/10/2003 Spud Date: 7/10/2003 Report Date: 7/14/2003 End: Stage No: 1 Slurry ,No: 2 of 4 Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol:50 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) ---....-.---.....-...-............ .. ..... Time Compressive Strength 1: Compressive Strength 2: Temp ("F) (OF) .. --.-------..... ...-.....-.-.-- Stage No: 1 Slurry No: 3 of 4 ... .----.- .... ...- ..--..----- Description: ARCTIC SET To: 3,785.00 (ft) Cmt Vol: 511.0 (bbl) Density: 10.70 (ppg) Slurry Vol:670 (sk) Water Vol: 309.2 (bbl) - Class: G Yield: 4.28 (ft3/:,k) Other Vol: 0 Test Data Thickening Time: 6.00 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) . Trade,Name D79 S001 D46 D65 D124 D53 D44 Slurry Data Fluid Type: TAIL Slurry Interval: 3,785.00 (ft}To: Water Source: Test Data Thickening Time: 3.42 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) ("F) Stage No: 1 Slurry Nø: 3 01,4- Additives Type .. Units Liquid Cone. Concentration 1.50 %BWOC 1.50 %BWOC 0.60 %BWOC 0.50 %BWOC 43.10 %BWOC 30.00 %BWOC Stage No: 1 Slurry N()(4 of 4 Description: LiteCRETE 5,221.00 (ft) Cmt Vol: 141.0 (bbl) Slurry Vol348 (sk) ------- Class: G Density: 12.00 (ppg) Yield: 2.27 (ft3/sk) Water Vol: 64.7 (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) -IZ- Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) ........ ..--...-.-.-. Purpose: PRIMARY Mix Water: 19.38 (gal) Foam Job: N Pressure (psi) (psi) Units 9.00 %BWOW Purpose: TAIL Mix Water: 7.81 (gal) Foam Job: N Pressure (psi) (psi) Printed: 7/21/2003 1:43:07 PM e e ConocoPhillips Alaska Page 3 of 3 Cementi nQ Report Legal Well Name: 18-20 Common Well Name: 18-20 Event Name: ROT - DRILLING Report #: Start: 1 7/10/2003 Spud Date: 7/10/2003 Report Date: 7/14/2003 End: .--...- ------.. . .. Stage No: 1 Slurry No: 4 of 4 - Additives ......----..... ....-...-------............ . . -.-.... ....--.. ...... ....-...... .... .. __ ---Tr.ade Name ....----.---.-..... Type -.L_Ç_OI}C;:~!!:ª_!!...c!'~_._. ... Units 0.80 %BWOC 0.60 %BWOC 0.30 %BWOC . Liquid Cq!!c;::.. Units D65 D46 D79 Casing Test Shoe Test Liner Top Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: Log/Survey Evaluation . InterpretationSÜmmary CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: CementTop: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Remarks Held PJSM with all personal. Switch over to Dowell, Mix & Pump 5 bbls CW1 00, Pressure test lines to 3500 psi, Mix & pump 45 more bbls of 8.3 ppg CW1 00 at rate of 4.5 bpm @ 350 psi, Shut down, Drop btm plug, Mix & pump 50 bbls MudPUSH wI Red dye added at 10.5 ppg at rate of 4.5 bpm @ 280 psi, Switch to Lead cement, Mix & Pump 511.0 bbls (670 sxs) of ArcticSet Lite cmt. mixed at 10.7 ppg w/1.5%D79, 1.5%S001, .6%D46, .5%D65, 43.1%D124, 30.0%D53, 9.0%D44 at rate of 6.3 bpm @ 300 psi, Followed by 141.0 bbls LiteCRETE Tail cmt (348 sxs) mixed at 12.0 ppg wI .8%D65, .6%D46, .3%D79 at rate of 5 bpm at 250 psi, Pump 2 bbls fresh water, Shut down, Drop top plug, Displace cmt wI 20 bbls fresh water followed by total of 370.5 bbls 9.4 ppg mud at rate of 6.5 bpm @ 400 psi, Had red dye to surface after 94 bbls of displacement, Slowed rate down to 2.6 bpm @ 800 psi for last 20 bbls of displacement, Bumped plug with 1300 psi, CIP @ 2045 hrs 7/14/03, Had good circ. thru out job, Had 191 bbls cement returns to surface, Floats held -OK, Worked casing until started pumping Tail cement. Note; At 120 bbls Lead cement pumped, Dowell's computer system on the cement unit had complete failure. Cement report was manually put in with figures written down on completion of the job. Printed: 7/21/2003 1:43:07 PM - /3- PRESSURE INTEGRITY TEST PHilLIPS Alaska, Pump Rate Volume/Stroke Volume Input ... Strklmin ... BblslStrk ... Strokes .... Mud Pump #1 Pump used Casing Test 0.5 5 7 9 9.5 10 3 5 8 30 .... annulus and DP. Pumping down Rig Wel Name Casing Shoe Size: Ft-MD .... BTC .... 1 ppg I I 1450 + .... = = EMW - held 4000 3500 3000 2500 000 2000 500 500 w ex: :::¡ V) V) w ex: 0.. 30 o o 6 4 _LEAK-OFF TEST 2 ..........CASING TEST o o Comments: ConocoPhillips Alaska Casing Report Page 1 of 2 Legal Well Name: 18-20 Common Well Name: 18-20 Event Name: ROT - DRILLING Report #: Start: 2 7/10/2003 Spud Date: 7/10/2003 Report Date: 7/18/2003 End: General Information String Type: Intermediate CasinglLiner Permanent Datum: Kelly Bushing Hole Size: 8.500 (in) Hole TMD: 8,015.0 (ft) Hole TVD: 6,033.0 (ft) KB-Datum: 89.00 (ft) Water TMD: (ft) Str Wt on Slips: 170,000 (Ibs) e Ground Level: 61.00 (ft) CF Elevation: (ft) Liner Overlap: (ft) Max Hole Angle: 52.01 (0) Circ Hours: 3.75 (hr) Mud Lost: (bbl) KB to Cutoff: 26.20 (ft) Days From Spud: 8.00 (days) Casing Flange 1 Wellhead Manufacturer: FMC Hanger Model: Actual TMD Set: 8,005.65 (ft) Model: Gen V Packoff Model: Top Hub/Flange: (in) I 5,000 (psi) BTM Hub/Flange: (in) I 5,000 (psi) I '- IJ. \ I - --_.__._--_.~--_._.- Item Size Weight Grade (in.) (Iblft) Casing Hanger 7.000 Casing 7.000 26.00 L-80 Float Collar Casing 7.000 26.00 L-80 Float Shoe 7.000 Integral Casing Detail Drift Threads JTS Length .' Top MU Torq. THD Manufacturer Model Condo Max OD MinlD Compo Name (in) (ft) (ft) (ft-Ibf) (in) (in) 6.151 BTC 1 1.77 26.20 Casing Hanger 6.151 BTC 192 7,890.48 27.97 6.276 7" 26# L-80 Cas 6.151 BTC 1 1.24 7,918.45 Float Collar 6.151 BTC 2 84.55 7,919.69 6.276 7" 26# L-80 ca_ 6.151 BTC 1 1.41 8,004.24 Float Shoe 8,005.65 Non~lntegral Casing Accessories Accessory Manufacturer. Number Spacing (ft) Interval . How Fixed' Bowspring Centralizer Centering Guides Centering Guides WEATHERFORD WEATHERFORD WEATHERFORD 20 5 4 Top (ft) 7,985.0 5,209.0 525.0 Bottom (ft) 7,213.0 OverCollar 5,006.0 Floating 152.0 Floating Remarks Rig & ran 7",26#, L-80, BTCM casing as follows, 7" Weatherford Float Shoe @ 8,005.65',2 joints 7" casing, 7" Weatherford Float Collar @ 7918.45', 192 joints 7' casing, FMC Gen V -11" x 7" Hanger wI 1.25' 7" casing pup joint on the btm., Landed casing wI 26.20' RKB, Placed 1 Bowspring centralizer in the middle of joints 1 & 2, Attached Bowspring centralizers on every Printed: 7/21/2003 1:42:36 PM Page 2 of 2 ConocoPhillips Alaska 7/10/2003 7/18/2003 Spud Date Report Date End: 2 7/1 0/2003 Casing Report Report # Start: 1 8-20 1 8-20 ROT Legal Well Name Common Well Name Event Name DRILLING e e :42:36 PM Broke circulation at 2500' & 7/21/2003 Printed: Remarks collar 3-19, Slid 7" x 8-3/8" Centering Guides onto joint #69 thru 73 and joint #183, 186, 189 & //191. Thread locked all connections from top of float collar down Circulated 200 bbls at 5220' then ran to btm, Had good displacement alllhe 10 btm. Had no mud loss on way in hole. ~ ~ \ It e ... . . . . ConocoPhillips Alaska .·.;Page 1 of3' Cementing Report Legal Well Name: 18-20 Common Well Name: 18-20 Event Name: ROT - DRILLING Primary Hole Size: 8.500 (in) TMD Set: 8,006 (ft) Date Set: 7/18/2003 Csg Type: Intermediate CasinglLi Csg Size: 7.000 (in.) Report #: Start: 2 7/10/2003 Cement Job Type: Primäry Squeeze Open Hole Hole Size: SQ TMD: (ft) sa Date: SQ Type: Cmtd. Csg: Intermediate CasinglLi Cmtd. Csg: Cement Co: Dowell Schlumberger Rot Time Start: : Rec Time Start:13:45 Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Spud Date: 7/10/2003 Report Date: 7/18/2003 End: Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement: Reciprocating Cementer: Dennis Davis Time End: : Time End: 20:00 RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 15.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 225 (Ibs) Type: Cement Casing Volume Excess %: 75.00 Meas. From: Time Circ Prior To Cementing: 4.25 Mud Circ Rate: 252 (gpm) Mud Circ Press: 550 (psi) Pipe Movement Stage No: 1 of 1 Start Mix Cmt: 18:53 Start Slurry Displ: 18:53 Start Displ: 19:03 End Pumping: 20:00 End Pump Date: 7/18/2003 Top Plug: Y Bottom Plug: Y Type: Non-Disp. LS Density: 10.0 (ppg) Vise: 42 (s/qt) Bottom Hole Circulating Temperature:112 (OF) Displacement Fluid Type: Mud Slurry Data Fluid Type: FLUSH Slurry Interval: 4,687.00 (ftyro: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.00 (bbl/min) 6.00 (bbl/min) Y 550 (psi) 1 ,200 (psi) 5 (min) Y Max Torque: (ft-Ibf) Drag Down: 120 (Ibs) Returns: Full Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Density Meas By: Densometer PVIYP: 12 (cp)/14 (lb/100ft2) Gels 10 see: 6 (lb/100ft2) Gels 10 min: 11 (lb/10Qft2) Bottom Hole Static Temperature: 144 (OF) Density: 10.0 (ppg) Volume: 300.90 (bbl) Mud Data Stage Nó:1 Slurry No: 1 of 3 Description: CW100 5,880.00 (ft) Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) -/7- Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: () Time Compressive Strength 1: Compressive Strength 2: PlII'XîSe: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 7/21/2003 1 :42:56 PM e e ConocoPhillips Alaska Page 2 of 3 Cementing Report Legal Well Name: 1 8-20 Spud Date: 7/10/2003 Common Well Name: 1 8-20 Report #: 2 Report Date: 7/18/2003 Event Name: ROT - DRILLING Start: 7/10/2003 End: Slurry Data Fluid Type: FLUSH Slurry Interval: 5,880.00 (ft}To: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Slurry Data Fluid Type: PRIMARY Slurry Interval: 7,208.00 (ft}To: Water Source: Test Data Thickening Time: 3.08 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Tr/ide'Name D46 D65 D167 B155 Stage N(): 1 SlUrry No: 2 of 3 Description: MUDPUSH XL Class: 7,208.00 (ft) Cmt Vol: (bbl) Density: 11.20 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: () Purpose: SPACER Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Pressure (psi) (psi) Temp (OF) (OF) Stage No: 1 Slurry No: 3 of 3 Clc::.s$ "6- .., Description: AnCTIC SE:T 8,005.00 (ft) Cmt Vol: 41.7 (bbl) Density: 15.80 (ppg) Slurry Vol201 (sk) Water Vol: 24.3 (bbl) Class: G Yield: 1.16 (ft3/sk) Other Vol: () Purpose: PRIMARY Mix Water: 5.09 (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Pressure (psi) (psi) Temp (OF) (OF) Stage No: 1 Slurry No: 30f 3 - Additives Type Units liquid Cone. Units Concentration 0.20 %BWOC 0.30 %BWOC 0.35 %BWOC 0.05 %BWOC Printed: 7/21/2003 1 :42:56 PM -/B _. e e ConocoPhillips Alaska Page 3 of 3 ,::Cementing Report Legal Well Name: 18-20 Common Well Name: 18-20 Event Name: ROT - DRILLING Report #: Start: 2 7/10/2003 Casing Test .Shoe"Têst Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: . .. ... . ...-......-----.----- . ... ... ......... .-.......- Log/Survey Evaluation Interpretation Summary . -.-.----..... -. .... - _. ___..__._u . _ ........... ___.... ... . CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Remarks Spud Date: 7/10/2003 Report Date: 7/18/2003 End: Liner Top Test Tool: Tool: .....---......- - . --....-. ... Held PJSM with all personal. Switch over to Dowell, Mix & Pump 10 bbls CW1 00, Pressure test lines to 3500 psi, Mix & pump 20 more bbls of 8.3 ppg CW1 00 at rate of 5.1 bpm @ 530 psi,Followed by 30 bbls MudPUSH at 11.2 ppg at rate of 5.0 bpm @ 530 psi, Shut down, Drop btm plug, Mix & pump 201 sxs (41.7 bbls) Class 'G' Cmt. wI .200%D46, .300%D65, .350%D167, .050%B155 mixed at 15.8 ppg at rate of 5.0 bpm @ 675 psi, Shut down, Drop top plug, Displace cmt w/1 0 bbls fresh water followed by total of 290.9 bbls 10.0 ppg mud at rate of 6.0 bpm @ 700 psi, Slowed rate down to 3.0 bpm @ 550 psi for last 16 bbls of displacement, Bumped plug with 1200 psi, CIP @ 2000 hrs 7/18/03, Had good circ. thru out job, Floats held -OK, Worked casing through out job, No noticeable mud loss, Well static. -/7- Printed: 7/2112003 1 :42:56 PM ... Rate Volume/Stroke ... Bbls/Strk ... Volume Input Strokes "I\lI' Mud Pump #1 Name: Pressure Strks ... annulus and DP. Casing Shoe Test LOT/FIT Type of 1 3 4 7 10 o 1 2 3 7 9 10 25 30 Ft-TVD "I\lI' Ft2 Ft-MD 711 00 Ft2 Other - RKB-CHF "I\lI' - 12.2 + - 4000 3000 2500 2000 3500 500 000 30 2S o 4 500 _LEAK-OFF TEST ..........CASING TEST Comments: - ConocoPhillips, Alaska i,Daily Drilling Report WELL NAME TMD 1 TVD 1 DFS AUTH MD 1 DAIL Y TANG 8,635.0 0 DAILY INT W/O MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 224,598 I JOB NUMBER 1 EVE~DC~DE 124 HRS PROG 1 FIELD NAME I OCS NO. Doyon 141 Kuparuk River ACCIDENTS LAST 24 HRS.? 1 B-20 SUPERVISOR 1 RIG NAME & NO. Dearl Gladden/Pat Reilly n1334@ppco.co CURRENT STATUS PU DP and working on diverter modifications. 24 HR FORECAST Complete diverter modification, check system for leaks, spud LITHOLOGY 1 JAR HRS OF SERVICE 1 BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING (in) @ I LEAKOFF AFE 10029900 1 NEXT CASING (in) @ eft) Page 1 of1 I REPT NO. I DATE 1 7/10/2003 ¡CUM. TANGO CUM INT ANG WI MUD o CUM COST WI MUD 224,598 AUTH. LAST BOP PRES TEST eft) DENSITY(ppg)' 8.70 PP : ·..···1 . FV PVNP. GELS : WUHTHP' FCIT.SOL: 192 I 23/36'[17/42""-r 13.61 ¡ '----31 I ECD¡ 'MUo'DATAi DAILY COST i 0 '-"--CÙMCOST: "-OiUWAT ! %S~~dIMB'¡' Ph/pM .. ......·P"fiMi-·-..· CI Ca .m./_ . I 122.5 10.01 . "'--'-'T n_ o H2S ¡LIME i ES "r'-''''-r OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB.,:·':,' PHASE ...,: 'DESCRIPTION 03:00 03:30 0.50 MOVE P MOVE MOVE Move pipe shed and rock washer. 03:30 04:30 1.00 MOVE P MOVE MOVE Move modules and sub off well. 04:30 07:30 3.00 MOVE P MOVE MOVE Move modules and sub to 1 B pad. 07:30 08:30 1.00 MOVE P MOVE MOVE Move sub over well, level and shim. 08:30 10:30 2.00 MOVE P MOVE MOVE Spod modules, level and shim. 10:30 11:30 1.00 MOVE P MOVE MOVE Move pipe shed and rock washer to 1 B pad. 11:30 12:00 0.50 MOVE P MOVE MOVE Spot pipe shed and rock washer. Take on water to pits and nippled up. Rig accepted on 1B-20 @ 1200 hrs 7/10103. 12:00 13:00 1.00 MOVE P RURD RIG UP Spot rock washer and berm around same. (mix spud mud). 13:00 14:00 1.00 MOVE P RURD RIGUP extend diverter line beyond flow lines. Move camp. (mix spud mud) 14:00 18:00 4.00 DRILL P RIRD RIGUP Hook up pipe skate, install riser pipe on stack. (mix spud mud) Go through pre spud check list. 18:00 22:50 4.83 DRILL P PULD RIG UP Load pipe shed w/150 joints 5" DP and PU same. 22:50 23:00 0.17 DRILL P OTHR RIG UP Diverter and koomey test. Witness waived by John Spaulding (AOGCC). 23:00 00:00 1.00 DRILL P PULD RIGUP PU HWDP. 24 HR SUMMARY: Move from 3R to 1 B-20. PU DP. COMPANY ConocoPhillips Company Doyon Drilling 'nc Doyon Universal Service . SERVICE PERSONNEL DATA NO.. HOURS COMPANY 2 Baker Hughes Inteq 29 APC - Alaska Petroleum 5 M-I Drilling Fluids SERVICE ITEM UNITS gals gals gals MATERIALS I CONSUMPTION ON HAND ITEM 3,690 Water, Drilling 2,720 Water, Potable UNITS bbls bbls USAGE 710 640 Fuel Camp Fuel Tioga -21- NO;" HOURS 4 2 2 USAGE 710 88 ON HAND' -110 112 Printed: 7/21/2003 1 :48:01 PM / - e ConocoPhillips, Alaska ,DaUy Drilling Re'þôrt Page 1 of 2 WELL NAME I JOB NUMBER 1 EVENT CODE 124 HRS PROG ODR 1,259.0 1 FIELD NAME I OCS NO. Doyon 141 Kuparuk River ACCIDENTS LAST 24 HRS.? TMD ITVD 1 DFS 1,259.0 1,253.0 1.00 AUTH MD 1 DAILY TANG 8,635.0 0 DAILY INT WIO MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 138,727 IREPTNO. I DATE 2 7/11/2003 1 CUM. TANGO CUM INT ANG WI MUD o CUM COST WI MUD 363,325 1 B-20 SUPERVISOR I RIG NAME & NO. Dearl Gladden/Mike Thor n1334@ppco.co CURRENT STATUS Drilling 12-1/4" hole @ 1965' 24 HR FORECAST Drill 12-1/4' Surface hole LITHOLOGY 1 JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF LAST SURVEY: DATE TMD INC AZIM 1 LAST CASING 7/11/2003 1,203.20 11.660 228.630 16.000 (in) @ 138.0 (ft) DENSITY(ppg) I 8.90 Ippl IECD IMUDDATAI DAILY COST, I FV ·1' PVNP I GELS WLiHTIiP·1 FCrr.SOL I OILlWAT I %SandlMBT 1 Ph/PM' 190 24/49 34/58 I 11.2/ 31 I 125.0 9.01 AFE AUTH. 10029900 1 NEXT CASING 9.625 (in) @ 5,214.0 (ft) o ¡CUM COST I )t;ul CL I Ca I H2S LAST BOP PRES TEST o I LIME 1 ES ...........-....--.-,-.--. . . .. - ------..-- BHA NO. . 2 ....__..:.. . .....-¡---... ...-.--- BHA WT. BELOW JARS ; STRING WT. UP 00 00 ____~.HA I H.º~_E;_Ç9~ DITIONS STRING WT. DN STRING WT. ROT TORQUE I UNITS BIT NO. 1 R1 . .. ----..--.-- BHA LENGTH 1,076.38 BIT HC MX-CX1 1 1.00 12.250 NAVIDRILL M1C 1 28.15 12.125 SHORT NMDC 1 9.35 7.750 2.810 NON-MAG STAB 1 5.37 MWD 1 29.37 8.000 NM CROSSOVER 1 1.55 7.750 2.875 NM FLEX COLLAR 1 28.64 7.875 2.875 NM FLEX COLLAR 1 30.00 8.062 2.875 NM FLEX COLLAR 1 28.87 7.875 2.875 CROSSOVER 1 2.45 8.000 2.625 HWDP 4 120.31 5.000 3.000 JARS 1 30.30 6.250 2.250 HWDP 25 755.02 5.000 3.000 GHOST REAMER 1 6.00 5.000 4.281 .___u.____.____. BITS . -.--.-. .... ... .. - n. __.... .. . BIT I RUN SIZE MANUF. i TYPE : SERIAL NO. JETS OR TFA DEPTH IN DATE IN ! .-- I-O-D-L-B-G-O-R ~I ¡~._..... \5022494' . ._____m 138":0--7 /:¡-Ù200~ ·1"=-1-NO-A-E-I-NO:DTF-oo. 11 12.250 I HC 12/20/20/2011 1R11 12.250 HC 5022494 12/20/20/2011 915.0 7/11/200 3-4-WT-A-F-3-EC-TD BIT I RUN I 1/ 1 WOB 15/20 RPM 60 I 80 GPM I 500 BIT OPERATIONS PRESS I P BIT ·1 HRS 1 24Hr DIST 1,250 193 4.30 777.0 24Hr ROP I CUM HRS CUM DEPTIiI CUM ROP 180.70 4.30 I 777.0 180.70 M~b. 0.00 138.00 283.56 375.01 467.01 556.33 647.90 INCL. I 0.000 0.000 0.890 0.720 0.520 1.120 2.270 AZIMUTH 0.000 0.000 322.700 298.600 265.740 226.870 225.590 SURVEY DATA '1':'11.0. NIS CUM EIW CUM SE(:T10N M.D.> 0.00 0.00 0.00 0.00 737.35 138.00 0.00 0.00 0.00 829.31 283.55 0.90 -0.69 0.23 918.88 375.00 1.74 -1.62 0.71 1,010.68 466.99 1.99 -2.54 1.43 1,109.04 556.30 1.36 -3.59 2.64 1,203.20 647.83 -0.52 -5.53 5.21 INCL. 3.430 5.820 8.540 8.570 10.060 11.660 AZIMUTH 215.750 219.180 221.390 225.170 228.260 228.630 ,'T.V.D/ NIS CUM EIW CUMSE,(:T10N 737.17 -3.93 -8.36 9.24 828.82 -9.78 -12.92 15.88 917.68 -18.29 -20.18 26.12 1,008.46 -28.23 -29.54 38.86 1,105.52 -39.12 -41.15 54.05 1,197.99 -50.88 -54.43 71.11 Printed: 7/21/2003 1:47:36 PM -2Z- e e Page 2 of 2 1 B-20 ConocoPhillips, Alaska Daily Drilling Report'·· 1 JOB NUMBER I EVENT CODE 124 HRS PROG I TMD ODR 1,259.0 1,259.0 ITVD IDFS 1,253.0 1.00 I REPT NO. I DATE 2 7/11/2003 WELL NAME N°'I 1 Emsco MAKE OF PUMP PUMP I HYDRAULIC DATA I STROKE (in) I· LINER (in) I SPM I Q (gpm) I PRESS. (psi) I TOTAL Q 1 12.000 6.000 120 507.62 1,250 507.62 KILL SPM I PRESSURE OPERATIONS SUMf!/J~.BY FROM TO I H~,!RS TROUBLE . . DESCRIPTION CODE SUB PHASE 00:00 01:00 1.00 DRILL P PULD SURFAC Pick up HWDP & 1 Stand DC's, Stand back in derrick 01:00 03:00 2.00 DRILL P PULD SURFAC Make up BHA #1 & Oreint same 03:00 03:30 0.50 DRILL P CIRC SURFAC Fill conductor & diverter with mud 03:30 06:00 2.50 DRILL T OTHR SURFAC Observe leak at FMC riser connector & attempt to repair same - No Good, Remove end section of diverter line to modify same. (Note; Riser connector in bind, Due to diverter line going under Pad flow lines.) 06:00 09:00 3.00 DRILL P PULD SURFAC Stand back BHA & Pick up 28 stands drill pipe. (While modifying diverter line) 09:00 09:30 0.50 DRILL Np OTHR SURFAC Wait on orders to proceed by AOGCC Tom Maunder for verble approval on modifcation to diverter line -OK. 09:30 17:45 8.25 DRILL P DRLG SURFAC Spud @ 0930 hrs. Drill f/138' to 915' ART= 2.9 hrs AST == 1.4 hrs 10-15 WOB, 80 RPM, 506 GPM @ 1200 PSI, UP 90K, DN 90K, ROT 90K, TO 2500, MWD Failed @ 915' - Would not switch over from Magnetic to High side. 17:45 19:00 1.25 DRILL Np TRIP SURFAC POOH to MWD 19:00 20:00 1.00 DRILL Np PULD SURFAC Change out MWD, Orient new MWD, Check bit -OK 20:00 20:30 0.50 DRILL Np TRIP SURFAC RIH (Test MWD -OK) to 915' 20:30 00:00 3.50 DRILL P DRLG SURFAC Drill f/915' to 1259' ART = .9 hrs AST = .8 hrs 15-20 WOB, 80 RPM, 506 GPM @ 1250 PSI, UP 90K, DN 90K, ROT 90K, TO 2500. 24 HR SUMMARY: PIU HWDP & BHA, Fill hole- Diverter leaked, Repair same, PIU 28 stands Drill pipe, Spud & drill to 915'- MWD failed, POOH, Change MWD, RIH to 915', Drill to 1259' COMPANY ConocoPhillips Company Doyon Drilling Inc Doyon Universal Service SERVICE PERSONNEL DATA NO. HOURS COMPANY 4 Baker Hughes Inteq 29 APC - Alaska Petroleum 5 M-I Drilling Fluids ,SERVICE NO. HOURS 4 2 2 ITEM UNITS. gals gals "MATERIALS I CONSUMPTION USAGE ON HAND I . iTEM 1,915 15,100 I Water, Drilling 3,040 Water, Potable UNITS bbls bbls USAGE 880 ON HAND 520 318 Fuel Camp Fuel . . RESERVOIR NAME 1 R-18 11 B-20 RESERVOIR AND INTERVAL DATA ZONE .. ,.. : TO;80 I BASE 0 j COMMENTS: Printed: 7/21/2003 1 :47:36 PM -23-- WELL NAME - ConocoPhillips, Alaska , Daily Drilling Report I JOB NUMBER 1 EVENT CODE 124 HRS PROG ODR 2,878.0 1 FIELD NAME I OCS NO. Doyon 141 Kuparuk River ACCIDENTS LAST 24 HRS.? e Page 1 of2 TMD ITVD IDFS 4,137.0 3,321.0 2.00 AUTH MD 1 DAILY TANG 8,635.0 0 DAILY INT WIO MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 118,469 1 REPT NO. 1 DATE 3 7/12/2003 1 CUM. TANGO CUM INT ANG WI MUD o CUM COST WI MUD 481,794 1 B-20 SUPERVISOR 1 RIG NAME & NO. Dearl Gladden/Mike Thor n1334@ppco.co CURRENT STATUS Drilling 12-1/4" hole @ 4540' 24 HR FORECAST T.D. 12-1/4" Surface hole, Wipe hole, Run 9-518" csg. LITHOLOGY I JAR HRS OF SERVICE 1 BHA HRS SINCE INSP 1 LEAKOFF LAST SURVEY: DATE TMD INC AZIM 1 LAST CASING 7/12/2003 4,081.37 50.990 249.080 16.000 (in) @ 138.0 (ft) DENSITY(ppg) I 9.30 I PP ECD: I MUD DATA,\: DAILY COST I 1~ I :~;~ I ~;~:I W~:P I FC:SOLI;:OI~AT I %5;;:;9T I P:;/M BHA NO. ,I 2 BHA I HOLE CONDITIONS BHA WT. ä2E7LOW JARS I STRIN~4:r' UP STRIN~o~' DN I STRIN~;; ROT I ITEM DESCRIPTION,' NO JTS LENGTH 1 1.00 1 28.15 1 9.35 1 5.37 1 29.37 1 1.55 1 28.64 1 30.00 1 28.87 1 2.45 4 120.31 1 30.30 25 755.02 1 6.00 BIT HC MX-CX1 NAVIDRILL M1C SHORT NMDC NON-MAG STAB MWD NM CROSSOVER NM FLEX COLLAR NM FLEX COLLAR NM FLEX COLLAR CROSSOVER HWDP JARS HWDP GHOST REAMER AFE AUTH. 10029900 1 NEXT CASING 9.625 (in) @ 5,214.0 (ft) o I CUM COST 0 ;1 Pf~f CI·I Ca I H2S I LlMEIES O.D. 12.250 12.125 7.750 8.000 7.750 7.875 8.062 7.875 8.000 5.000 6.250 5.000 5.000 TORQUE I UNITS 9 ft-Ibf I.D. 2.810 2.875 2.875 2.875 2.875 2.625 3.000 2.250 3.000 4.281 LAST BOP PRES TEST BIT NO; I 1R1 '. BHALENGTH 1,076.38 CON'tfSIZE .' CONN TY¡:>E BITS BIT I RUN 21 I ...... I SERIAL N°'1 SIZE I MANUF. TYÞE' JETS OR TFA DEPTH IN DATE IN J I-O-D-L-B-G-O-R 1R11 12.250 HC D 5022494 12/20/20/2011 915.0 7/11/200 3-4-WT-A-F-3-EC-TD '180R;~00 I BIT OPERATIONS; BIT I RUN WOB. GPM I PRESS 1 PBIT I ,'1~~:0 I 24Hr DIST 24Hr ROP I CUM HRS I CUM DEPTH I'C::UM ROP 1R1/ 21 15/30 590 1,950 281 3,222.0 194.10 16.60 3,222.0 194.10 M.D. 1,295.83 1,388.74 1,481.78 1,574.22 1,666.51 1,760.19 1,851.71 1,945.21 2,037.56 2,128.08 2,222.42 INCL. 13.420 15.160 16.450 18.300 22.530 26.870 30.400 34.730 39.080 42.570 44.960 ::ÄZIMUTH 224.140 225.970 229.890 230.890 232.570 234.030 235.910 237.460 239.810 238.060 239.210 T.V.D. 1 ,288.41 1,378.44 1,467.97 1,556.19 1,642.66 1,727.75 1,808.06 1,886.85 1,960.68 2,029.17 2,097.29 SURVEY DATA NIs CUM EJW CI,IM SECTION M.D. ' -64.78 -68.94 90.22 2,314.57 -80.96 -85.18 111.87 2,407.77 -97.91 -104.01 136.19 2,502.08 -115.50 -125.28 162.98 2,595.19 -135.39 -150.58 194.40 2,687.67 -158.75 -181.98 232.83 2,778.30 -183.88 -217.90 276.10 2,871.53 -211.48 -259.97 325.98 2,963.75 -240.29 -307.33 381.15 3,057.54 -270.84 -357.99 440.05 3,148.32 -304.79 -413.71 504.98 3,242.65 INCL. 46.450 47.280 49.800 51.110 51.910 51.440 50.490 52.010 50.870 49.630 50.770 - -z4 - . 'AZIMUTH 237.680 236.510 237.440 235.590 236.630 236.820 236.700 237.230 238.290 238.020 237.740 T.V.D. NIS CUM EJW CUM SECTÌON 2,161.65 -339.31 -469.91 570.59 2,225.37 -376.26 -527.00 638.06 2,287.81 -414.77 -586.26 708.16 2,347.09 -454.39 -646.13 779.29 2,404.65 -494.75 -706.22 850.94 2,460.85 -533.75 -765.66 921.42 2,519.57 -573.45 -826.23 993.21 2,577.29 -612.65 -886.53 1,064.54 2,635.75 -651.78 -948.55 1,137.40 2,693.80 -688.60 -1,007.8 1,206.79 2,754.18 -727.14 -1,069.2 1,278.81 Printed: 7/21/2003 1:47:10 PM WELL NAME M.D. 3,336.25 3,428.51 3,522.84 3,617.40 3,709.27 NO; I 1 Emsco '>INCL. I 50.870 49.970 49.760 49.490 50.980 :FROM TO H()URS 00:00 12:00 12.00 12:00 00:00 12.00 18-20 AZIMU11i . 238.660 237.980 240.170 245.120 246.170 T.V.D. 2,813.31 2,872.10 2,932.90 2,994.18 3,052.94 MAKE OF PUMP e e ConocoPhillips, Alaska Da:ïly Drilling Report I JOB NUMBER 1 EVENT CODE 124 HRS PROG 1 TMD ODR 2,878.0 4,137.0 :i"SURVEY DATA NIS CUM E/W. CUM SECTION M.p" . . -765.37 -1,130.8 1,350.96 3,802.33 -802.71 -1,191.4 1,421.68 3,893.75 -839.77 -1,253.2 1,493.49 3,986.29 -872.86 -1,317.2 1,565.46 4,081.37 -901.97 -1,381.5 1,636.05 Page20f 2 ITVD 1 DFS 3,321.0 2.00 1 REPT NO. 1 DATE 3 7/12/2003 :.". ,. IN,CL. 50.420 51.480 51.560 50.990 : AZIMUTH 246.000 246.560 248.380 249.080 T.V;D'" "NIS CUM EIW CUM SECTION 3,111.89 -931.17 -1,447.3 1,708.03 3,169.48 -959.72 -1,512.3 1,778.98 3,227.07 -987.48 -1,579.2 1,851.31 3,286.55 -1,014.3 -1,648.3 1,925.26 PUMP/HYDRAULIC DATA \', STROKE (in) LlNER'{in) I SPM I a (gpm) PRESS. (psi) I TOTAL a KILL SPM I PRESSUf\~' 12.000 6.000 140 592.22 1,800 592.22 DRLG OPERATIONS SUMMARY PHASE DESCRIPTION,: SURFAC Drill f/1259' to 2744' (2438' TVD) AST= 5.5 hrs ART= 2.4 hrs UP 115K DN 96K ROT = 105K, TO ON BTM= 4,000 ftllb, TQ OFF BTM= 3,000 ftllb, 590 GPM @ 1600 PSI, WOB 20K, RPM 100 SURFAC Drill f/2744' to 4137' (3321' TVD) AST= 1.8 hrs ART= 5.2 hrs UP 140K DN 105K ROT= 120K, TQ ON BTM= 9,000 ftIIb, TO OFF BTM= 7,000 ftIIb, 590 GPM @ 1800 PSI, WOB 25K, RPM 100 CODE 'tROUBLE SUB DRILL P DRLG DRILL P 24 HR SUMMARY: Drill f/1259' to 4137' COMPANY ConocoPhillips Company Doyon Drilling Inc Doyon Universal Service Fuel Camp Fuel ITEM RESERVOIR NAME 1 R-18 SERVICE UNITS gals gals 118-20 PERSONNEL DATA NO. HOURS COMPANY 4 Baker Hughes Inteq 29 APC - Alaska Petroleum 5 M-I Drilling Fluids SERVICE NO. HOURS 4 2 2 MATERIALS 1 CONSUMPTION USAGE: . ON HAND ITEM 2,890 12,210 Water, Drilling 320 2,720 Water, Potable UNITS bbls bbls -USAGE 1,635 ON HAND 665 328 RESERVOIR AND INTERVAL DATA ZONE I TOP I BASE I 2030 0 .. '.... COMMENtS Printed: 7/21/2003 1:47:10 PM -:z:;:>- WELL NAME - ConäcoPhillips, Alaska .' . . Daily Drilling Report 1 B-20 SUPERVISOR I RIG NAME & NO. Dear! Gladden/Mike Thor n1334@ppco.co CURRENT STATUS 1 JOB NUMBER 1 EVENT CODE 124 HRS PROG ODR 1,093.0 1 FIELD NAME I OCS NO. Doyon 141 Kuparuk River ACCIDENTS LAST 24 HRS.? Page 1 of 2 TMD ITVD IDFS 5,230.0 4,015.0 3.00 AUTH MD I DAILY TANG 8,635.0 0 DAILY INT WIO MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 118,097 Running 9 5/8" surface csg 24 HR FORECAST Run & CMT 9-5/8" csg. - ND Div I NU & Test BOPs - TIH LITHOLOGY I JAR HRS OF SERVICE 1 BHA HRS SINCE INSP I LEAKOFF LAST SURVEY: DATE TMD INC AZIM 1 LAST CASING 7/13/2003 5,173.61 51.650 248.600 16.000 (in) @ 138.0 (ft) DENSIJY(ppg) I 9.55 I PP I IECD IMUD DATAl DAILY COST I . FV "1' PVIYP I GELS I WUHTHP ¡ FCfT.SOL \., . OIUWATT %SandIMBT I Ph/pM 96 33/36 14/34 5.61 2/ I I 125.0 9.01 BHA NO. 2 -.......... ...-. BHA WT. BELOW JARS 27 BIT HC MX-CX1 NAVIDRILL M1C SHORT NMDC NON-MAG STAB MWD NM CROSSOVER NM FLEX COLLAR NM FLEX COLLAR NM FLEX COLLAR CROSSOVER HWDP JARS HWDP GHOST REAMER BI1' I RUN 1 1 R11 2 1R~~r~UN 21 M.D. 4,175.20 4,267.59 4,359.63 4,452.08 4,546.07 4,637.01 INCL. . 50.560 50.240 50.030 49.080 50.800 51.000 .....-.-.... . .....--.-...... ..---........ .---.-.-.....---.. - .. .. STRING WT. UP 155 BHA I Ho.~.!=. STRING WT. DN 120 STRING WT. ROT 130 TORQUE I UNITS 10 ft-Ibf 1 1 1 1 1 1 1 1 1 1 4 1 25 1 1.00 28.15 9.35 5.37 29.37 1.55 28.64 30.00 28.87 2.45 120.31 30.30 755.02 6.00 SIZE· I MANUF. 12.250 HC I DTYPE BITS I SERIAL N°'1 JETS'OR TFA 5022494 12/20/20/2011 WOB 20/30 180R;~00 I': ~:~ I BITo.PERA,.IONS" :~~:; I' ::~ 1 '1 ~~;O 12~;9~~T 1 REPT NO. I DATE 4 7/13/2003 ICUM. TANGO CUM INT ANG WI MUD o CUM COST WI MUD 599,891 AFE AUTH. 10029900 1 NEXT CASING 9.625 (in) @ 5,214.0 (ft) o ¡CUM COST I Pf~f CI' I Ca ¡ H2S LAST BOP PRES TEST o I LIME 'I ES" ... .. -.... .-... .. ! BIT NO. 1R1 BHA LENGTH 1,076.38 12.250 12.125 7.750 2.810 8.000 7.750 7.875 8.062 7.875 8.000 5.000 6.250 5.000 5.000 2.875 2.875 2.875 2.875 2.625 3.000 2.250 3.000 4.281 ...... DEPTH,IN DATE IN I 1-0·D·L'Ï3-G-0~R" 915.0 7/11/200~ 3-4-WT-A-F~3-EC-TD .. .... . . . . . . .... .. . . ..... . .... ..... ... ..... ... . .. . ...... .... ... . . . . ... .. . I 24Hr ROP 1 CUM HRS: f'CUM DEPTH I CUM ROP 99.36 27.60 4,315.0 156.34 . . - .___..___ . ___.__. _.......__ ..._ n.. __....___. .__.,___ ._.. _ .__.__..._. . ...__ .__,_".__, SURV~.Y º~I~._... AZIMUTH ~_..!.V.D. iNlS CU~_~..f?UNI! SECTION ;:.. M.I?:...: INCL. 247.740 3,345.88 -1,041.1 -1,715.9 1,997.76 4,729.29 50.720 245.180 3,404.78 -1,069.5 -1,781.2 2,068.88 4,823.27 50.760 244.370 3,463.78 -1,099.6 -1,845.1 2,139.52 4,914.64 51.130 246.250 3,523.75 -1,129.0 -1,909.0 2,209.86 5,008.97 51.180 248.060 3,584.25 -1,156.9 -1,975.3 2,281.70 5,100.54 51.300 250.500 3,641.60 -1,181.9 -2,041.3 2,352.00 5,173.61 51.650 ..... -··.----------·."1--------·------ n__.__._.__.... ..-.-... . AZIMUTH ' T.V.D. ! NIS CUM EJW CUM! SECTION --. .....--.-... -.--. -.--..-.-.-..-....----..-.-..-. 250.880 3,699.85 -1,205.6 -2,108.8 2,423.12 250.260 3,759.33 -1,229.8 -2,177.5 2,495.45 248.560 3,816.90 -1,254.7 -2,243.9 2,566.12 248.410 3,876.06 -1,281.7 -2,312.2 2,639.39 249.450 3,933.39 -1,307.3 -2,378.9 2,710.56 248.600 3,978.91 -1,327.8 -2,432.2 2,767.53 . .. ......- -. ... --... .-.-...- . NO. MAKE OF PUMP 1 I Ems~~-'-"''' PUMP I HYDRAULIC DATA --······--TsmOKE (in)· ·iiÑEÃ--(i~i····· SPM I Q (gp~). .: PRESS. (psi) _u r"-'" 12.000 I -6~õõo'T"'""'1'4() I ""s·gii.22···.. '2,150 TOTAL Q ¡KILL SPM I PRESSURE 592.22Î - -...... -Zú> - - ---. ..------..-...-.. Printed: 7/21/2003 1 :46:47 PM 'Conoc()P,hiUip~, Ala$ka .' .' Däily DrillingR~port.. I JOB NUMBER I EVENT CODE 124 HRS PROG I TMD ODR 1,093.0 5,230.0 -~'iI"_' WELL NAME 1 B-20 - .. . .... .... .. . ..... . ..... . . . .. . .. Page 20t2 ITVD I DFS 4,015.0 3.00 I REPT NO. I DATE 4 7/13/2003 OPERATIONS SUMMARY PHASE DESCRIPTION SURFAC Drill f/4137' to 5230' (4014' TVD) AST= 1.9 hrs ART= 9.1 hrs, UP 155K, DN 120K, ROT 132K, 590 GPM @ 2150 PSI, 100 RPM, 20-30K WOB SURFAC Pump Hi-Vis weighted sweep & circ for wiper trip SURFAC Precautionary back ream out to 4137', Slight packing off. SURFAC RIH to 5230' no problems SURFAC Pump Hi-Vis weighted sweep & Circ hole clean total of 3.5 btm's up, 590 GPM @ 2150 PSI 100 RPM wI 7,000 ftIlb TQ SURFAC POOH to BHA (Hole in very good shape- Pulled 30K over f/1800' to 1700', wiped out very good) 24 HR SUMMARY: Drill f/1259' to 5230' 12-1/4" TD, Circ. clean, Wipe & pump out to 4137', RIH to 5230', Circ. hole clean, POOH to BHA. FROM TO I HOURS CODE TROUBLE SUB 00:00 15:15 15.25 DRILL P DRLG 15:15 16:30 1.25 DRILL P CIRC 16:30 18:00 1.50 DRILL P WIPR 18:00 18:30 0.50 DRILL P WIPR 18:30 21:00 2.50 DRILL P CIRC 21:00 00:00 3.00 DRILL P TRIP COMPANY ConocoPhillips Company Doyon Drilling Inc Doyon Universal Service SERVICE ITEM UNITS gals gals USAGE 2,420 240 Fuel Camp Fuel PERSONNEL DATA NO. HOURS COMPANY 3 Baker Hughes Inteq 29 APC - Alaska Petroleum 5 M-I Drilling Fluids SERVICE NO. HOURS 4 2 2 MATERIALS I CONSUMPTION ON HAND ITEM 9,790 Water, Drilling 2,480 Water, Potable , 'UNITS bbls bbls USAGE 1 ,420 59 ON HAND 645 331 RESERVOIR NAME 1 R-18 11 B-20 RESERVOIR AND INTERVAL DATA ZONE. I . TOP I BASE I 1450 0 COMMENTS Printed: 7/21/2003 1 :46:47 PM -27- WELL NAME e e ConocoPhillips, Alaska Daily Drilling Report.... . .. .. 1 B-20 SUPERVISOR I RIG NAME & NO. Dearl Gladden/Mike Thor n1334@ppco.co CURRENT STATUS I JOB NUMBER I EVE~DC~DE 124 HRS PROG I FIELD NAME I OCS NO. Doyon 141 Kuparuk River ACCIDENTS LAST 24 HRS.? Testing BOPE TMD ITVD IDFS 5,230.0 4,015.0 4.00 AUTH MD I DAILY TANG 8,635.0 0 DAILY INT WIO MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 7/11/2003 441,088 I LEAKOFF AFE 10029900 I NEXT CASING 5,221.7 (ft) 7.000 (in) @ 8,008.0 (ft) 24 HR FORECAST NU & Test BOPs - TIH, Drill out, LOT, Drill 8-1/2' hole LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 7/13/2003 5,173.61 51.650 248.600 9.625 (in) @ BHANO.; 2 . ...... . BHA WT. BELOW JARS : --00-1 ITEM DESCRIPTION ...__n.. _ .. BIT HC MX-CX1 NAVIDRILL M1C SHORT NMDC NON-MAG STAB MWD NM CROSSOVER NM FLEX COLLAR NM FLEX COLLAR NM FLEX COLLAR CROSSOVER HWDP JARS HWDP GHOST REAMER BIT I RUN 1R11 BIT I RUN :FROM TO 00:00 02:30 02:30 03:30 03:30 07:00 07:00 08:00 08:00 10:00 10:00 10:30 10:30 11:00 11 :00 12:00 12:00 16:45 16:45 21 :00 .........-.-....--- STRING WT. UP 00 '-.-~-=I . . ... __.__n..______.. _ .... .... .__.. _. BHAI ~º~~..Ç()NDITION~ ..00 '_00' __. . STRING WT. DN i STRING WT. ROT TORQUE I UNITS . oo'[:~~~~:. _00'''_' -..~.~:~:=~=:::_=[==.~:=:... ~::.~~~-=:~._~.:., . ----..-. I I 21 SIZE I MANUF. 12.250 HC L WOB HOURS 2.50 1.00 3.50 1.00 2.00 0.50 0.50 1.00 4.75 4.25 CODE DRILL P CASE P CASE P CASE P CASE P CASE P CASE P CASE P CEMENT P CEMENT P I'IPM NO JTS LENGTH O.D. I.D. -.-- -.- ---. .-- . .... .---.,--... . ..-- - ...-- 1 1.00 12.250 1 28.15 12.125 1 9.35 7.750 2.810 1 5.37 1 29.37 8.000 1 1.55 7.750 2.875 1 28.64 7.875 2.875 1 30.00 8.062 2.875 1 28.87 7.875 2.875 1 2.45 8.000 2.625 4 120.31 5.000 3.000 1 30.30 6.250 2.250 25 755.02 5.000 3.000 1 6.00 5.000 4.281 BITS I D TYPE SERIAL NO.·· JETS OR TFA 5022494 12/20/20/2011 Page 1 of 2 I REPT NO. I DATE 5 7/14/2003 I CUM. TANGO CUM INT ANG WI MUD o CUM COST WI MUD 1,040,979 AUTH. LAST BOP PRES TEST ....-.-.---..-- -- .-...---...-- -- --. - BIT NO. ' 1R1 BHA LENGTH 1-"-' . 1 ,076.38- CONN SIZE ' CONN TYPE _n_._____________ __._.. DEPTH IN DATE IN I I·O·D.·L·B·G-O-R 915.0 7/11/200~ 3-4-WT-A-F-3-EC-TD BIT OPERATIONS PRESS I P BIT I' HRS I 24Hr. DIST 24Hr ROP I CUM HRS CUM DEPTH I CUM ROP 'OPERATIONS SUMMARY" . . ft. .:PHASE . . SURFAC Lay down BHA, Clear rig floor SURFAC Rig up GBR 9-5/8' Fill up tool & Doyon casing tools. SURFAC PJSM, Run 9-5/8", 40#, L-80, BTC casing to 2955' with no problems. SURFAC Circ. btm's up @ 2955' stage rate up to 6 bpm @ 500 psi, No mud loss SURFAC Run 9-5/8" csg to 5139' - Hit tight spot SURFAC Work thru tight spot & run csg. to 5190' SURFAC Make up hanger & landing joint, Land csg. at 5221' SURFAC Lay down GBR fill up tool, Make up Dowell cement head. SURFAC Circ. & condo mud for cement job 7 bpm @ 370 psi. No mud loss. SURFAC Held PJSM, Switch to Dowell, Mix & pump 5 bbls CW100, Pressure test lines to 3500 psi, Mix & pump 45 more bbls of 8.3 ppg CW100 at rate of 4.5 bpm @ 350 psi, Shut down, Drop btm plug, Mix & pump 50 bbls MudPUSH wI Red dye added at 10.5 ppg at rate of 4.5 bpm @ 280 psi, Followed by 670 sxs (511.0 bbls) ARCTICSET Lead cmt. mixed at 10.7 ppg w/1.5%D79, I GPMI TROUBLE! SUB', PULD RURD RUNC CIRC RUNC RUNC RUNC RURD CIRC PUMP . "DESCRIPTlON - 2S .- Printed: 7/21/2003 1 :46:24 PM e WELL NAME 1 B-20 .. ....-.---.... . FÃ·~~I=~~··-"! HÖ~:~~I' CODE ..~!~~~~ï:Ë···· SUB 16:45 21 :00 4.25 CEMENT P PUMP 21 :00 22:00 22:00 00:00 1.00 CEMENT P 2.00 WELCTL P PULD NUND e Page 2 of 2 ConocoPhillips, Alaska Daily Drilling Report IJOBNUMBER IEVE~Dc~DE 124HRSPROG IT~~230.0 ITVD IDFS 4,015.0 4.00 I REPT NO. I DATE 5 7/14/2003 .. - ...--..-.-....------.... .--- _.______. ..____.__n_ ...u .__u. Q~.¡;B.~ItºN§. $.UMMAR.Y.... .............. .... ..... ..........._.......__. PHASE DESCRIPTION n. ..u__.... SURFAC 1.5%S001, .6%D46, .5%D65, 43.1%D124, 30.0%D53, 9.0%D44 at rate of 6.3 bpm @ 300 psi, Followed by 348 sxs (141.0 bbls) LiteCRETE Tail cmt. mixed at 12.0 ppg wI .8%D65, .6%D46, .3%D79 at rate of 5 bpm @ 250 psi, Pumped 2 bbls fresh water, Shut down, Drop top plug, Displace cmt. wI 20 bbls fresh water followed by 370.5 bbls 9.4 ppg mud at rate of 6.5 bpm @ 400 psi, Had red dye to surface after 94.0 bbls of displacement, Slowed rate down to 2.6 bpm @ 800 psi for last 20 bbls of displacement, Bumped plug wI 1300 psi, C.I.P @ 2045 hrs 7/14/03, Had good circ. thru out job, Floats held -OK, Worked csg. until started pumping tail cmt, Had 191.0 bbls cement retums to surface. SURFAC Rig down Dowell cmt. head, Lay down landing joint, Flush out diverter system. SURFAC Nipple down Diverter system. ..-...-...------ .. 24 HR SUMMARY: Lay down BHA, Rig & run 9-5/8" csg. to 5221', Cement 9-5/8' w/191 bbls cmt. returns, Nipple down diverter .._u_..... .....----... COMPANY ConocoPhillips Company Doyon Drilling Inc Doyon Universal Service SERVICE ',.ITEM USAGE 1,320 320 Fuel Camp Fuel UNITS gals gals ... ...---. ................ . ... ...- ........-- . ~~J~~9NNEL DATA NO. 'HOURS, COMPANY' "T" .............--SERVic"ë..· --...... - ....-.. 3 Baker Hughes Inteq 29 APC - Alaska Petroleum 5 M-I Drilling Fluids .-------...-....-.. . ....:._._.~_()_~....... '. ~OURS 4 2 2 MATERIALS I CONSUMPTION I ON HAND ITEM I 8,470 Water, Drilling 2, 160 Water, Potable USAGE 1,105 147 UNITS bbls bbls ON HAND 640 184 RESERVOIRNAME 1 R-18 j 1 B-20 RESERVOIR AND INTERVAL DATA lONE I TOP I BASE I' 1705 0 C()~MENTS ." Printed: 7/21/2003 1 :46:24 PM ""';2"1- e e ConocoPhillips, AlaSka' Daily Drilling Repott TMD TVD IDFS 5,850.0 4,406.0 5.00 AUTHMD 1 DAILY TANG 8,635.0 0 DAILY INT WIO MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 7/11/2003 129,821 1 LEAKOFF AFE 16.26 10029900 1 NEXT CASING 5,221.7 eft) 7.000 (in) @ 8,008.0 eft) 1 B-20 SUPERVISOR I RIG NAME & NO. Fred Herbert/Mike Thornt n1334@ppco.co CURRENT STATUS I JOB NUMBER EVENT CODE 124 HRS PROG ODR 620.0 1 FIELD NAME I OCS NO. Doyon 141 Kuparuk River ACCIDENTS LAST 24 HRS.? DENSITY(ppg)' 9.50 pp! ;,ECD: M,UI:.U;)_AI~_...~~..~~~_~~!._i_ ,. FV ¡ PVNP GELS, WUHTHP' FCIT.SOL; OIUWAT ! %SandIMBT: Ph/pM I --'55 "'15/22 112/24 ¡---"'4:sï T.... '11 I I [" /Ù...s------T---1""õ:OI -- Î __n'__._..,...._......". BHAI STRING WT. DN 105 WELL NAME Drilling 8-1/2" Hole @ 6450' 24 HR FORECAST Drill 8-1/2" hole to top set depth of 8008' 1 JAR HRS OF SERVICE 1 BHA HRS SINCE INSP INC AZIM 1 LAST CASING 50.260 246.410 9.625 (in) @ LITHOLOGY LAST SURVEY: DATE TMD 7/15/2003 5,751.51 .- . ----.--.. .. --...- -- .----.. ...-..---. . o PflMf . ... -...- -.. -.. --...--.- .--....... . .. _~.~~..~O:. : 3 _.... _...____......_.............._..._........... BHA WT. BELOW JARS 13 BIT HCM605 MACH 1 XL MTR NON-MAG STAB CROSSOVER MPR MWD CROSSOVER NMCSDP NMCSDP NMCSDP CROSSOVER HWDP JARS HWDP DRILL PIPE "G-105" 1 1 1 1 1 1 1 1 1 1 1 4 1 25 STRING WT. ROT 130 Påge 1 of 2 1 REPT NO. I DATE 6 7/15/2003 I CUM. TANGO CUM INTANG WI MUD o CUM COST WI MUD 1,170,800 AUTH. LAST BOP PRES TEST 7/15/2003 : CUM COST . CI Ca I' -- o . . - ._~--_..__._., --..------ H2S ; LIME ¡ ES --r'" -----r-- -...T------· 8.500 8.375 8.375 6.250 6.750 6.750 6.000 5.000 5.000 5.000 6.750 5.000 6.187 5.000 5.000 BIT I RUN 21 " I' 3 I Äg~:~5 Brts I SERIAL N°'1 JETS OR TFA 7102575 12/12/13/13/131 .. ... ... 'I DEPTH IN DATE IN I I·O·D·L·B·G·O·R 5,230.0 7/15/200~ 1-1-CT-S-D-1-WT-TD SIZE I MANUF. 8.500 HC ....-'1".....--.-'-..- ___J.....I:I.I!.~.~_.._.._ ?..._ TORQUE / UNITS BHA LENGTH . .-.... .....-..-..... 15 ft-Ibf 1,083.46 2.000 1.00 31.56 5.75 1.49 16.19 25.60 1.35 30.91 30.75 30.72 2.51 120.31 30.30 755.02 2.750 2.875 2.875 2.875 2.875 2.875 2.750 3.000 2.250 3.000 4.281 BIT/RUN "1 21 3 WOB 5/10 ! 8~à;~00 r ~:~ I BIT OPERATIONS:' ' ~~:~~ I ::: I '=.~~'r'24::'~ST !'2~:~~~P I CU:'9~RS I CU~~~~TH 1 ç;:~~p M.D. ", INCL. 5,285.55 51.440 5,380.22 51.060 5,472.49 50.680 AZIMYTH 250.590 248.950 249.600 SURVEY DATA T.V.D. NIS CUM E/W CUM SECT10N M.D. 4,048.53 -1,358.4 -2,514.4 2,854.81 5,565.43 4,107.78 -1,383.9 -2,583.7 2,928.29 5,658.67 4,166.01 -1,409.2 -2,650.6 2,999.60 5,751.51 INCL. 50.960 50.680 50.260 AZIMUTH 246.200 246.830 246.410 T.V.D. NISCUM EIW CUM SECT10N 4,224.74 -1,436.3 -2,717.3 3,071.48 4,283.65 -1,465.1 -2,783.6 3,143.70 4,342.74 -1,493.5 -2,849.4 3,215.25 ... PUMP I HYDRAULIC , DATA ' , I STROKE (in) I LINER (In) I SPM I Q(gpm) I PRESS. (psi) I TOTALQ I I 12.000 6.000 110 465.31 1,700 465.31 KILL SPM / PRESSURE NO. I 1 Emsco MAKE OF PUMP ~c3ð- Printed: 7/21/2003 1 :46:01 PM e e Page 2 of 2 1 B-20 ConocoPhillips, Alaska Daily Drilling Report 1 JOB NUMBER 1 EVENT CODE 124 HRS PROG I TMD ODR 620.0 5,850.0 ITVD IDFS 4,406.0 5.00 I REPT NO. 1 DATE 6 7/15/2003 WELL NAME .., - ",._" ."...,-,-,.,_.,.__.,. . -.- -... -. ........ .... .-- .......... DESCRIPTION . .. .. ......._. .___n.. ......._...._.__.____.......... ... Nipple up FMC Gen 5 Wellhead & test to 1000 psi -OK. Nipple up BOPE. Install test plug, Test all valves & BOPE to 5000 psi & Hydril to 3500 psi, Test waived by AOGCC Jeff Jones, Remove test plug, Install wear bushing. Derrick Inspection, Service top drive. Make up & Program BHA #3, Surface test same. RIH & tag float collar @ 5139' Circ. fl casing test Test 9-5/8" casing to 3500 psi f/30 -OK, Record test on chart. Drill out float collar @ 5139', Cmt, Shoe @ 5221',20' of new hole to 5250' Circ & Balance mud weight to 9.3 ppg Perform F.I.T wI 9.3 ppg mud, 1450 psi, 4010' TVD = 16.3 ppg EMW Drill fl 5250' to 5850' (TVD 4406'), ART = 4.4 hrs AST = 0.3 hrs, UP 190K, DN 107K, ROT 131K, TO 15on/140ff 24 HR SUMMARY: NIU & test FMC wellhead, NIU & test BOPE, Make up BHA, RIH to 5139', Test csg to 3500 psi -OK, Drill out shoe track & hole to 5250', Perform FIT to 16.2 ppg, Drill to 5850' FROM! TO HOURS ~ CODE ¡TROUBLE; SUB . . ... ------......-.. 00:00 00:30 0.50 WELCTL P 00:30 02:30 2.00 WELCTL P 02:30 07:30 5.00 WELCTL P c;>.~.çBATIONS SUMMAFW. . .-----.-.. ..-.--.- NUND NUND BOPE ! PHASE ' INTRM1 INTRM1 INTRM1 07:30 08:00 0.50 RIGMNT P RSRV INTRM1 08:00 10:00 2.00 DRILL P PULD INTRM1 10:00 12:00 2.00 DRILL P TRIP INTRM1 12:00 12:30 0.50 DRILL P CIRC INTRM1 12:30 13:30 1.00 DRILL P DEOT INTRM1 13:30 14:45 1.25 DRILL P DRLG INTRM1 14:45 15:45 1.00 DRILL P CIRC INTRM1 15:45 16:30 0.75 DRILL P FIT INTRM1 16:30 00:00 7.50 DRILL P DRLG INTRM1 COMPANY ConocoPhillips Company Doyon Drilling Inc Doyon Universal Service SERVICE PERSONNEL DATA NO. HOURS COMPANY 2 Baker Hughes Inteq 29 APC - Alaska Petroleum 5 M-I Drilling Fluids SERVICE NO. HOURS 4 2 2 ITEM UNITS gals gals USAGE 1,760 320 MATERIALS I CONSUMPTION ON HAND ITEM 6,710 Water, Drilling 1,840 Water, Potable UNITS bbls bbls USAGE 265 65 ON HAND 575 119 Fuel Camp Fuel .......-.........----. .___. .__.._______._._. n_.___._______. ... .....-..-.---...--. . RESERVOIR AND INTERVAL DATA . ..-..---... . ..........-- .............. ZONE TOP ; BASE .¡-----. 296 0 I .. .--. ---. ---- . .--.. - --.- .--. .... - RESERVOIR NAME 1-Fi"-1-8- .. - .-.-.-..... -1'B-20 COMMENTS . ..---.-...--. -...--. .--.. --.--...- - ---. ------..-... . Printed: 7/21/2003 1:46:01 PM - ,31- I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD I DFS ODR 1,637.0 7,487.0 5,565.0 6.00 I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Doyon 141 Kuparuk River 8,635.0 0 ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD Drill 8-1/2' hole to 7974' 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL TD 8-1/2" hole, Wipr hole, POOH & Run 7" Cs,. 7/11/2003 135,996 LITHOLOGY I JAR HRS OF SERVICE BHA HRS SINCE INSP I LEAKOFF AFE 16.26 10029900 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST 7/16/2003 7,421.84 34.930 246.670 9.625 (in) @ 5,221.7 (ft) 7.000 (in) @ 8,008.0 (ft) 7/15/2003 DENSITY(ppg) I 9.70 I PP I ECDI IMUD DATAl DAILY COST I 0 I CUMCO$T ! 0 FV 1 PVNP I GËi:.s I WUHTHP FClT.SOL OIUWAT I %SandlMBT I Ph/pM PflMf '·'1 CI I CIi".¡ H2S I LIME I ES 62 19/29 16/35 3.61 I 11 I I 122.5 9.01 I e ConocoPhillips, Ala~ka Daily Drilling Report WELL NAME 18-20 SUPERVISOR I RIG NAME & NO. Fred Herbert/Mike Thornt n1334@ppco.co CURRENT STATUS n.. ..___.._.___.... .. ..--.--- --.. BHA NO. 3 -... . ... -..-. .... - .---------. ..... BHA WT. BELOW JARS SlRlNG WT. UP --·'---·--"-"'13 ·"-l-·"- 215 ----r.. ITEM DESCRIPTION B~~l!!º.b~ ..C;:ONDITIONS STRING WT. DN SlRlNG WT. ROT 126 .......-r...·-..----·---·1S8 e Page 1 of 2 I REPT NO. I DATE 7 7/16/2003 I CUM. TANGO CUM INT ANG WI MUD o CUM COST WI MUD 1,306,796 AUTH. I BIT NO. 2 ..____1 TORQUE/UNITS BHALENGTH r.....-..-----:¡B":·ööo fi:ïbf·---·· 1--.... ..........1-:ë>s3:46..-.. ...... . BIT HCM605 MACH 1 XL MTR NON-MAG STAB CROSSOVER MPR MWD CROSSOVER NMCSDP NMCSDP NMCSDP CROSSOVER HWDP JARS HWDP DRILL PIPE "G-105" NO JTS LENGTH O.D. I.D. CONN SIZE CONN TYPE 1 1.00 8.500 2.000 1 31.56 8.375 1 5.75 8.375 2.750 1 1.49 6.250 2.875 1 16.19 6.750 1 25.60 6.750 1 1.35 6.000 2.875 1 30.91 5.000 2.875 1 30.75 5.000 2.875 1 30.72 5.000 2.875 1 2.51 6.750 2.750 4 120.31 5.000 3.000 1 30.30 6.187 2.250 25 755.02 5.000 3.000 5.000 4.281 BIT I RUN !' SIZE I" MANUF. 2 I 3 8.500 I HC BITS I TYPE ·1 SERIAL N°'1 JETS OR TFA' HCM60~' , 7102575 12/12/13/13/131 n.__._____... _ .......-.---.... B,I.I.º_F.'..E:~A TIONS PRESS; P BIT HRS 2,45OT-" 665 I 17.70.....1 ,SURVEY DATA AZIMUTH T.V.D. NIS CUM EIW CUM$ECTlON M.D. 247.570 4,401.97 -1,521.3 -2,914.7 3,286.19 6,678.83 247.210 4,462.26 -1,548.4 -2,979.8 3,356.62 6,771.30 247.690 4,523.45 -1,575.1 -3,044.2 3,426.16 6,864.37 247.040 4,585.37 -1,601.9 -3,108.4 3,495.65 6,957.94 245.990 4,647.28 -1,629.3 -3,171.5 3,564.43 7,050.28 246.800 4,709.08 -1,656.6 -3,233.8 3,632.38 7,143.14 246.680 4,771.28 -1,683.9 -3,297.4 3,701.50 7,236.84 247.550 4,832.23 -1,710.6 -3,360.7 3,770.12 7,329.13 246.310 4,895.52 -1,738.2 -3,425.4 3,840.44 7,421.84 -----......... . I' J" DEPTH IN DATE IN " I-O-D-L-B·G-Q-R 5,230.0 7/15/200 1-1-CT-S-D-1-WT-TD ..-..-.---.-,-----.-....----- 24Hr DIST ·24H~·RÕp·_·¡-CÜï\4 "HRS ;t=u,,-õ-EP"iïiTcü..ooÄop "1,637'.-0"""1 92.49·-·-r-22·'-6"Ö· -l"·Ù57.0 ..., 99.87 BIT / RUN ..----....... 21 31 WOB 5/20 RPM GPM 1100 i 1-1'Õ-"'S26 M.D. 5,843.99 5,936.78 6,029.49 6,122.64 6,215.22 6,307.10 6,400.14 6,491.98 6,586.65 "INCL. 50.080 48.880 48.510 48.170 47.900 47.560 48.530 48.320 47.760 ',INCL. 46.710 46.400 45.030 43.540 42.140 40.250 38.520 36.830 34.930 -3Z- AZIMUTH . 250.410 251.370 250.940 250.510 250.320 250.200 249.500 248.350 246.670 , , TN.D. NIS CUM EIW CUM SECTION 4,958.13 -1,763.1 -3,488.3 3,907.92 5,021.72 -1,785.1 -3,551.8 3,974.61 5,086.70 -1,806.6 -3,614.8 4,040.76 5,153.68 -1,828.2 -3,676.5 4,105.67 5,221.39 -1,849.2 -3,735.6 4,168.10 5,291.26 -1,869.9 -3,793.2 4,228.93 5,363.68 -1,890.4 -3,849.0 4,288.10 5,436.72 -1,910.6 -3,901.6 4,344.31 5,511.84 -1,931.4 -3,951.8 4,398.56 Printed: 7/21/2003 1:45:36 PM WELL NAME NO. I 1 Emsco 1 B-20 MAKE OF PUMP e e ConocoPhilHps, Alaska., Daily Drilli119 Report , , I JOB NUMBER I EVENT CODE 124 HRS PROG I TMD ODR 1,637.0 7,487.0 Page 2 of 2 ... . ~ TVD DFS 5,565.0 6.00 I REPT ~O. I DATE 7/16/2003 PUMP {HYDRAULIC DAtA' ISTRQKE(ill)! LINER (in) I' SPM I Q(gpm) '·IPRESS.(PSi)l>rOTALQ,,1 12.000 6.000 124 524.54 2,450 524.54 FROM 1 TO 'HOURS: - - ------.. --.... 00:00 12:00 12.00 .. . ..... ...._ _.. .__..___.____......._...9PERATIONS SUMMARY CODE TROUBLE. SUB PHASE I _ _ . _ . . . --.---.--..- .--..... .... DRILL P DRLG INTRM1 . . - - ...-----".'"-"-... . 12:00 00:00 12.00 DRILL P 24 HR SUMMARY: Drill f/5850' to 7487' COMPANY ConocoPhillips Company Doyon Drilling Inc Doyon Universal Service ITEM Fuel Camp Fuel RESERVOIR NAME 1 R-18 SERVICE, UNITS gals gals 11 B-20 KILL SPM I PRE,SSURE .,..'''..n.''.._.'._n_.'...,_.._,. .....__.__.. _ _. .... n.... ._...__.__,_______.... DESCRIPTION __n... ....... ... .....___._....._...... Drill fl 5850' to 6930' (TVD 5132') AST = 0.9 hrs. ART = 7.9 hrs, UP 21 OK, DN 116K, ROT 148K, TQ 10-15 on 116-18 off, 10-20 WOB, 100 RPM, 506 GPM @ 2400 psi, Pump Hi-vis sweeps as needed Drill f/6930' to 7487' (TVD 5565') AST = 1.7 hrs. ART = 7.2 hrs, UP 215K, DN 126K, ROT 158K, TQ 11-18 on 112-17 off, 5-10 WOB, 100-110 RPM, 523 GPM @ 2450 psi, Pump Hi-vis sweeps as needed DRLG INTRM1 PERSONNEL DATA " NO. HOURS COMPANY 3 Baker Hughes 'nteq 29 APC - Alaska Petroleum 5 M-I Drilling Fluids USAGE 2,970 240 MATERIALS I CONSUMPTION ON HAND ITEM 3,740 Water, Drilling 1,600 Water, Potable , ,."RESERVOIR AND INTERVAL DATA ZONÈ, , I TO:801 BASE 0 I' -33- SERVICE NO. HOURS 4 2 2 UNITS bbls bbls USAGE 645 114 ON HAND 635 324 COMMENTS Printed: 7/21/2003 1 :45:36 PM - Page 1 of 2 ConocoPhillips, Alaska Daily Drilling Report 1 B-20 SUPERVISOR 1 RIG NAME & NO. Fred Herbert/Mike Thornt n1334@ppco.co CURRENT STATUS 1 JOB NUMBER I EVENT CODE 124 HRS PROG ODR 528.0 1 FIELD NAME I OCS NO. Doyon 141 Kuparuk River ACCIDENTS LAST 24 HRS.? TMD ITVD IDFS 8,015.0 6,033.0 7.00 AUTH MD I DAILY TANG 8,635.0 0 DAILY !NT WIO MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 7/17/2003 109,246 I LEAKOFF AFE 16.26 10029900 1 NEXT CASING 5,221.7 (ft) 7.000 (in) @ 8,008.0 (ft) I REPT NO. 1 DATE 8 7/17/2003 ICUM. TANGO CUM INT ANG WI MUD o CUM COST WI MUD 1,416,042 WELL NAME Running 7" casing. 24 HR FORECAST Run & cmt 7' csg., UD 5" DP, PIU 4-3/4" BHA & 4" DP LITHOLOGY 1 JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM 1 LAST CASING 7/17/2003 8,015.00 24.570 246.740 9.625 (in) @ AUTH. LAST BOP PRES TEST 7/15/2003 ........... _._______u. .. __.. ..- .... .---------. .. BHANO. ¡ 3 . .. ...---.---... ............... BHA WT. BELOW JARS STRING WT. UP 13 245 DENSITY(ppg) ...~g:..~9_ ..___.,~~..; __.m.... .. ..ECD MUD DATA, DAILY COST ! ~________.____.~~MCOST FV PVNP. GELS: WUHTHP Fcrr.SOL' OIUWAT . %Sand/MBT Ph/pM PflMf CI Ca '66 I 22/29 [ 16/26 I . 3.6i '''-]'' ·1T-·..-r·.... ·.....T.... 122.5 . 9:Õï" "'T'-"'-ï--' 'r' "".,_.... . .....-- BHA I HOLE CONDITIONS . ............-.. .........--..--.... ... STRING WT. DN STRING WT. ROT 130 156 o H2S l LIME. ES I [oo ........-........---... .-- : BIT NO. ____.. _?.__....... BHA LENGTH 1,083.46 TORQUE / UNITS __n_______._._.__ n.... 18,000 ft-Ibf BIT HCM605 1 1.00 8.500 2.000 MACH 1 XL MTR 1 31.56 8.375 NON-MAG STAB 1 5.75 8.375 2.750 CROSSOVER 1 1.49 6.250 2.875 MPR 1 16.19 6.750 MWD 1 25.60 6.750 CROSSOVER 1 1.35 6.000 2.875 NMCSDP 1 30.91 5.000 2.875 NMCSDP 1 30.75 5.000 2.875 NMCSDP 1 30.72 5.000 2.875 CROSSOVER 1 2.51 6.750 2.750 HWDP 4 120.31 5.000 3.000 JARS 1 30.30 6.187 2.250 HWDP 25 755.02 5.000 3.000 DRILL PIPE "G-105" 5.000 4.281 BIT/RUN I 21 3' SIZE 'I MANUF. 8.500 HC BITS I TYPE' I SERIAL NO. I HCM605 7102575 I JETS OR TFA 12/12/13/13/13/ DEPTH IN DATE IN I I-O-D-L-B-G-o-R 5,230.0 7ï15/200~ 1-1-CT-S-D-1-WT-TD BIT/RUN I 21 3 I WOB 5/10 BIT OPERATIONS 111 ~~~ 10 I ~:: I :~::: I ~:~T I :.~~ I 24:;:'~ST I 2~~;~~P C~~.:S I é;~~:~TH I C~: :~P M.D. 7,514.28 7,606.43 7,699.96 7,792.55 : INCL. 32.530 30.050 28.430 26.130 AZIMUTH 248.700 248.780 248.710 248.330 SURVEY DATA T.V.D. NIS CUM EIW CUM SECTION M.D. 5,588.72 -1,950.9 -3,999.3 4,449.79 7,885.68 5,667.46 -1,968.3 -4,043.9 4,497.50 7,947.76 5,749.07 -1,984.8 -4,086.5 4,543.05 8,015.00 5,831.35 -2,000.4 -4,126.0 4,585.37 INCL. 25.360 24.570 24.570 AZIMUTH 247.570 246.740 246.740 T.V.D. NISCUM EIW CUM SECTION 5,915.24 -2,015.6 -4,163.5 4,625.74 5,971.52 -2,025.7 -4,187.6 4,651.90 6,032.67 -2,036.8 -4,213.3 4,679.84 . . . .. --- -........- ...... . ........-.... --..--....... -... .... - ..--...---.. . FROM: TO ; HOURS i . ........-.-..... 00:00 06: 15 6.25 ... ..... . _... _.___............ _....PPERAT10NSß_~M_M.ARy_ ....___.._.._._.____...... _._ __._... CODE TROUBLE SUB PHASE DESCRIPTION ____.___... ._. .._ ._n..._ ..... .......... .. DRILL P DRLG INTRM1 Drill f/7487' to 7974' AST = 1.0 hrs ART = 3.4 hrs, WOB 15K, RPM 110, 523 GPM @ 2850 psi, UP 230K, DN 133K, ROT 169K, TQ 13-19 off 112-18 on. Printed: 7/21/2003 1:45:13 PM -Jf- e e Page 2 of 2 18-20 ConocoPhillips, Alaska Daily Drilling Report 1 JOB NUMBER I EVENT CODE 124 HRS PROG 1 TMD ODR 528.0 8,015.0 ITVD IDFS 6,033.0 7.00 IREPTNO. 1 DATE 8 7/17/2003 WELL NAME OPERATIONS SUMMAAY FROM TO HOURS CODE 'TROUBLE SUB 'PHASE DESCRIPTION .,' 06:15 06:30 0.25 DRILL P CIRC INTRM1 Circ for Geologist & E-mail logs to office. 06:30 07:00 0.50 DRILL P DRLG INTRM1 Drill f/7974' to 8015' AST= 0 hrs ART=.5 hrs, WOB 15K, RPM 110,523 GPM @ 2850 psi, UP 230K, DN 133K, ROT 169K, TQ 13-19 off 112-18 on. 07:00 09:30 2.50 DRILL P CIRC INTRM1 Pump Hi-vis weighted sweep, Circ 3 btm's up & hole clean at rate of 530 GPM @ 2700 psi, Monitor well, Pump dry job. 09:30 12:30 3.00 DRILL P WIPR INTRM1 Wipe hole to shoe @ 5222' - Hole in very good shape, Precautionary ream btm 60' - No fill. 12:30 14:45 2.25 DRILL P CIRC INTRM1 Circ. btm's up - trip gas 437 units, Pump Hi-vis weighted sweep, Raise mud weight to 10.1 ppg. 14:45 16:15 1.50 DRILL P WIPR INTRM1 Wipe hole to 7100', Observe well- OK, RIH to 8015' 16:15 17:30 1.25 DRILL P CIRC INTRM1 Circ. btm's up - trip gas 70 units. 17:30 23:00 5.50 DRILL P TRIP INTRM1 Monitor well, Dry pipe, POOH to BHA (Hole in good shape) 23:00 00:00 1.00 DRILL P PULD INTRM1 Lay down 2 jts HWDP, Jars, 3 jts CSDP, Break bit, Down load MWD, Lay down BHA 24 HR SUMMARY: Drill f/7487' to 8015', Circ clean, Wipe hole to shoe, Circ clean- trip gas 437 units, Raise mud weight to 10.1 ppg, Wipe hole 7100', Circ clean- trip gas 70 units, POOH & UD BHA. COMPANY ConocoPhillips Company Doyon Drilling 'nc Doyon Universal Service SERVICE PERSONNEL DATA NO. HOU,RS, COMPANY 3 Baker Hughes Inteq 29 APC - Alaska Petroleum 5 M-I Drilling Fluids SERVICE NO.< HOURS' 4 2 2 ITEM UNits gals gals USAGE 2,090 460 MATERIALS I CONSUMPTION ON HAND ITEM 7,150 Water, Drilling 4,640 Water, Potable UNITS bbls bbls USAGE 315 91 ON HAND 520 233 Fuel Camp Fuel .......... ........ ........----.--- --... .. ...-.--,----... . RESERVOIR AND INTERVAL DATA ...... .--...--...... .. . ... ZONE TOP BASE . i --... 220' f 0 I COMMENTS RESERVOIR NAME 1 R-18 1 B-20 Printed: 7/21/2003 1:45:13 PM -3~- -- /~ Page 1 of 2 ConocoPhillips, Alaska Daily Drilling Report 1 B-20 SUPERVISOR 1 RIG NAME & NO. Fred Herbert/Mike Thornt n1334@ppco.co CURRENT STATUS I JOB NUMBER I EVE~DC~DE 124 HRS PROG 1 FIELD NAME I OCS NO. Doyon 141 Kuparuk River ACCIDENTS LAST 24 HRS.? TMD ITVD IDFS 8,015.0 6,033.0 8.00 AUTH MD 1 DAILY TANG 8,635.0 0 DAILY INT WIO MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 7/17/2003 262,640 I LEAKOFF AFE 10029900 I NEXT CASING LAST BOP PRES TEST 5.500 (in) @ 8,635.0 (ft) 7/15/2003 o !;ÇUM COST I 0 Pf~f CI r Ca I H2S I LIME I 1 REPT NO. 1 DATE 9 7/18/2003 1 CUM. TANGO CUM INTANG WI MUD o CUM COST WI MUD 1,678,682 WELL NAME Lay down 5" drill pipe 24 HR FORECAST LID 5" DP, PIU 4-3/4' BHA & 4" DP, Drill out, LOT, Drill LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM 1 LAST CASING 7/17/2003 8,015.00 24.570 246.740 7.000 (in) @ 8,005.6 (ft) DENSITY'(ppg) 10.10 I PP i IECD IMUD DATAl DAILY CO$" :: I ~;:l'::~~sr W~~P I FC~~SOL I OIu;'AT I %S;1";;BT I P:~PA AUTH. ES OPERATIONS SUMMARY FROM TO ' HOURS , CODE TROUBLE SUB PHASE DESCRIPTION 00:00 00:30 0.50 DRILL P PULD INTRM1 Clear rig floor of drilling tools. 00:30 01:30 1.00 WELCTL P EQRP INTRM1 Change top pipe BOP rams to 7", Test rams to 250 low & 5000 high. 01:30 03:00 1.50 CASE P RURD INTRM1 Rig up Frank's fill up tool & 7' casing tools. 03:00 05:45 2.75 CASE P RUNC INTRM1 PJSM, Run 7", 26#, L-80, BTCM casing to 2500' at rate of 50/60 ftImin.- no problems. 05:45 06:00 0.25 CASE P CIRC INTRM1 Break circ. @ 2500' at 4 bpm @ 300 psi. 06:00 09:00 3.00 CASE P RUNC INTRM1 Run 7', 26#, L-80, BTCM casing to 5221' at rate of 50/60 ftImin.- no problems. 09:00 10:00 1.00 CASE P CIRC INTRM1 Circ. casing volume @ 5221' at 5 bpm @ 600 psi circ total of 241 bbls, No mud lost. 10:00 13:45 3.75 CASE P RUNC INTRM1 Run 7",26#, L-80, BTCM casing to 8005' (Total of 194 jts.) at rate of 45 ftImin.- no problems, Make up landing joint, Land casing in hanger & shoe @ 8005.65'. 13:45 14:15 0.50 CASE P RURD INTRM1 Rig down Frank's fill up tool, Rig up Dowell cement head. UP 237K, DN 122K 14:15 18:30 4.25 CEMENT P CIRC INTRM1 Work pipe & circ. (Had trouble staging pump rate up), Slowly stage rate up from 1 bpm @ 550 psi to 6 bpm @ 550 psi, Condition mud from MW 10.4 ppg, vis 71, PV 25, YP 34, gels 20/41, FL 3.2, PH 9.3, Condition mud to MW 10.0, vis 42, PV 12, YP 14, gels 6/11, FL 3.8, PH 8.9, Held PJSM for cmt job. 18:30 20:00 1.50 CEMENT P PUMP INTRM1 Switch to Dowell, Mix & pump 10 bbls CW100, Pressure test lines to 3500 psi, Continue mix & pump 20 more bbls of 8.3 ppg CW1 00 at rate of 5.1 bpm @ 530 psi, Followed by 30 bbls 11.2 ppg MudPUSH at rate of 5.0 bpm @ 530 psi, Shut down, Drop btm plug, Mix & pump 201 sxs (41.7 bbls) Class 'G' cmt. wI .200%D46, .300%D65, .350%D167, .050%B155 mixed at 15.8 ppg at rate of 5.0 bpm @ 675 psi, Shut down, Drop top plug, Displace cmt. w/1 0 bbls fresh water followed by total of 290.9 bbls 10.0 ppg mud at rate of 6.0 bpm @ 700 psi, Slowed rate to 3.0 bpm @ 550 psi for last 16 bbls of displacement, Bumped plug wI 1200 psi, CIP @ 2000 hrs. 7/18/03, Had good circ. thru out job, Floats held -OK, Worked csg. through out job, No noticeable mud loss, Well static. 20:00 21:30 1.50 CEMENT P PULD INTRM1 Rig down Dowell cmt. head, Landing joint, Csg. tools. 21:30 22:30 1.00 WELCTL P NUND INTRM1 Install FMC 11" x 7" Pack off, Test same to 5000 psi fl min.- OK 22:30 00:00 1.50 RIGMNT P RSRV PROD Slip & cut drilling line 78', Adjust brakes on drawworks, Start changing rams on BOP to 4", Load pipe shed wI 246 jts 4' drill pipe. 24 HR SUMMARY: Change BOP rams to 7", Rig & run 7' csg to 8005', Circ & cmt. 7" csg, Set 7" pack off, Slip & cut Drilling line, Change BOP rams to 4". Printed: 7/21/2003 1 :44:49 PM - ð¿b - WELL NAME 1 B-20 ... --. .. . .... -. .-------..... .-. - ... COMPANY SERVICE .....-....--..-...... ConocoPhillips Company Doyon Drilling Inc Doyon Universal Service ITEM ; ,,uNITS " gals gals Fuel Camp Fuel 1 R-18 RESERVOIR NAME ,,¡ '11 B-20 it e Conoc()Phillips, Alaska DailyD,rilling Report IJOB NUMBER IEVE~Dc~DE 124 HRS PROG IT~~015.0 . . .....-.....-...-... ... PERSONNEL DATA ITVD IDFS 6,033.0 8.00 NO. 3 29 5 .. .....-.-.---.-----..--- -..---...---...-. .. . - . . HOURS .' COMPANY SERVICE . .. _ no __._..._ ._....._..___.____.________._________.___ Baker Hughes Inteq APC - Alaska Petroleum M-I Drilling Fluids I I MATERIALS I CONSUMPTION ON HAND ITEM 5,995 Water, Drilling 4,400 Water, Potable USAGE 1,155 240 RESERVOIR'AND1NTERV AI...''DATA ZONE I ro:90 I ,BASE 0 I:: -37- UNITS bbls bbls COMMENTS USAGE 440 92 Page 2 of 2 I REPT NO. I DATE 9 7/18/2003 . ....."."..-..,. ........ ..... .. . ............. . .. . ......-.-. NO. ! HOURS 4 2 2 ON HAND 410 272 Printed: 7/21/2003 1 :44:49 PM WELL NAME 1 B-20 SUPERVISOR I RIG NAME & NO. Fred Herbert/Mike Thornt n1334@ppco.co CURRENT STATUS - ConocoPhillips, Alaska Daily Drilling Report 1 JOB NUMBER 1 EVE~DC~DE 124 HRS PROG I FIELD NAME I OCS NO. Doyon 141 Kuparuk River ACCIDENTS LAST 24 HRS.? TMD ITVD IDFS 8,015.0 6,033.0 9.00 AUTH MD I DAILY TANG 8,635.0 0 DAILY INT WIO MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 7/17/2003 142,946 ILEAKOFF AFE 10029900 1 NEXT CASING 8,005.6 (ft) 5.500 (in) @ 8,635.0 (ft) Raise mud weight to 12.2 ppg 24 HR FORECAST Raise mud weight to 12.2 ppg, LOT, Drill to 8635' LITHOLOGY 1 JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 7/17/2003 8,015.00 24.570 246.740 7.000 (in) @ - ------. ECD :~UD DAT~: D..AI.~~_~~ST ! OIUWAT ! %Sand/MBT' Ph/pM I ¡ /17.5 r" "ã".õT . I BHA tHOLE CONDITIONS STRING WT. DN STRING WT. ROT Page 1 of 2 I REPT NO. I DATE 10 7/19/2003 1 CUM. TANGO CUM INT ANG WI MUD o CUM COST WI MUD 1,821,628 AUTH. LAST BOP PRES TEST 7/15/2003 o : LIME I I DENSITY(ppg) 10.00 PP -.... ..,....,_.. .--. . .......... .....--,-.----- FV : PVNP GELS: WUHTHP FCIT.SOL: "'--53" I' 1'4i18 I 8/24 1..-·-3.4/--..'"[-.... "1Ï' .. r o Pf/Mf CUM COST ¡ CI ,Ca H2S ..n-r r'" I BHA NO. I 4 I BHA WT. BELOW JARS' STRING WT. UP Bi-Cntr PDC CDS444 Mud Motor M1XL Short NMCSDP NM Stabilizer MAP/MPRlSDN MWD/UPA NMCSDP NMCSDP NMCSDP Crossover Drill Pipe - Heavy Wgt Jars Drill Pipe - Heavy Wgt Crossover Drill Pipe "S-135" BIT I RUN S7IZ.0EOO I'.D:PI MANUF., 3/4 BIT I RUN I 31 4 WOB I ., TORQUE I UNITS 1.32 7.000 30.07 4.750 10.00 3.500 2.250 5.68 4.750 2.250 38.12 4.750 23.03 4.750 30.98 3.438 2.250 31.03 3.750 2.625 30.94 3.500 2.750 2.49 4.875 2.500 122.84 4.000 2.563 29.98 4.750 2.250 767.53 4.000 2.563 2.03 4.938 2.875 4.000 3.340 ',BITS' I TYPE I SERIAL N°~"I JETS OR TFA CSD444 1963412 13/13/11/11/111 ES BIT NO. I 3 BHA LENGrH,' " 1,126.04 ~~:::'~N ;~::~oJ o_o__~_~_-D-L~B~G-o-R RPM I BIT OPERATIONS I ~~~ 1 ~~:: ' P BIT< I HRS 'I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP F_~OM ! 00:00 01:00 03:00 09:30 10:00 11:00 11:30 13:00 1.00 2.00 6.50 0.50 1.00 0.50 1.50 2.50 WELCTL P DRILL P DRILL P DRILL P DRILL P RIGMNT P DRILL P DRILL P . ___,__.__ no.. ()PERATIONS SUMMARY , HOURS' CODE TROUBLE SUB . PHASE --.-....-... -. ... .~. BOPE PROD OTHR PROD PULD PROD OTHR PROD PULD PROD RSRV PROD PULD PROD PULD PROD DESCRIPTION . ...... .. .....- .-----..-.--. Test top & btm 4" BOP rams to 250 psi low & 5000 psi high. Change saver sub to 4' on top drive, Clear rig floor. Lay down 5" drill pipe from derrick in mouse hole. Change over to 4' handling tools. Pick up 8 stands 4',14#, S-135, XT-39 drill pipe & stand back in derrick. Service rig & top drive Pick up 10 stands 4",14#, S-135, XT-39 drill pipe & stand back in derrick. Make up BHA #4, 6"x7" Bi-Center bit, Set motor to 1.2 AKO, Stab, MWD, Program MWD. TO 01:00 03:00 09:30 10:00 11:00 11:30 13:00 15:30 ...... ........... .._..._.__u_ -38- Printed: 7/21/2003 1:44:21 PM ,,- /~ 1 B-20 "',' ConócoPhiUips, Alaska Daily Drilling Report ,', JOBNUMBER EVE~Dc~DE 24HRSPROG T~~015.0 Page 2 of 2 WELL NAME ITVD DFS 6,033.0 9.00 REPT NO. DATE 10 7/19/2003 OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 15:30 17:30 2.00 DRILL Np PULD PROD Change out 2 of 6 blades on density tool due to over sized stand off & would not fit in 7" casing. 17:30 18:15 0.75 DRILL P PULD PROD PJSM, Load R.A. Sources 18:15 19:30 1.25 DRILL P PULD PROD Pick up 29 jts HWDP, Jars, RIH & Shallow test MWD @ 1200' 19:30 23:45 4.25 DRILL P PULD PROD Pick up 4",14#, S-135, XT-39 drill pipe to 7852' 23:45 00:00 0.25 DRILL P CIRC PROD Circ & wash f/7852 to 7888' (Tag hard cmt), 200 GPM @ 1600 psi 24 HR SUMMARY: Test 4" BOP rams to 5000 psi, Change saver sub, UD 5" DP, PIU 8 std's 4" DP, M/U BHA #4, P/U 4" DP to 7888', Circ btm's up. COMPANY ConocoPhillips Company Doyon Drilling Inc Doyon Universal Service SERVICE PERSONNEL DATA NO. HOURS COMPANY,' ," 3 Baker Hughes Inteq 29 APC - Alaska Petroleum 5 M-I Drilling Fluids SERVICE:' NO. HOURS 4 2 2 ITEM UNITS gals gals USAGE 1,155 240 MATERIALS I CONSUMPTION ON HAND ITEM 4,840 Water, Drilling 4,160 Water, Potable UNITS bbls bbls USAGE 30 100 ON HAND 610 272 Fuel Camp Fuel RESERVOIR NAME 1 R-18 118-20 RESERVOIR AND INTERVAL DATA ZONE I TOP I BASE I o 01 COMMENTS '" Printed: 7/21/2003 1:44:21 PM - fJ9 - TMD 1 TVD I DFS 8,105.0 6,114.0 10.00 AUTH MD I DAILY TANG 8,635.0 0 DAILY INT WIO MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL Drill to 8635' 7/17/2003 153,436 I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 16.03 10029900 INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST 24.570 246.740 7.000 (in) @ 8,005.6 (ft) 5.500 (in) @ 8,635.0 (ft) 7/15/2003 I PP I IECDI I MUD:DATA DAILYCOST I 0 I CUM COST I 0 W:~P FC:SOL ''ÞU¡AT I~::BT I ~~~~ 'Pf~ CI Ca ! H2S I LIME ES I - ConocoPhillips, Alaska Daily Drilling Report WELL NAME I JOB NUMBER I EVENT CODE 124 HRS PROG ODR 90.0 I RELD NAME I OCS NO. Doyon 141 Kuparuk River ACCIDENTS LAST 24 HRS.? 1 B-20 SUPERVISOR I RIG NAME & NO. Fred Herbert/Mike Thornt n1334@ppco.co CURRENT STATUS Drilling 6"x 7" hole @ 8147' 24 HR FORECAST LITHOLOGY LAST SURVEY: DATE TMD 7/17/2003 8,015.00 DENSITY(ppg) I 12.20 FV PVNP I GELS 54 20/27 12/22 BHANO. I 4 I BHA WT. BELOW JARS ·""STRING:WT.UP 10 172 BHA I HOLE 'SfRiNGWT. DN 122 , STRING WT. ROT 97 Bi-Cntr PDC CDS444 Mud Motor M1XL Short NMCSDP NM Stabilizer MAP/MPRlSDN MWD/UPA NMCSDP NMCSDP NMCSDP Crossover Drill Pipe - Heavy Wgt Jars Drill Pipe - Heavy Wgt Crossover Drill Pipe "S-135" 1.32 30.07 10.00 5.68 38.12 23.03 30.98 31.03 30.94 2.49 122.84 29.98 767.53 2.03 BIT I RUN 4"1' ", SIZE MANUF. 31 7.000 DPI BITS I SERIALNO. JETS OR TFA 1963412 13/13/11/11/111 I TYPE CSD444 BIT/RUN 31 4 BIT OPERATIONS PRESS P BIT I HRS I 24Hr DIST 2,150 188 11.20 90.0 I WOB 12/14 I RPM GPMI 80/100 220 .. -... . ---.. .---. --- - .. . ---...-. ... /~ 7.000 4.750 3.500 4.750 4.750 4.750 3.438 3.750 3.500 4.875 4.000 4.750 4.000 4.938 4.000 Page 1 of 2 I REPT NO. 1 DATE 11 7/20/2003 I CUM. TANGO CUM INT ANG WI MUD o CUM COST WI MUD 1,975,064 AUTH. TORQUE I UNITS '...'. 7,000 ft-Ibf BIT NO. I 3 BHA LENGTH 1,126.04 2.250 2.250 2.250 2.625 2.750 2.500 2.563 2.250 2.563 2.875 3.340 DEPTH IN DATE IN I I-O-D-L-B-G-O-R 8,015.0 7/19/200~ 0-0------ 24Hr ROP I CUM HRå CUM DEPTH I CUM ROP 8.04 11.20 90.0 8.04 PUMP I HYDRAULIC DATA ! STROKE (in) LINER (in); SPM Q (gpm) :'PRESS~ipSijrröTAL Q : '-'-KII:'L SPM I PR'ËSSUÄË 00. I 12.000 I 6.000 I 52 I 219.97 I 2,150 '1' ----219.97 I . .... .----..- .--.......... NO. MAKE OF PUMP 1 I Emsco FROM TO HOURS CODE 00:00 00:30 0.50 DRILL P 00:30 01:00 0.50 DRILL P 01:00 01:45 0.75 DRILL P 01:45 03:45 2.00 DRILL P 03:45 10:00 6.25 DRILL P , , . .", 'OPERATIONS SUMMARY TROUBLE SUB PHASE OTHR PROD CIRC PROD DEQT PROD OTHR PROD CIRC PROD , bEScFiIFmON Clean out cmt to float collar @ 7918' Circ. btm's up wI 200 GPM @ 1550 psi Rig & test 7" casing to 3500 psi fl 30 min. -OK Drill out float collar @ 7918', Cmt, Shoe @ 8005' and clean out to TD @ 8015' Circ & treat out cement contamination, Raise mud weight to 12.2 ppg using sack material. -/j,ð -- Printed: 7/21/2003 1 :43:54 PM WELL NAME 1 B-20 -.. ...-..--..-..-..........-...-.---- --.---....----........ FROM TO ; HOURS : CODE ..... .. . . .... 03:45 10:00 6.25 DRILL P 10:00 11:30 1.50 DRILL P 11 :30 12:30 1.00 DRILL P 12:30 13:15 0.75 DRILL P 13:15 14:00 0.75 DRILL P 14:00 00:00 10.00 DRILL P ConocoPhillips,Alaska Daily Drilling Report I JOB NUMBER I EVENT CODE 124 HRS PROG I TMD ODR 90.0 8,105.0 -- 'TROUBLE: SUB CIRC DRLG CIRC FIT CIRC DRLG Page:2 of 2 ITVD IDFS 6,114.0 10.00 I REPT NO. 11 I DATE 7/20/2003 . .--...... . OPER.I\:TJONS SUMMA..RV_..... ..__ .___.... .. . ...... ... . . PHASE ' DESCRIPTION .. .. ..n ... __._n PROD (Note; Unable to receive weighted spike fluid for raising mud weight due to Nordic #2 stuck in road between Kuparuk and Kuparuk river.) PROD Drill f/8015' to 8035' (TVD 6051') ART= 1.5 hrs, WOB 14K, RPM 80, 200 GPM @ 2250 psi, PU 175K, DN 92K, ROT 118K, TQ off 1 OK! on 8K Circ btm's up for Leak off test Perform F.I.T to 16.0 ppg EMW wI 1200 psi, 6024' TVD, 12.2 ppg mud Perform PWD base line tests for ECD clean hole = 13.7 ppg. Drill f/8035' to 8105' (6114' TVD) ART= 9.6 hrs, WOB 12K, RPM 100, 220 GPM @ 2150 psi, UP 172K, DN 97K, ROT 122K, TQ off 7K! on 7K, Max ECD's 13.85 ppg PROD PROD PROD PROD 24 HR SUMMARY: Clean out cmt. to 7918', Circ, Test csg to 3500 psi, Drill out shoe track & to TD 8015', Cric & weight up to 12.2 ppg, Drill to 8035', Circ btm's up, Perform FIT to 16.0 ppg, Drill to 8105' COMPANY ConocoPhillips Company Doyon Drilling Inc Doyon Universal Service ITEM UNITS gals gals Fuel Camp Fuel RESERVOIR NAME 1 R-18 SERVICE USAGE 1,870 240 <'PERSONNEL DATA NO. . HOURS COMPANY 3 Baker Hughes Inteq 29 APC - Alaska Petroleum 5 M-I Drilling Fluids SERVICE NO. HOURS 4 2 2 MATERIALS/CONSUMPTION ON HAND' ITEM 2,970 Water, Drilling 3,920 Water, Potable UNITS ' bbls bbls USAGE 70 109 ON HAND 600 287 ¡ 11 B-20 ,RESERVOIR AND INTERVAL DATA ZONE I" TO;OO IB.o.SE 01 COMMENTS Printed: 7/21/2003 1 :43:54 PM -·1';- e NOTE TO FILE e 18-20...203-115...303-204 Request for Annular Disposal Approval Summary ConocoPhillips (ConPPCo) has requested approval for annular disposal on the subject well. This is the 1 sl well to be drilled on 1 B pad since 1994. They have submitted the required information. This document analyzes the information and recommends approving their request. Offset Well Information NA-No offset wells were identified within % mile of the surface casing shoe of 1 B-20. Well 1 8-20 Information The surface casing was run and successfully cemented to surface. It is noted that over 190 bbls of cement were circulated. Based on spreadsheet calculations, gauge plus 58% XS cement was left in the well. It is indicated that the surface casing is adequately cemented. The casing was successfully pressure tested prior to drillout. When tested, the formation did not leak off at about 16.0 ppg EMW. During the 10-minute observation period, the pressure dropped about 50 psi. The well was drilled to the top of the Kuparuk reservoir and 7" casing string was set and cemented. On the injectivity test, the pressure builds steadily to about 950 psi when it sharply breaks. Approximately Y:1 bbl. Of mud is injected at about 1000 psi and the pressure continues to rise on a new slope ultimately reaching 1600 psi. After pumping was stopped, a 175 psi drop was recorded after 1 minute with a stabilized pressure of about 1300 psi being reached by the end of 5 minutes and declining for the remainder of the observation period to 1250 psi. These pressures are substantially higher than have been seen in other annuli at Kuparuk. According to the Drilling Supervisor, it appeared that the annulus was attempting to plug off. Subsequently, when the annulus was freeze protected it was necessary to "rock" and surge the pressure until sustained injection could be achieved. Please reference the attached pressure graph. While pumping in, the pressure is steady at between 1300 - 1400 psi. Based on a full column of 9.2 ppg mud, the EMW is 15.5 to 16.0 ppg. It should be noted that during this pumping operation, 60 bbls of diesel was pumped which is essentially half the capacity of the annulus. Allowing for the lightened hydrostatic because of the diesel, the EMW at completion of the pumping was 15.1. It is indicated that the surface casing is well cemented and that in the pumping operation conducted that fluids were contained in the open hole strata below the casing shoe. Recommendation Based on the presented information, I recommend that ConocoPhillips' request for annular disposal in 1 B-20 (203-115) be approved. t~~~ Sr. Petroleum Engineer M:\tommaunder\Well Information\By Subject\Annular Disposal\030629 _ 203-043--KRU _lB-20 _ AD.doc Pump Rate: ... 0.51 Bbljmin 1"'_ Pressure Integrity Testl Shut-in Min p~ o 1.11 0.25 1-~1'J 0.5 1 ~I.I'J 1 1~ 1.5 1-"""', 2 n,~ 2.5 1350 3 1350 3.5 4 4.5 5 5.5 6 6.5 7 7.5 8 8.5 9 9.5 10 Volume Input I... O. Casin'il Test PRESSURE INTEGRITY TEST nc, 7/26/2003 PHILLIPS Alaska, Date: Pump used 141 Doyon I Rig Fred Herbert I Pete Wilson 8-20 Wel Drilling Supervisor: Name: 1010 ... #1 Pumping down I annulus and DP. Mud Pump Bbls/5trk Barrels ... Pumping Bbls psi Shut-in Min psi Pumping Bbls psi Hole Depth 7,025 Ft-MD 5,203 Ft-TVD I... 1350 1325 1325 1300 1300 1300 1300 1300 1300 1275 1275 1275 ~. 300 500 650 800 950 950 1000 1100 1250 1350 1450 1550 600 0.2 0.4 0.6 0.8 1 1.1 1.5 2 2.5 3 3.5 4 4.1 ---- Pressure lntegritvTest Mud Weight: 9.3 ppg nner casing OD: 19.0 In. Hole Size: Casing Shoe Depth I RKB-CHF: 24.9 Ft 5,221 Ft-MD 4,010 Ft-TVD Casing Size and Description 19-5/8" 4O#/Ft L-BO BTC Adequacy Test 9.3 in comments 14.0 casing string. ... Annulus Leak Off Test for Disposal Adequacy Type of Test: .... 8-112' -, - -- -'hftrr -- o 3550 1 3550 2 3550 3 3550 4 3550 5 3550 6 3550 7 3550 8 3550 9 3550 10 3550 15 3400 20 3400 25 3400 30 3400 200 300 500 650 750 870 970 1110 1230 1350 1500 1700 1850 1950 2150 2300 2450 2625 2775 2925 3075 3200 3350 3550 -<. 0.2 0.4 0.6 0.8 1 1.2 1.4 1.6 1.8 2 2.2 2.4 2.6 2.8 3 3.2 3.4 3.6 3.8 4 4.2 4.4 4.6 4.8 131,000 35,000 16.0 ppg 1397 psi Desired PIT EMW: Estimates for Test: 3,500 casing 31,000 35,000 Changes for Annular Enter outer casing shoe te Casing Description referen Hole Size is that drilled bel Use estimated TOC for Ho Enter inner casing 00 at right -10.3 bbl 1....1 PIT 15 Second Shut-in Pressure, psi 1450 4010 + 9.3 13.9 950 0.052 x .... = = leak-off Pressure + Mud Weight 0.052 x TVD EMW at 5221 EMW (4010 Ft-TVD) Ft-MD ----------- - ... held .. -= Lost 150 psi during test, = 95.8% of test pressure. ",~·w..,,· ---" ... / ~ / ~/ ~ ~_,/' -T -r 4000 3500 3000 2500 2000 500 000 500 LIJ 0::: :::> V) V) LIJ 0::: 0.. VOlume Bled Back 2.5 Bbls ---- Volume Volume Bled Back 4.7 Bbls /-1-1- Volume 30 20 25 Minutes 10 Shut-In time, o PIT Point 15 5 o 6 5 4 3 Barrels 2 o o Pumped 4.1 Bbls Pumped 4.8 Bbls Outer annulus (9-5/8" X 7") -LEAK-OFF TEST Estimated top of cement 7025' MD. 5203' TVD. Mud weight 9.3 ppg. Hole size 8-1/2" .....CASING TEST Comments: e [Fwd: [Fwd: Doyon 141 Diverter Vent Line]-lB-20 (203-115)] . ep¡-~ Subject: [Fwd: [Fwd: Doyon 141 Diverter Vent Line]·1.B-.(1ø3-U~] Date: Fri, 11 Jul 2003 08:44:36 -0800 From: Jim Regg <jim Jegg@admin.state.ak.us> 1Ze4q 1 \lIl D3 Organization: AOGCC t To: John H Spaulding <john_spaulding@admin.state.akus> It John - G J..tS ree $ :J pr' Thanks for the note and photos. T9ffi and I agree that what CPA is proposing is appropriate (i.e.,.~ downturn for last 15 ft of diverter vent line); see below. Tom asked about mud gas logging capabilities - we are not requiring that from CPA for this approval but it would be in their best interest to gather info if they intend to request a waiver from diverter requirements for subsequent wells. Jim Regg Subject: Re: [Fwd: Doyon 141 Diverter Vent Line]-1B-20 (203-115) Date: Fri, 11 Jul 2003 08:34:26 -0800 From: Tom Maunder <tom_maunder@admin.state.akus> To: Jim Regg <jimJegg@admin.state.akus> Jim, I agree with the assessment and what is proposed for the diverter line at 141 for IB-20. This is the first well drilled on this pad since June 1994. It is not appropriate to waive the diverter to allow drilling the first well on this pad in nearly 10 years. Steve Shultz called me regarding this matter and we discussed that they also plan to drill 2 West Sak wells (IB-I02 and -101) at this site and asked how they might get the diverter waived for those wells. I asked if they would have any gas information from drilling the surface hole section of IB-20. He indicated that at the moment they didn't plan to gather gas information, however in the interest of gathering additional information to support their potential request to waive the diverter on the West Sak wells that they would discuss getting some mud gas logging capability. Do you want me to pass this note to John?? Tom Jim Regg wrote: > Tom - > > What ConocoPhillips is proposing seems to make sense and I believe is > consistent wi th the intent of our regs ("designed to prevent > freeze-up"). I recall from MMS diverter requirements (at least for AK) > that we insisted on a down turn in end of diverter line to ensure > drainage and prevent fluid freezing in the lines. ~should not create > any unusual flow resulting in erosion or plugging. I recommend : approval. tJ ~rel-S > Jim > > ------------------------------------------------------------------------ 0~f2- > > Subject: Doyon 141 Diverter Vent Line > Date: Fri, 11 Jul 2003 07:53:54 -0800 > From: John Spaulding <john_spaulding@admin.state.ak.us> > Organization: aogcc 100 7/11/20038:50 AM [Fwd: [Fwd: Doyon 141 Diverter Vent Line]-IB~20 (203-115)] , 200 e e > To: Jim Regg <jim_regg@admin.state.ak.us> > > Jim, > Attached are some photo's taken -earlier today of the diverter vent line > on Doyon 141 at Kuparuk's 1E pad. > > Initially the rig thought they could get under the flow line rack. When > testing there drilling spools and valve with water they encountered a > leak in the flange upstream of the knife valve on the vent line. I, upon > receiving a call from the contract company man went out to location and > took some photo's for consideration by the AOGCC professional staff. > > The company rep. has proposed for the last fifteen feet (15') being > turned down by approx. 5 degrees to go under the flow line. This would > be accomplished be removing and re-welding the flange at the 5 degree > angle. > > Mr. Randy Thomas will probably call this am requesting the proposal be > accepted. Please advise me as to what the decision is. > > Thank you, > jhs > > ------------------------------------------------------------------------ > [Image] [Image] [Image] [Image] [Image] [Image] > > John Spaulding <john_spaulding> > Petroleum Inspector > Alaska Oil and Gas Conservation Commission > > John Spaulding > Petroleum Inspector <john_spaulding> > Alaska oil and Gas Conservation Commission > Additional Information: > Last Name Spaulding > First Name John > Version 2.1 > > ------------------------------------------------------------------------ > > Jim Regg <jim_regg@admin.state.ak.us> > Petroleum Engineer > AOGCC > Administration > > > > > > > > > > > > > > Jim Regg Petroleum Engineer AOGCC Administration 333 W. 7th Avenue Suite 100 Anchorage AK 99501 USA Additional Last Name First Name Version Fax: 907-276-7542 Work: 907-793-1236 <jim_regg@admin.state.ak.us> Information: Regg Jim 2.1 7/11120038:50 AM [Fwd: [Fwd: Doyon 141 Diverter Vent Line]-lB-20 (203-115)] e "1 T.(.H!.)..~J.;lllndcr <tqm_nW~I!ldc(dadmill.~).a!,<:..ak.u~> i Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission ~....... .."................................ ........... ........ .......... .."....... ................. .................".."..... ,,,. Jim Regg <Jim rcgg:0'adl11ill.statc.ak.lIs> Petroleum Engineer AOGCC Administration 300 e 7111/20038:50 AM JPEG ima,ge 1024x768 pixels Subject: Doyon 141 Diverter Veut Line Date: Fri, 11 Ju12003 07:53:54 -0800 From: John Spaulding <john_spaulding@admin.state.ak.us> Organization: aogcc To: Jim Regg <jimJegg@admin.state.ak.us> Jim! Attached are some photo's taken earlier today of the diverter vent line on Doyon 141 at Kuparuk's 1B pad. Initially the rig thought they could get under the flow line rack. When testing there drilling spools and valve with water they encountered a leak in the flange upstream of the knife valve on the vent line. I, upon receiving a call from the contract company man went out to location and took some photo's for consideration by the AOGCC professional staff. The company rep. has proposed for the last fifteen feet (15') being turned down by approx. 5 degrees to go under the flow line. This would be accomplished be removing and re-welding the flange at the 5 degree angle. Mr. Randy Thomas will probably call this am requesting the proposal be accepted. Please advise me as to what the decision is. Thank you! jhs 10f6 7/11/2003 8:54 AM JPEG image 1024x768 pixels 2of6 7111/2003 8:54 AM JPEG image 1024x768 pixels 30f6 7/11/20038:54 AM JPEG image 1024x768 pixels 4of6 7/] ]/20038:54 AM JPEG iIDi!ge 1024x768 pixels John Spaulding Petroleum Inspector Alaska Oil and Gas Conservation Commission 50f6 7/11120038:54 AM . lID J !Æ~!Æ~~~!Æ . AI/ASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 333 W. 'fT" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Unit, IB-20 ConocoPhillips Alaska, Inc. Permit No: 203-115 Surface Location: 497'FNL, 823' FEL, SEC. 9, TIIN, RI0E, UM Bottomhole Location: 2639 FNL, 12' FEL, SEC 8, TIIN, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you trom obtaining additional permits or approvals required by law trom other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. This permit is approved subject to full compliance with 20 AAC 25.055. Approval to test or produce is contingent upon issuance of a conservation order approving a spacing exception. ConocoPhillips Alaska, Inc. assumes the liability of any protest to the spacing exception that may occur. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ;Il~Á-~ Randy R rich Commis lOner BY ORDER OF THE COMMISSION DATED this-3 day of July, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section Conoc~nnps . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: rlthomas@ppco.com """"", 11- ~r- t'(~{ r- '~"~·V'''n:?~ June 1 0,2003 JUN 2 0 2003 Sarah Palin, Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 AJeska Re: Application for Permit to Drill, producer 18-20 Dear Commissioner Taylor: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well, KRU 18-20, a development well. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). If you have any questions or require any further information, please contact Shane Cloninger at 265- 6829. Sincerely, \è-~\~' Randy Thomas GKA Drilling Team Leader ORIGINAL 1a. Type of Work: Drill [2] Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RedrillU 1b. Current Well Class: Stratigraphic Test 0 RECEI\/E jJ ~bc, JUN 2 0 2003 AiÐzka ExploratoryU Development Oil l:11nchorage Multiple Zone 0 Service 0 Development Gas 0 Single Zone [2] 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1B-20 6. Proposed Depth: 12. Field/Pool(s): MD: 8635' TVD: 6593' Kuparuk River Field 7. Property Designation: P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 497' FNL, 823' FEL, Sec. 9, T11 N, R10E, UM . Top of Productive Horizon: 2562' FNL, 181' FWL, Sec. 9, T11 N, R10E, UM Total Depth: 2639' FNL, 12' FEL, Sec. 8, T11 N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 549616 16. Deviated wells: Kickoff depth: 600 ft. 18. Casing Program Size y- 5969647 Zone- 4 (Height above GL): 28 feet Well within Pool: 1B-02.32.7' @ 926' 17. Anticipated Pressure (see 20 MC 25.035) Maximum Hole Angle: 50° Max. Downhole Pressure: 3923 psig I Max. Surface Pressure: 3227 psig Setting Depth Quantity of Cement Specifications Top Bottom c. I. or sacks Weight Grade Coupling Length MD TVD MD TVD (including stage data) 62.5# H-40 Weld 110' 28' 28' 138' 138' Pre-Installed 40# L-80 BTC 5185' 28' 28' 5213' 4015' 650 sx AS III Lite & 300 sx LiteCrete 26# L-80 BTC-M 7980' 28' 28' 8008' 6025' 190 sx Class G 15.5# L-80 Hydril 511 777' 7858' 5889' 8635' 6593' 130 sx Class G Hole 42" Casing 16" 12.25" 9.625" 8.5" 7" 7" 5.5" 19 Total Depth MD (It): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments: Filing Fee [2] Property Plat 0 ALK 25647 & 25648 8. Land Use Permit: ADL 466 & 465 9. Acres in Property: 2560 10. KB Elevation PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) Kuparuk River Pool 13. Approximate Spud Date: 7/25/2003 14. Distance to Nearest Property: 12' at TO 15. Distance to Nearest (To be completed for Redrill and Re-Entry Operations) I Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Cement Volume MD TVD Length Size BOP SketchD Diverter Sketch 0 I Perforation Depth TVD (ft): Drilling Program [2] Time v. Depth Plot 0 Seabed Report 0 Drilling Fluid Program [2] Date: 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Permit to Drill 2D3- lIS- Number: Conditions of approval : Other: Approved by: IL-~ Form 10-401 Revised 3/2003 . Shallow Hazard Analysis 0 20 AAC 25.050 requirements [2] R. Thomas Contact Shane Cloninger @ 265-6829 Title Kuparuk Drilling Team Leader Phone Date t /1 7/0 3 PreDared bv Sharon AI/suo-Drake ~ ~ COMMISSIONER () 1/\',1 f i ~ BY ORDER OF THE COMMISSION L .~~- I API Number: 50-0¿';- Samples required Hydrogen sulfide measures Commission Use Only 23/b c./'OC :::it~3/6 J DYes RNo Mud log required ~es 0 No Directional survey required ~5"()O((S\ tðCJ? ~"">~ \1""'-.'\~,\~'-.) 'f-"- Isee cover letter for other requirements DYes gJ ~ Yes 0 No No Date: 1/3/03 Submit in duplicate ) }cation for Permit to Drill, Well 1 8-20 Revision No.O Saved: 6/02/03 Permit It - Kuparuk Well 1 8-20 Application for Permit to Drill Document Table of Contents 1. Well Name................................................................... ............. .... .......... ........... ........ 2 Requirements of 20 AAC 25.005 (f)...................... ..................... ......... ....................................................2 2. Location Summary.. .................... ........ .............................. ..... ........................... ... .... 2 Requirements of 20 AAC 25. 005( c)(2) ................................................... ............................ ....................2 Requirements of 20 AAC 25. 050(b)................... ................................... ............................................ ...... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005( c)(3) ............................................... .................................................... 3 4. Dri II i ng Hazards Information ........................ .......................... .... ......... ... .... ..... ... ..... 3 Requirements of 20 AAC 25.005 (c)( 4) ...................................... .................................................. .....,....3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .......................... ................................................................. ....... 3 6. Casing and Cementing Program ............................................ .................................4 Requirements of 20 AAC 25. 005( c)(6) ............................. ...................................................................... 4 7. Diverter System Information............................... ..... ......... ...... ... ......... ............ ........ 4 Requirements of 20 AAC 25. 005( c)(7) ....................................................................................... ............4 8. Dri II i ng FI u id Program ........................... ..................................... ..................... ........ 4 Requirements of 20 AAC 25.005(c)(B) ............................................................................. ...................... 4 9. Abnormally Pressured Formation Information ......................................................5 Requirements of 20 AAC 25.005 (c)(9) .................................. ................................................................ 6 1 o. Se ism i c An a I ys is...................................................................................................... 6 Requirements of 20 AAC 25.005 (c)(1 0) ................................................................................................ 6 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 12. Evidence of Bond i ng ............ ........ .......... ......... ........... ... ... .............. ... .... ....... .... ....... 6 Requirements of 20 AAC 25.005 (c)(12) .................................................................................................6 O rO\ " "~', ~ '" ", 1 " ¡'1,; I 1\ '.7 ; ïi.",\ :. « . \.,j !,~ I, ,~ 18-20 PERMIT IT. DOC Page 1 of 7 Printed: 10-Jun-03 18-20 PERMIT IT. DOC Page 2 of 7 Printed: 10-Jun-03 8,635' 6,593' 6,504 8,322' 6,310' 6,221' 8,145' 6,149' 6,060' 28,0' AMSL 61.0' AMSL " tl~.mr O P:),' ,,~I', 1 :~ , . ¡.J~ ,I, (: ì I, ' , lid :' ,"'; " I 1 , ~Ji',~ ~ ~ See 08, T11N, Rl0E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: Location at Total Depth I 2639' FNL, 12' FEL, NGS Coordinates Northings: 5,967,478 Eastings: 545,167 ~ation for Permit to Drill, Well 1 8-20 Revision No.O Saved: 6/02103 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: Eastings: 545,289 2590' FNL, 111' FWL, See 09, TllN, Rl0E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: Eastings: 545,359 Location at Top of Productive Interval (Kuparuk "A" Sand) NGS Coordinates Northings: 5,967,527 Location at Top of Productive Interval (Kuparuk "C" Sand) NGS Coordinates Northings: 5,967,555 Location at Surface NGS Coordinates Northings: 5,969,647 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must: be a{x:ompanied by ead¡ of the lollOfI'¡jng t!em5~ except tÒr an Item already on file with the mmmis:sion and identitìeä in the application: (2) if plat identifying the property and the p¡vperly's owners and showing (A)the coordinates of'the proposed loc'ation of the well at the 5'Ulfc¡a~ at the top of eacf¡ objective rÓrmatiol7/ and at total d{;'pth referenced to governmental section Ili7es. (B) the coordinates of the proposed location of the well at the surféc~ referenced to the state plane coordinate sy.<;tem for this state as maintained by the Natìonal Geodetic Survey li7 the National Oceanic and Atmospheric Administration; (q the proposed depth of the well at the top of ead7 objective formation and at total depth' 2562' FNL, 181' FWL, See 09, Tl1N, Rl0E, UM 1497' FNL, 823' FEL, See 09, TllN, Rl0E, UM RKB Elevation Eastings: 549,616 Pad Elevation 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identiried by a unique name designated by tile operator and a unique API number 3s:.s"'/gned by the commission under 20 AAC 2!i.040(b). For a well with mullïfJ/e well brancl7es~ each branch must sirmïady be identified by a unique name andAP! number by adáng a suffix to the name designated for the well by the operator and to the number as:<;fqned to the well by the commls:<;io!7. The well for which this application is submitted will be designated as 1B-20, 15. Attachments .. ....... ................... ....................... ................ ........... ........... ........ ..... ... .... 7 Attachment 1 Directional Plan .................................................................................................. ............. 7 Attachment 2 Drilling Hazards.. ...... ........... .... ... ............ ..... ......... ... .......... ........ .... ... ...... ....... 7 Attachment 3 Well Schematic.............................................................................................. 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 13. Proposed Dri II i ng Program ....... ..... ... ............. ....... ....... ........ ..... ......... ... ......... ......... 6 Requirements of 20 AAC 25.005 (c)(13) ............................................................................................ .... 6 ') )ication for Permit to Drill, Well 1 8-20 Revision No.O Saved: 6/02/03 and (D) other li7formation required by 20 AAC 2S. 050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form .10-40.1) must (l) li7c1ude a plat; drawn to a sll/table scale, showing ttle path of tile proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed wel¿~ Please see Attachment 1: Directional Plan and (2) for all wells wlthlÌ7 200 feet of the proposed well bore (A) list the names of the operators of those well~~ to the extent that t/70se names are known or discoverable li7 public record.~ and show that each named operator has been ñJmi..-;/7ed a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner, 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be aCGVmpanied by each of the (vllowlÌ7g items¡ except for an item already on file with the commission and identified in the application: (1) a diagram and desC/iption of the blowout prevention equipment (BOPE) as required by 20 AAC 2.£03w~ 20 AAC 2.£036, or 20 AAC 2.'i:037, as applicable; Please reference BOP schematics on file for Doyon rig 141, 4. Drilli~g Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application fvr a Permit tv Drill must be accompanied by each of the following item5~ except tar an item already on file with the (."ommis:c,ion and identified in the application: (4) information on dlilling hazardS¡ ineluding (A) the maximum downhole pressvre that may be encountere4 cnteJia used to deteJmine it; and maximum potential surface pressure based on a methane gradìent;· Based on offset well data, the estimated pressure in the Kuparuk 'A' is to be 3850 psi at 6238' TVD SS, Therefore, the highest expected pressure is 0,62 psi/ft or 11.9 ppg EMW (equivalent mud weight), The maximum potential surface pressure (MPSP) while drillin~~ ca~ using above maximum reservoir pressure, a gas gradient of 0,11 psi/ft, and the Kuparuk A sand target at 6327' TVD: MPSP =(6327 ft)*(O,62 - 0,11 psi/ft) = 3227 psi (B) data Of] potential gas ZOf]e5~' The well bore is not expected to penetrate any gas zones, .and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones¡ and zones that have a propensity for differential stk.*il7g; Please see Attachment 2 - Drilling Hazards Summary, 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items¡ except for an item already on file wIth the commission and Identified in the application: (5) a description of the procedure for conducting formation integrity tests¡ as required under 20 AAC 25. 030(f); A procedure is on file with the commission for performing LOT's, ) -,r l" '~J 11 L " :iìuln/i. 18-20 PERMIT IT. DOC Page 3 of 7 Printed: 10-Jun-03 I ~ation for Permit to Drill, Well 1 8-20 Revision No.O Saved: 6/02/03 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Dtill mU!;t be accompanied by each of the following items~ except for an item already 0/7 tìle with the comrnisSìon and Identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25:0..50, and a descriptton of any slotted liner, pre- perforated /ti7ef~ O( screen to be installed; Casing and Cementing Pro(lram Hole Top Btm CsgíTbg Size Weight Length MDíTVD MDíTVD 00 (in) (in) (Iblft) Grade Connection (ft) (ft) (ft) Cement Program 30 X 16 42 62,5 H-40 Welded 110 28/28 138/138 9 cy High Early Insulated 9-5/8 12-1/4 40 L-80 BTC 5,185 28/28 5,213/4,015 Lead: 650 sx 10.7 ppg AS III Lite Tail: 300 sx 12.0 ppg 'LiteCRETE'. (Yield = 2,28 cuft/ sk) Planned TOC=Surface 7 8-1/2 26 L-80 BTC-Mod 7,980 28/28 8,008/6,025 190 sx 15,8 ppg 'G' w/ add, Planned TOC= 7,208' 5-1/2 7 15.5 L-80 Hydril 511 777 7,858 MD 8,635/6,593 130 sx 15,8 ppg 'G' w/ add, Plan TOC = Liner Top 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applicatIon fÓr a Permit to On/I must be aa-ompanied by each of the fOllowing items~ exCX:.pt lor an item already on llIe wtfh the commisSìon and kientifit"d in the applkation: (7) a diagram and desniptiol7 of the diverter sy.slem as required by 20 AAC 25. 035" unless this requirement lç ~1/aived by the commis.'iion under 20 MC 25.03S(17)(2); Please reference diverter schematic on file for Doyon rig 141. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Dn/I must be aŒompanied by each of" the to/lowing items; ex({;'pt {'or an item already 0/7 Me with tile commis"S1on and Identified i/7 the application: (8) a dri111i7(J fluid program/ indudlÌ7g a diagram and description olthe drrlling fluid 5;ystem/ as required by 20 MC 2.5. 033; Drilling will be done using mud systems having the following properties: 1B-20 PERMIT IT. DOC Page 4 of 7 Printed: 10-Jun-03 ) '1 ~Iication for Permit to Drill, Well 1 8-20 . Revision No.O Saved: 6/02/03 Surface Hole Mud Proqram (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Total Depth Initial Value Final Value Initial Value Final Value Density (ppg) 8,5 -8,6 ~9,2 ~9,2* 9.5* Funnel Viscosity 150 - 200 150 - 200 150 65 - 75 (seconds) Yield Point 30 - 60 30 - 60 20 - 35 18 - 30 (cP) Plastic Viscostiy 8 - 15 11 - 22 12 - 30 12 - 24 (lb1100 sf) 10 second Gel 15 - 30 15 - 25 15 - 25 15 - 25 Strength (/b1100 sf) 10 minute Gel 25 - 55 25 - 55 20 - 45 20 - 45 Strength (lb1100 sf) pH 8,5 - 9,5 8,5 - 9,5 8,5 - 9,5 8,5 - 9,5 API Filtrate(cc) 8-15 <8 <8 <6 Solids (%) 5-8 5-8 5-8 6 - 10 *9.6 ppg if hydrates are encountered Intermediate Interval Mud Proqram (LSND) Kalubik Initial Value 9.4 - 9.5 35 - 41 22 - 26 10-15 <600 9-9.5 <6 <10 <20 <11 Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb/100 sf) Chlorides pH API filtrate **HTHP filtrate MBT ***Solids ppb Production Interval Mud Proqram (LSND) Kuparuk Sand Initial Value 9.4 - 9.5 35 - 45 20 - 25 10-15 <600 9-9.5 <6 <10 <25 <12 Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (Ib/100 sf) Chlorides pH API filtrate **HTHP filtrate MBT ***Solids ppb .... HTHP to be run at 800 F ...... The drilled LGS Final Value through HRZ 9.8 38 - 45 25 - 35 15 - 20 <600 9 -10 4-5 <10 <20 <12 Final Value 12.2 45-60 25 - 35 15 - 20 <600 9 -10 <5 <10 <25 <20 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25,033, Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. C h ",". ~, ~, l .', ,',' ;~!.: ~.: ,,' '", :) ~ . ~ ,.;~ . ." . I ~ \~,.. 4 ,~' i ",~ 1 8-20 PERMIT IT. DOC Page 5 of 7 Printed: 1 0-Jun-03 P 'ation for Permit to Drill, Well 1 B-20 Revision No.O Saved: 6/02/03 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit tv Drill mu!;t1: be accompanied by each of the tollow/ng items~ except tÓr an Item already on file with the commission and identified in the application: (9) lor an exploratOlY or stratiqrapl7ic test we/Ir a tabulation setting out the depths of predicted abnormally qeo-pressured strata as required by 20 MC 25. 033(tX N/ A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit tv Dnll [nust be accompanied by eaäï of the following item'::'~ except for an Item already on file with the commi%ion and identified in the application: (1 ()) for an exploratOlY or stratigraphic test well- 3 s:eismic: refraction or reflecllÒn analysis as required by 20 AAC 25: 06.t (3)/ N/ A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An applic,:":Jtion fÒr a Permit to Drill must be aCJ.:vmpanied by each of the tò/lowing items/ except tòr an item already on file wIth tile commission and identified Ii] the applk73tion: (U) for a well drilled ti'Om an otfs17ore platform/ mob¡le Öottom..(ounded strïJäurc~ jack-up rig/ or floating dnlling ves:çel, an analysi..:; of'seabed conditions as required by 20 AAC 25. 061 (b); N/ A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application lÒr a Permit to On!! mllst be accompanied by each a/the fòllowin{l items~ except f'or an item a/ready onll!e wltll the commission and identified in the dpplicatioo: (12) evidence showing that the requirements of20 MC 25.025 {Bondlng}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application fof' a Pel'ln/t to Drill must be accompanied by each of the following Itetn~ except for an Item already on lYe with the c:'Ommis:<;ion and identified in the applk"¡::1tion: The proposed drilling program is listed below, Please refer as well to Attachment 3, Well Schematic. 1. MIRU Doyon 141. 2. Install diverter system, 3, Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan, 4, Run and cement 9-5/8" 40#, L -80 BTC casing string to surface, Employ lightweight permafrost cement lead slurry and LiteCRETE tail slurry. Pump adequate excess to ensure cement reaches the surface. If cement does not circulate to surface, perform top job, Install and test BOPE to 5000 psi. Test casing to 2500 psi. 5, Drill out cement and 20' of new hole, Perform LOT, 6, Drill 8-1/2" hole to top-set casing point according to directional plan, Run LWD logging equipment with GR and resistivity, Drill well to casing depth according to directional plan, and run 7" 26# L-80 BTCM casing to surface and cement, Test casing to 2500 psi. 7, Drill out cement and 20' of new hole, Perform LOT, l,',r'~","1 tl 18-20 PERMIT IT. DOC Page 6 of 7 Printed: 10-Jun-03 ) )lication for Permit to Drill, Well 1 8-20 , Revision No.O Saved: 6/02/03 S, Drill 6"X7" hole to total depth according to directional plan, Run LWD logging equipment with GR, resistivity, and neutron-density tools, Drill well to total depth, then run and cement 5-1/2" 15,5# Hydrill 511 liner, Note: If significant hydrocarbon zones are present above the Kuparuk C sand, sufficient cement will be pumped for isolation in accordance with 20 AAC 25,030(d)(3)(C), 9. Perforate the C-sand interval on e-line w/ 6 SPF, 10, Run 3-1/2" 9,3#, L-SO Srd EUE Srd-Mod single selective completion assembly w/ 3-1/2" X 5-1/2" SABL-3 permanent packer, 3-1/2" X 7" Premier permanent packer and PBR, Set packers, shear out of PBR, P/U tubing hanger, and land tubing, Pressure test tubing to 3500 psi, Pressure test 3 1/2" x 7" annulus to 3500 psi, Burst shear valve for freeze protect, 11. Set TWC and ND BOPE, Install and pressure test production tree, 12, Freeze protect, Secure well. Rig down and move out. 13, Handover well to Operations Personnel. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An app/ícatiol7 f'or a Permit to Drill mustc be accompanied by each of the folloWli7g items" except for an Item already on file with the cormm:<;siol7 ánd identified in th(: application: (14) a general description of how the operator plans to dí.<:,pos--e of drilling mud and cuttings and a statement of whether the operator intend"'ito request authorization under 20 AAC 25:080 for an annular disposal operation in the well,,: Waste fluids generated during the drilling process will be disposed of down a permitted annulus on lB pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on lB pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. At the end of drilling operations, an application may be submitted to permit lB-20 for annular pumping of fluids occurring as a result of future drilling operations on lB pad, 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. '0 i:~:'" .~.. ~~\ ~ ~: f i~" ~ ~.) \,;,;~ ¡, I~ ,~.'I!J 18-20 PERMIT IT. DOC Page 7 of 7 Printed: 10-Jun-03 18-20 Kuparuk ProL )cer Proposed Completion Schematic 7" T opset Base Case 3-~" Single Selective Completion String ~ l ~ r l 12 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ " ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ -- ~ " ~ ~ ~ ~ ~ ~ ~ 16" 62.6# ~ ~ ~ ~ ~ ~ Conductor @ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ +1- 138' MO ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ TAM 9-518" Port ~ ~ Ii Collar Stnd Grade ; ~ ~ ~ ~ ~ BTC Threads (+/- I ~ ~ ~ ~ ~ 1000' MD/TVD) ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Use of port collar at the ~ ~ ~ " discretion of the drilling team. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ " ~ ~ I ~ Surface csg. ~ ~ I ~ ~ ~ I " 9-5/S"40# L-80 BTC ~ ~ I ~ +1- 5,213' MO/4,015' TVO ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ (casing pt -200' TVD ~ ~ below base of West Sak) ~ ~ ~ ~ ~ ~ ~ ~. ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ..~ ~ . I ~ ~ ~ ~ ~ ~ I Intermediate csg. ~ ~ ~ ~ 7" 26.0# L-80 BTCM ~ ~ ~ ~ ~~ ~ I +1- 8,OOS' MD /6,025' TVO ~ ~ r.. ~ ~ ~ - ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ C-Sand ...!2 ~ --'-I .... ,.. --~ ~- ~ ~ ~ ~ !II: ~ ~ ~ ~ ~ ~ ~ ~ a ~ ~ ~ ~ ~ ~ ~ ~ ~ Future ~ ~ Perforations ~ 'I!.._,_,,, .J~,. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ p:=- A-Sand ...~ ~ ---~ p=- Production Liner ~ :f. 5-1/2" 15.5# HYORIL 511 r..n S,635' MO I 6,593' TVO 11 " :I \~. ... )~.... ConocoPhillips 3-1/2" FMC Gen V Tubing Hanger, 3-1/2" L-SO EUESRD pin down, wi Control Line Port. 3-1/2" 9.3# L-80 EUESRO Spaceout Pups as Required 3-1/2" 9.3# L-80 EUESRO Tubing to Surface 3-1/2" Cameo TRM-4E SSSV wi 2.813" X Nipple profile set @ +1- 1,SOO' MD. Standard 'XI" SS Control line to surface (1 band per Jt). GI M Placement: Valves #1-4: 3- %" x 1" KBUG Place gas-lift mandrels at the following depths: TVO Approximate MO TBO' TBO' TBO' TBO' TBO' TBO' TBO' TBO' Valve #5: 3-1/2" x 1-1/2" 'MMG' GLM wi OCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-SO handling pups installed on top and bottom of mandrel. 6' Handling Pup Joint 3-1/2", L-SO, 9.3# EUE Srd Mod Tubing. 12' Baker 'SO-40' PBR. Baker 7" x 3-1/2" 'Premier' Permanent Packer. Minimum 10 through the packer 3.00". 3-1/2", L-SO, 9.3# EUE 8rd Mod Tubing as needed. Valve #6: 3-1/2" x 1" 'KBG-2-9' GLM. 6' L-SO handling pups installed above & below. XO, 3.%" EUE S RNO BOX X 3-%" HYORIL 511 PIN. 90' 3-%" HYORIL 511 Flush Joint with 60' of 3-%" BLAST RINGS. XO, 3-1/2" HYORIL 511 BOX X 3-%" EUE 8 RNO PIN. 1 jt 3-1/2" 9.3# L-80 EUESRO Tubing. 6' Pup Joint 3-1/2", L-SO, 9.3# EUE Srd Mod Tubing. 3.5" Baker 'CMO' Sliding Sleeve with Otis 2.S13" X Nipple Profile. 6' Pup Joint 3-1/2", L-SO, 9.3# EUE 8rd Mod Tubing. 6' Pup Joint 3-1/2", L-SO, 9.3# EUE Srd Mod Tubing. Baker 3-1/2" x 5-1/5" SABL-3 Packer 2.78" 10 wi K-22 tubing anchor and mill-out extension. 6' Pup Joint 3-1/2", L-SO, 9.3# EUE Srd Mod Tubing. 3-1/2" Otis Nipple wi 2.75" XN profile. 6' Pup Joint 3-1/2", L-SO, 9.3# EUE Srd Mod Tubing. Baker 3-1/2" WL Re-entry Guide wi shear out sub. Liner Assembly (run on drillpipe). 150' of liner overlap Baker 7" x 5-1/2" 'CPH' Liner Top Isolation Packer with C2 profile Baker 7" x 5-1/2" 'HMC' Liner Hanger XO Sub, 5-1/2" BTC box x 5-112" HYORIL 511 pin 5-1/2" 15.5# L-SO HYORIL 511 liner as needed 5-1/2" Baker Landing Collar 1 jt 5-1/2" 15.5# L-SO HYORIL 511 liner 5-1/2" Baker Float Collar .) j~ 9- Y2:l1i·5# L-SO HYORIL 511 liner 5-1 12" B~ker Float Shoe ~ ','1 I SOC, 6/2/03 1 ..,,i" ·j ) ) 18-20 Drilling Hazards Summary 12-1/4" Hole / 9-5/8" Casina Interval Event Broach of Conductor Gas Hydrates Gravel/Sand Sloughing to 500' Hole Swabbing/Tight Hole on Trips Possible thaw bulb Lost Circulation Risk Level Moderate Moderate Moderate Moderate Low Low 8-1/2" Hole / 7" Casina Interval Event Shale stability in HRZ and K-l Barite Sag Differential Sticking Lost Circulation Risk Level Low Low Low Low 7" Hole / 5-1/2" Liner Interval Event High ECD and swabbing with higher MW's required Barite Sag Differential Sticking Abnormal Reservoir Pressure Lost Circulation Risk Level Moderate Low Moderate Moderate Moderate o ~¡ M iti~ation Strateqy Monitor cellar continuously during interval. If observed - control drill, reduce pump rates, and reduce drilling fluid temperatures, Additions of Drilltreat. Increase mud weight / viscosity, High viscosity sweeps, Monitor fill on connections, Circulate hole clean prior to trip, Proper hole fill (use of trip sheets), Pumping out of hole as needed, Watch return viscosity for signs of thinning, Increased mud weight/viscosity as needed, Prevent by keeping hole clean, If losses occur - reduce pump rates and mud rheology, use LCM, I M iti~ation Strate~y Control with higher MW and proper drilling practices, Good drilling practices as documented in well plan, Periodic wiper trips, Do not leave pipe static for extended period of time. Reduced pump rates, Mud rheology, LCM, Use GKA LCM decision tree, M itiqation Strateqy Condition mud prior to trips, Monitor ECD's while drilling across pay interval. Pump and rotate out on trips as a last resort, Good drilling practices as documented in well plan. Periodic wiper trips, Do not leave pipe static for extended period of time, Follow mud weight schedule and do not fall behind, Stripping Drills, Shut-in Drills, and Increase mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Reduced pump rates, Mud rheology, LCM, Use GKA LCM decision tree, 18-20 Drilling Hazards Summary. doc prepared by Shane Cloninger 11/14/02 ,,1 f , ì ,II:. .~ \::~ Page 1 of 1 ) ) ConocoPhillips Alaska, Inc. Pad lB 20 slot #20 Kuparuk River Unit North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License 1B-20 Ver#l.A prop5442 Date printed Date created Last revised ll-Jun-2003 10-Apr-2003 ll-Jun-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 35 27.418 Slot location is n70 19 40.285,w149 35 51.414 Slot Grid coordinates are N 5969647.247, E 549616.397 Slot local coordinates are 497.00 S 822.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North 1;'" (, ,,< \-? ~ ;1 ., ~ ~' ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 1 Pad 1B,20 Your ref 1B-20 Ver#l.A Kuparuk River Unit,North Slope, Alaska Last revised : ll-Jun-2003 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 100.00 0.00 220.00 100.00 0.00 N 0.00 E 0.00 0.00 200.00 0.00 220.00 200.00 0.00 N 0.00 E 0.00 0.00 300.00 0.00 220.00 300.00 0.00 N 0.00 E 0.00 0.00 400.00 0.00 220.00 400.00 0.00 N 0.00 E 0.00 0.00 500.00 0.00 220.00 500.00 0.00 N 0.00 E 0.00 0.00 600.00 0.00 220.00 600.00 0.00 N 0.00 E 0.00 0.00 KOP 700.00 2.00 220.00 699.98 1.34 S 1.12 W 2.00 1. 59 800.00 4.00 220.00 799.84 5.35 S 4.49 W 2.00 6.36 900.00 6.00 220.00 899.45 12.02 S 10.09 W 2.00 14.30 1000.00 8.00 220.00 998.70 21. 36 S 17.92 W 2.00 25.41 1100.00 10.00 220.00 1097.47 33.34 S 27.98 W 2.00 39.67 Begin 3/100 BId & Trn 1200.00 12.92 223.40 1195.4,6 48.12 S 41. 24 W 3.00 58.04 1270.37 15.00 225.00 1263.75 60.28 S 53.09 W 3.00 73.99 1300.00 15.86 225.89 1292.31 65.81 S 58.71 W 3.00 81. 45 1400.00 18.77 228.31 1387.77 86.02 S 80.54 W 3.00 109.88 1500.00 21.71 230.10 1481.59 108.59 S 106.74 W 3.00 143.29 1600.00 24.66 231.48 1573.51 133.44 S 137.26 W 3.00 181.56 1686.18 27.21 232.45 1651.00 156.64 S 166.95 W 3.00 218.38 Base Permafrost 1700.00 27.62 232.59 1663.27 160.52 S 172.00 W 3.00 224.61 1800.00 30.58 233.49 1750.64 189.74 S 210.86 W 3.00 272.30 1900.00 33.56 234.24 1835.37 221.04 S 253.75 W 3.00 324.52 2000.00 36.53 234.89 1917.23 254.31 S 300.54 W 3.00 381.11 2100.00 39.51 235.45 1996.00 289.48 S 351.10 W 3.00 441.93 2200.00 42.50 235.95 2071.45 326.44 S 405.30 W 3.00 506.80 2300.00 45.48 236.39 2143.39 365.10 S 462.99 W 3.00 575.55 2400.00 48.47 236.79 2211.62 405.34 S 524.01 W 3.00 647.99 2456.70 ,50.16 237.00 2248.58 428.82 S 560.03 W 3.00 690.62 EOC 2500.00 50.16 237.00 2276.32 446.93 S 587.91 W 0.00 723.60 3000.00 50.16 237.00 2596.65 656.02 S 909.89 W 0.00 1104.42 3317.42 50.16 237.00 2800.00 788.77 S 1114.30 W 0.00 1346.18 Begin 3/100 Turn 3400.00 50.05 240.23 2852.97 821. 76 S 1168.37 W 3.00 1409.21 3424.95 50.03 241.20 2869.00 831.11 S 1185.05 W 3.00 1428.29 Top Ugnu 3500.00 50.03 244.14 2917.22 857.51 S 1236.14 W 3.00 1485.78 3600.00 50.14 248.05 2981.39 888.58 S 1306.23 W 3.00 1562.41 3608.62 50.16 248.38 2986.91 891. 04 S 1312.38 W 3.00 1569.01 EOC 4000.00 50.16 248.38 3237.65 1001.74 S 1591.76 W 0.00 1868.76 4284.63 50.16 248.38 3420.00 1082.25 S 1794.95 W 0.00 2086.76 Top West Sak 4500.00 50.16 248.38 3557.97 1143.16 S 1948.69 W 0.00 2251.70 4901.20 50.16 248.38 3815.00 1256.64 S 2235.08 W 0.00 2558.97 Base West Sak 5000.00 50.16 248.38 3878.29 1284.59 S 2305.61 W 0.00 2634.64 5213.39 50.16 248.38 4015.00 1344.95 S 2457.94 W 0.00 2798.07 9 5/8 CSG 5500.00 50.16 248.38 4198.61 1426.01 S 2662.53 W 0.00 3017.58 5758.16 50.16 248.38 4364.00 1499.03 S 2846.81 W 0.00 3215.30 C-80 6000.00 50.16 248.38 4518.93 1567.44 S 3019.45 W 0.00 3400.52 6500.00 50.16 248.38 4839.26 1708.86 S 3376.38 W 0.00 3783.46 6612.01 50.16 248.38 4911.01 1740.54 S 3456.33 W 0.00 3869.24 Begin 2/100 Drop 6700.00 48.40 248.38 4968.41 1765.11 S 3518.33 W 2.00 3935.76 6800.00 46.40 248.38 5036.10 1792.22 S 3586.76 W 2.00 4009.18 6900.00 44.40 248.38 5106.31 1818.45 S 3652.95 W 2.00 4080.19 All data is in feet unless otherwise stated. Coordinates from slot #20 and TVD from Est RKB=89 (89.00 Ft above mean sea level). Bottom hole distance is 4950.83 on azimuth 244.39 degrees from wellhead. Total Dogleg for wellpath is 84.60 degrees. Vertical section is from wellhead on azimuth 244.29 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) ) ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad 1B,20 Your ref 1B-20 Ver#l.A Kuparuk River Unit,North Slope, Alaska Last revised : 11-Jun-2003 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect 7000.00 42.40 248.38 5178.96 1843.76 S 3716.83 W 2.00 4148.72 7100.00 40.40 248.38 5253.97 1868.12 S 3778.31 W 2.00 4214.68 7200.00 38.40 248.38 5331.24 1891.50 S 3837.31 W 2.00 4277.99 7300.00 36.40 248.38 5410.67 1913.88 S 3893.78 W 2.00 4338.57 7304.13 36.32 248.38 5414.00 1914.78 S 3896.05 W 2.00 4341.01 C-40 7400.00 34.40 248.38 5492.18 1935.22 S 3947.63 W 2.00 4396.35 7500.00 32.40 248.38 5575.66 1955.49 S 3998.80 W 2.00 4451. 25 7600.00 30.40 248.38 5661. 01 1974.69 S 4047.24 W 2.00 4503.22 7700.00 28.40 248.38 5748.13 1992 .77 S 4092.87 W 2.00 4552.18 7768.76 27.03 248.38 5809.00 2004.55 S 4122.60 W 2.00 4584.08 Top HRZ 7800.00 26.40 248.38 5836.91 2009.72 S 4135.66 W 2.00 4598.08 7870.02 25.00 248.38 5900.00 2020.91 S 4163.89 W 2.00 4628.37 End of Drop 7907.54 25.00 248.38 5934.00 2026.75 S 4178.63 W 0.00 4644.19 Base HRZ 8000.00 25.00 248.38 6017.80 2041.15 S 4214.95 W 0.00 4683.16 8007.54 25.00 248.38 6024.63 2042.32 S 4217.92 W 0.00 4686.34 7" INT CSG 8026.70 25.00 248.38 6042.00 2045.30 S 4225.44 W 0.00 4694.42 K-1 8117.18 25.00 248.38 6124.00 2059.39 S 4260.99 W 0.00 4732.56 Top Kuparuk 8144.76 25.00 248.38 6149.00 2063.69 S 4271.83 W 0.00 4744.19 C-4 8166.83 25.00 248.38 6169.00 2067.12 S 4280.50 W 0.00 4753.49 C-3 8169.04 25.00 248.38 6171.00 2067.46 S 4281.37 W 0.00 4754.42 C-2 8185.59 25.00 248.38 6186.00 2070.04 S 4287.87 W 0.00 4761.40 C-1 8322.41 25.00 248.38 6310.00 2091.34 S 4341. 63 W 0.00 4819.07 A5 8341.17 25.00 248.38 6327.00 2094.26 S 4349.00 W 0.00 4826.98 1B-SW A4 TGT 14 May 03 8409.58 25.00 248.38 6389.00 2104.91 S 4375.87 W 0.00 4855.81 A3 8434.95 25.00 248.38 6412.00 2108.87 S 4385.84 W 0.00 4866.51 Miluveach 8500.00 25.00 248.38 6470.95 2118.99 S 4411 . 40 W 0.00 4893.93 8634.95 25.00 248.38 6593.26 2140.00 S 4464.42 W 0.00 4950.82 TD, 5 1/2 Liner All data is in feet unless otherwise stated. Coordinates from slot #20 and TVD from Est RKB=89 (89.00 Ft above mean sea level). Bottom hole distance is 4950.83 on azimuth 244.39 degrees from wellhead. Total Dogleg for wellpath is 84.60 degrees. Vertical section is from wellhead on azimuth 244.29 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ~ F" t :1 tì ,f 6 ConocoPhillips Alaska, Inc. Pad 1B,20 Kuparuk River Unit, North Slope, Alaska PROPOSAL LI8TING Page 3 Your ref 1B-20 Ver#l.A Last revised : 11-Jun-2003 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment. ----------------------------------------------------------------------------------------------------,------- 600.00 600.00 0.00 N 0.00 E KOP 1100.00 1097.47 33.34 8 27.98 W Begin 3/100 BId & Trn 1686.18 1651. 00 156.64 8 166.95 W Base Permafrost 2456.70 2248.58 428.82 8 560.03 W EOC 3317.42 2800.00 788.77 8 1114.30 W Begin 31100 Turn 3424.95 2869.00 831.11 8 1185.05 W Top Ugnu 3608.62 2986.91 891.04 co 1312.38 W EOC 4284.63 3420.00 1082.25 8 1794.95 W Top West 8ak 4901. 20 3815.00 1256.64 8 2235.08 W Base West 8ak 5213.39 4015.00 1344. 9~) 8 2457.94 W 9 5/8 CSG 5758.16 4364.00 1499.03 8 2846.81 W C-80 6612.01 4911.01 1740.54 8 3456.33 W Begin 2/100 Drop 7304.13 5414.00 1914.78 8 3896.05 W C-40 7768.76 5809.00 2004.55 8 4122.60 W Top HRZ 7870.02 5900.00 2020.91 8 4163.89 W End of Drop 7907.54 5934.00 2026.75 8 4178.63 W Base HRZ 8007.54 6024.63 2042.32 8 4217.92 W 7" INT C8G 8026.70 6042.00 2045.30 8 4225.44 W K-1 8117.18 6124.00 2059.39 S 4260.99 W Top Kuparuk 8144.76 6149.00 2063.69 8 4271.83 W C-4 8166.83 6169.00 2067.12 8 4280.50 W C-3 8169.04 6171.00 2067.46 8 4281. 37 W C-2 8185. ~)9 6186.00 2070.04 8 4287.87 W C-1 8322.41 6310.00 2091.34 8 4341.63 W A5 8341.17 6327.00 2094.26 8 4349.00 W 1B-8W A4 TGT 14 May 03 8409.58 6389.00 2104.91 8 4375.87 W A3 8434.95 6412.00 2108.87 8 4385.84 W MiIuveach 8634.95 6593.26 2140.00 8 4464.42 W TD, 5 1/2 Liner Casing posit.ions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD RRcctangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 0.00 0.00 O.OON O.OON O.OON O.OOE O.OOE O.OOE 8634.95 8007.51 5213.39 6593.26 6021.63 4015.00 2140.008 2042.328 1344.958 4464.42W 4217.92W 2457.94W 5 1/2 Liner 7" C8G 9 5/8 C8G Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ------------------------------------------------------------------------------------------------------.----- 1B-8W A4 TGT 14 May 1B-8W C4 TGT 14 May 545282.000,5967524.000,0.0000 545447.000,5967722.000,0.0000 6327.00 6150.00 2094.268 1897.368 4349.00W 4182.65W 3-Mar-2003 3-Mar-2003 If... BAKIIR HUGH. ' , ·.INTEQ . Measured SVY#' . Depth Tie-In' 0.00 1 100.00 2 ,.200.00 3 300.00 4 .400.00. 5 500.00 6 600.00 7 700.00 8 800.00 9 '900.00 10 1000.00 11 1100.00 12 1200.00 13 1270.37 14 1300.00 15 1400.00 16 1500.00 17 1600.00 18 1686.18 19 1700.00 20 1800.00 21 1900.00 22 2000.00 23 2100.00 24 2200.00 25 2300.00 26 2400.00 27 2456.70 28 2500.00 29 3000.00 30 3317.42 31 3400.00 32 3424.95 33 3500.00 34 3600.00 35 3608.62 36 . 4000.00 37 4284.63 38 4500.00 39 4901.20 40 5000.00 41 5213.39 42 5500.00 43 5758.16 44 6000.00 45 6500.00 46 6612.01 47 6700.00 48 6800.00 49 6900.00 50 7000.00 51 7100.00 52 7200.00 53 7300.00 54 7304.13 55 7400.00 56 7500.00 57 7600.00 58 7700.00 59 7768.76 60 7800.00 61 7870.02 62 7907.54 63 8000:00 64 8007.54 65 , 8026.70 66 ", 8117:1.8 67 8144.76 68 ",,;,81ß6;83 69 13169.04' 70 ·"·'8185:59 71 8322:41' 72 8341;17 73 "8409;58 74 8434.95 758SöO.00 76?ß34·~5" ) ) 1 8-20 Version #1.A June 1.1. 2003 A!aska State Plane Zone' 4 . Nad27 Coordinates Angle Azimuth TVD-RKB 'TVD X ' ' . .' Y N /.-$. E I-W . DLS ",.. . Vert.' Sec . deg .deg ftSubse,a ft. '. c:.ft .ft ft deg/100ftft . 0.00 O.C)O 0.00 -89.00 549616.40 .5.96fJ647~25 0.00 . q.OO 0.00.0..00 0.00 220.00 100.00 . 11;00 549616.40 5969647:.25 0.00' ,0.00 0.000.00 0.00 220.00 200.00 . 111".00 549616.40'5969647.25 0.00 0:00 0.00'. ',O.Otl 0.00 '220:00 300.00 211;00 549616.40 '5969647.25 0.00 0.00 0.00' 'o~bo' 0.00 . :220;00 400.00 311.00· 549616.40 5969647~25 0.00 . Ö.OO· 0.00 '..0.00: 0.00 220:00 500.00 :' 411.00 549616.40 5969Eì47.25 0.00 0.00 0.00 '·0.00: 0.00 220.00 600.00 511.00 549616.40 5969647.25 0.00': 0.00 0.00 !lOO: 2.00 220.00 699.98 610.98 549615.28 596~645.90 -1.34 -1.12 2.00 1.59: 4.00 220.00 799.84 710.84 549611.95 5969641.87 -5.35. -4.49 2.00 . 6.36: 6.00 220.00 899.45"" 810.45' 549606.39 5969E335.16 -12.02-10.09 2.00 . 14.30: 8.00 220.00 998.70 909.70 549598.62 5969625.77 -21.36 -17.92 2.00 25.41 ¡ 10.00 220.00 1097.47 1008.47 549588.65 ·5969613.72 -33.34 . -27.98 2.00 39.67.: 12.92 223.40 1195.46 1106.46 549575.48 5969598.85 -48.12 -41;24 3.00' 58.04: 15.00 225.00 1263.75 1174.75 549563.72 5969586.62. -60.28 -53.09 3.00 . 73.99, 15.86 225.89 1292.31 . 1203.31 549558.14 5969581.05 -65.81 -58.71 3.00 81.45: 18.77 ,'228.31 1387.77 1298.77 549536.45 5969560.70 -86.02 -80.54 3.00 109.88: 21.71 230.10 1481.59 1392.59 549510.40· 5969537.96 -108.59 -106.74 3.00143.29': 24.66' 231.48 1573.51 1484.51 549480.05 5969512.90 -133.44 -137.26 3.00 181.56: 27.21 232.45 1651.00, ~562.00 549450.52 596E14~9.50 -156.64 -166.95 3.00 21~.38i 27.62 232.59 1663.27 1574.27 549445.50 5969485.59. -160.52 -172.00 3.00: 224.61; 30.58 '233.49 1750.64 1661.64 549406.84 5969456.11 -189.74 -210.86 3.00 272.30: 33.56 234.24 1835.37 1746.37 549364.17 5969424.53 -221.04 -253.75 3.00 324.52; 36.53 234.89 1917.23 1828.23 549317.61 5969390.94 -254.31 -300.54 3.00 381.11': 39.51 235.45 1996.00 1907.00 549267.28 5969355.44 -289.48 ,-351.10 3.00' 441.93; 42.50 235.95 2071.45 1982.45 549213.34.5969318.12 -326.44 -405.30 3.00' 506.801 45.48 236.39 2143.39 2054.39 549155.91 5969279.08' -365.10 -462.99 3.00 575.551 48.4 7 . 236.79 2211.62 2122.62 549095.17 5969238.43 -405.34 -524.01 3.00 647.991 50.16 237.00 2248.58 2159.58 549059.32 5969214.71 -428.82 -560.03 3.00 690.62:: 50.16 237.00 2276.32 2187.32 549031.56 5969196.42 -446.93 -587.91 0.00723.60~ 50.16 237.00 2596.65 2507.65 548711.02 5968985.18 -656.02 -909.89 0.00 1104.42; 50.16 237.00 2800.00 2711.00 548507.53 5968851.08' -788.77 -1114.30 0.00 1346.18; 50.05 240.23 2852.97 2763.97 548453.69 5968817.73 -821.76 -1168.37 3.00 1409.21; 50.03 241.20 2869.00 2780.00 548437.08 5968808.27 -831.11 -1185.05 3.00. 1428.29i 50.03 244.14 2917.22 2828.22 548386.17 59687.~1.53 -857.51 -1236.14 3.00 1485.78': 50.14 248.05' 2981.39 2892.39 548316.29 5968749.99 -888.58 -1306.23 3.00 1562.41~ 50.16 248.38 2986.91 2897.91 548310.17 5968747.50 -891.04 -1312.38 3.00 1569.011 50.16. 248~38 3237.653148.65 548031.56 5968ß34.93: -1001.74 -1591.76 0.00 . 1868.76!¡ 50.16 248.38 3420.00 3331.00 547828.94 5968553.06 -1082.25 -1794.95 0.00 2086.761 50.16 248.38 3557.97 3468.97 547675.63 5968491.12 -1143.16 -1948.69 0.00 2251.70¡ 50.16 248.38 3815.00 3726.00 547390.03 5968375.73 -1256.64 -2235.08 0.00 2558.97': 50.16 248.38 3878.29 3789.29 547319.70 5968347.31 -1284.59 -2305.61 0.00' 2634.641 50.16 248.38 4015.00 3926.00 547167.80 5968285.94· -1344.95 -2457.94 0.00' 2798.0t! 50.16 248.38 4198.61 4109.61 546963.77 5968203.51 -1426.01 -2662.53 0.00 3017.581 50.16 248.38 4364.00 4275.00 546780.00 5968129.26 -1499.03 -2846.81 0.00 3215.30;; 50.16 248.38 4518.93 ·4429.93 546607.84 5968059.70 -1567.44 -3019.45 0.00 3400.52:; 50.16 248.38 4839.26 4750.26546251.915967915.89' -1708.86 -3376.38 0.00 '3783A6!~ 50.16' 248'.38 4911.01 4822.01 546172.18 '5967883.68 -1740.54 -3456.33 0.00 3869.241 48.40 248.38 4968.41 4879.41" 546110.35 5967858.70 -1765.11 -3518.33 2.00 '3935.761 46.40 248.38 5036.10 4947.10 546042.11 5967831.13 -1792.22 -3586.76 2.00 4009. 18!i 44.40 248.38 5106.31 5017.31 545976.11 5967804,4,6 -1818.45 -3652.95 2.00 4080.19:i 42.40 248.38 5178.96 5089.96 545912.41 5967778.72 -1843.76 -3716.83 2.00' 4148.721 40.40 248.38 5253.97 5164.97 545851.10 5967753.95 -1868.12 -3778.31 2.00 4214.68;' 38.40 248.38 5331.24 5242.24 545792.26 5967730.18 -1891.50 -3837.31 2.00 4277.99; 36.40· 248.38 5410.67 5321.67 545735.95 5967707.43 -1913.88 -3893.78 2.00 4338.57i: 36.32 248.38 5414.00 5325.00 545733.68 5967706.51 -1914.78 -3896.05 2.00 4341.01; 34.40 248.38 5492.18 5403.18 545682.25 5967685.73 -1935.22 -3947.63 2.00 4396.35; 32.40 248;38 5575.66 5486.66 545631.22 .5967665.11 -1955.49 -3998.80 2.00 4451.25) 30.40 248.38 5661.01 5572.01 545582.92 '5967645.59 -1974.69 -4047.24 2.00 4503.22( 28.40 . '248.38 5748.13 5659.13 545537.41 "5967627:20 -1992.77 ~4092.87 2.00' 4552.18 27.03 '248.38 5809.00 .5720.00 545507.76 5967615.22 -2004.55 -4122.60 2.00 4584.08; 26.40 248.38 5836.91 5747.91 545494.75 5967609.96 -2009.72 -4135.66 2.00 4598;08: 25.00 248.38 5900.00 5811.00 545466.59 5967598:59 -2020.91 -4163.89 2.00 4628.37; 25.00 248.38 5934.00 5845.00 545451.90 5967592.65 -2026.75 -4178.63 0.00 4644.19 25.00 248.38' 6017.80 5928.80 545415.67 ·5967578.01 -2041.15 -4214.95 0.00 4683.16' 25.00 248.38 6024.63 5935.63 545412.7159Q7576.82 -2042.32 -4217.92 0.00 4686.34: 25.00 248.38 6042.00 5953.00 545405.21 5967573.78 -2045.30; -4225.44 0.00 4694A2 25.00; ,248;38 6124.00 6035.00 545369.76:qgQ~~:4ß -2059.39 -4260.99 0.00\473~.56: 25.00'248.38 6149.00 6060.00 545358.95<59,~?~;09: -2063.69:':~?71.83 0.00i:,iU~~<M:t9 25.00\:248;38 6169.00 6080.00 545350.30 ,:~&?§5~:QO -2067.12;';>~4280~50 0.00i')f;¡47?~i1W 25.00' 248.38 6171.00 6082.00 545349.44 5967551.25 -2067.46,~4281.37 0.00'~'.4754:42 25.00 ',,'.' ·>~48:38 6186.00: . ß097;0() 545342.95 '?~Z,?~8:ß3¡ -2070.04 '~4gà7:87 0.00 ;;,,47Ø1t#>' 25.00. :248.38 6310.00: ,6221.QO 545289.3559ß7526.97 -2091.34.:..4;34L63 0.00 481Ø.07 25.00'~'24~·.38 6327.00, 6238.00 545282.00 5967524.00 -2094.26~49~9,Q() 0.00, 48~ß.98 25.00 ><248;38' 6389.00 :,"63ÖÖ.ÖO; 545255.20 5967513.17 -2104.91 : ';+4375;87 0.00 ;'\48$~i81' 25.00;248.38 6412.00'632$;00 545245.25 5967509.15 -2108.87 ~4385';84 0.00 ',,4866.51 25.00248;38 6470.95 }6~§1t~!)'/'s45219 77 596749~.8~ 1-2118.99: <441J.4Ò 0.00' ,4~~ª'~:3 25.00 ?4/::!,$!3 6593.26 §?q4.?§~ ~5166.90 5967477·Ø~~'-2140.00 :;..44ê4.4~ O.004:~?p.ªg ,'.....' ,I ~ :I~ ~ \~,~:þ'~ , 1 "P ,~'I :'~::j VSect. Plane = 244~29°. ) ) Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocriP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 June 27, 2003 J, p, Williams, Jr, ExxonMobil Alaska Production, Inc, 3301 'C' Street Suit 400 Anchorage, Alaska 99519-6601 Dear Mr, Williams: RE: Notice of Request for Exception to the Provisions of 20 AAC 25,055(d) for the Kuparuk well 1 8-20 Pursuant to the requirements of 20 AAC 25,055(d), ConocoPhillips Alaska, Inc, hereby gives notice of a request to the Alaska Oil and Gas Conservation Commission for an exception to the spacing requirements of 20 AAC 25,055(d), A copy of the request to AOGCC is attached. Sincerely, ~~ R, Thomas Kuparuk Drilling Team Leader CPAI Drilling RT /sc/skad ') Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 June 27, 2003 J, MacArthur Union Oil Company of California 909 W, 9th Avenue Anchorage, Alaska 99501 Dear Mr, MacArthur: RE: Notice of Request for Exception to the Provisions of 20 AAC 25.055(d) for the Kuparuk well 1 8-20 Pursuant to the requirements of 20 AAC 25,055(d), ConocoPhillips Alaska, Inc, ,hereby gives notice of a request to the Alaska Oil and Gas Conservation Commission for an exception to the spacing requirements of 20 AAC 25,055(d), A copy of the request to AOGCC is attached, Sincerely, ~~ R, Thomas Kuparuk Drilling Team Leader CPAI Drilling RT /sc/skad ) ) Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells '. ConocJP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 June 27, 2003 Chevron U,S,A. Inc, G, M, Forsthoff 11111 So, Wilcrest Drive Houston , Texas 77099 Dear Mr. Forsthoff, RE: Notice of Request for Exception to the Provisions of 20 AAC 25,055( d) for the Kuparuk well 1 8-20 Pursuant to the requirements of 20 AAC 25,055(d), ConocoPhillips Alaska, Inc, hereby gives notice of a request to the Alaska Oil and Gas Conservation Commission for an exception to the spacing requirements of 20 AAC 25,055(d), A copy of the request to AOGCC is attached. Sincerely, ~~- R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT /sc/skad ) ) Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocJP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 June 27, 2003 BP Exploration Alaska, Inc, 900 E, Benson Boulevard Anchorage, Alaska 99508 Attention: D, Nicolson Dear Mr, Nicolson: RE: Notice of Request for Exception to the Provisions of 20 AAC 25,055(d) for the Kuparuk well 1 B-20 Pursuant to the requirements of 20 AAC 25,055(d), ConocoPhillips Alaska, Inc, hereby gives notice of a request to the Alaska Oil and Gas Conservation Commission for an exception to the spacing requirements of 20 AAC 25,055(d), A copy of the request to AOGCC is attached, Sincerely, ~~ R, Thomas Kuparuk Drilling Team Leader CPAI Drilling RT /sc/skad 18-20 Directional Plots ') ') Subject: 18-20 Directional Plots Date: Wed, 25 Jun 2003 13:02:20 -0800 From: "Shane D Cloninger" <Shane.Cloninger@conocophillips.com> To: Steve Davies <steve_davies@admin.state.ak.us>, <tom_maunder@admin.state.ak.us> CC: "Owen J Hnatiuk" <Owen.Hnatiuk@conocophillips.com> Tom, Attached below are the spider plots you requested for the 1 B-20 permit. Let me know if you need additional information. Steve, Will these plots suffice for the plat $howing the location of the well for which the $pacing exception i$ $ought? We have no ga$ well$ within 3,000 feet of the well, and I believe these plots show all the completed well$ within 1000 feet of 1 B-20. If this won't work, please let me know $0 I can get something made up before I leave for vacation on Friday. Thanks! Shane D Cloninger ConocoPhillip$ Ala$ka Inc. (907) 265-6829 OFFICE (907) 240-5654 CELL ATO-1578 (See attached file: 1B-20 Ver$1a Vertical View.doc)(See attached file: 1 B-20Ver$1 a Plan View.doc)(See attached file: 1 B-20Ver$1 a Spider View1.doc) (See attached file: 1 B-20Vers1 a Spider View2.doc)(See attached file: 1 B-20Vers1 a anti-collis scan.pdf)(See attached file: 1 B-20 Vers1 a Vertical View.doc)(See attached file: 1 B-20Vers1a Plan View.doc)(See attached file: 1 B-20Vers1 a Spider View1.doc)(See attached file: 1 B-20Ver$1 a Spider View2.doc)(See attached file: 1 B-20Vers1 a anti-collis scan.pdf) :o'-~.'.._""_.__.~-_.._--._--"'.._---~_._..~----~._-'-_..~.~..._- -...-.----..-.-----..--..------..-. ..-.....-..- .-.---..-----... 01 B-20 Vers1 a Vertical View. doc . Name: 1 B-20 Vers1a Vertical View.doc Type: WINWORD File (application/msword) ba$e64 ·..··..,·"';",,,v,¡,,' '·'''VI···.,···,······..··...··.,·....··.........··· ·····..··"'....··..·,,,·..;...,..w,', : . Name: 1 B-20Vers1 a Plan View.doc .01 B-20Vers1a Plan View.doc! Type: WINWORD File (application/msword) ""'.",..",,,,,,,.,,,,,,"',,""'.'.'MW"""""."',,"w,'w.w^'''',.,,,,,."w.,..,"w,,,,,"',,"',,,,,,,,,,....,,,,,,.."',: .,~~,~~,~"i"~~,,:,'""~,~,~,:,~,~,,.,,""""'..~""",.'w,.w.wM""""".""w",.""""",,,,.,,.,,,",,,,,",,,,,,, w",,,,,,,,,,,,.,' Name: 1 B-20Vers1 a Spider View1.doc · 01 B-2 OVe rs 1 a Spider View1.doc Type: WINWORD File (application/msword) Encoding: base64 " 1 Name: 1 B-20Vers1 a Spider View2.doc . 01 B-20Vers1a Spider View2.doc Type: WINWORD File (application/msword) I Encoding: base64 Name: 1 B-20Vers1 a anti-collis scan.pdf 01 B-20Vers1a anti-collis scan.pdf Type: Acrobat (application/pdt) Encoding: base64 1 of 1 6/25/2003 2:09 PM ) ) Baker Hughes Incorporated Anticollision Report çøJr1pariy: Gono¢oRhi.lliþ~·.Alaskà..lnc. Field: Kyp;uuk Riyør lJnit J,t~f~re~~~~i~e: Pad 18 J{~f~~e~ceW~ll: 20 ReferenceWellpath: t8~20 Vers#1.à NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD + Stations Interval: 25.00 ft Depth Range: 0.00 to 8634.95 ft Maximum Radius: 5000.00 ft D~te: '6/1112003 Time: .16:06:59 Ço.or~in~te(NF.)~efer~nce: Vertical (TVD) Refere.n.ce: VJ.~11:29",1trLJe., t\lprth Well.hE!a9(8~~)···69;O Reference: Error Model: Scan Method: Error Surface: Db: "OraCle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Well path Date: 5/27/2003 Validated: No Planned From To Survey ft ft 0.00 8634.95 Planned: 18-20 Version#1.a V17 Version: 0 Toolcode Tool Name MWD+SAG MWD + Sag correction Casing Points TV'D ft 6000.00 4518.93 13.375 17.500 13 3/8" Summary Offset Wellpath > Reference Offset Ctr-Ctr No;.Go Allowable Well Wellpath MD MD Distance, Area Deviation Warning ft ft ft ft ft 20,18-20 Vers#1.a,1 8-2 3450.00 3450.00 0.65 165.74 -165.08 FAIL: Major Risk Pad 18 10 18-10GI VO 1407.64 1400.00 425.76 28.37 397.46 Pass: Major Risk Pad 18 11 18-11 GI V1 1120.79 1150.00 274.30 21.10 253.23 Pass: Major Risk Pad 18 1 18-01 VO 449.99 450.00 159.55 7.98 151.57 Pass: Major Risk Pad 18 12 18-12 VO 549.98 550.00 650.50 9.83 640.66 Pass: Major Risk Pad 18 13 18-13 VO 695.19 700.00 215.95 13.12 202.85 Pass: Major Risk Pad 18 14 1B-14 VO 599.98 600.00 296.65 11.05 285.61 Pass: Major Risk Pad 1 8 15 18-15 VO 739.60 750.00 331.23 13.47 317.82 Pass: Major Risk Pad 1 8 16 18-16 VO 620.85 625.00 581 .42 12.44 568.98 Pass: Major Risk Pad 1 8 17 18-17 V2 665.29 675.00 667.07 11.82 655.24 Pass: Major Risk Pad 1 8 18 18-18 VO 689.37 700.00 532.33 13.00 519.34 Pass: Major Risk Pad 18 19 18-19 VO 1440.79 1550.00 423.04 39.57 383.98 Pass: Major Risk Pad 18 2 1 8-02 VO 926.42 925.00 32.68 15.82 16.88 Pass: Major Risk Pad 18 3 1 8-03 VO 673.65 675.00 81.70 12.01 69.69 Pass: Major Risk Pad 18 4 1 8-04 VO 671.78 675.00 200.85 11.98 188.87 Pass: Major Risk Pad 18 5 1 8-05 VO 669.92 675.00 322.58 11.95 310.63 Pass: Major Risk Pad 18 6 18-06 VO 668.23 675.00 441.72 11.93 429.79 Pass: Major Risk Pad 1 8 7 18-07 VO 525.00 525.00 561.32 9.37 551.95 Pass: Major Risk Pad 1 8 8 18-08 VO 643.41 650.00 679.53 11.46 668.07 Pass: Major Risk Pad 1 8 8 1 8-08A VO 643.41 650.00 679.53 11 .46 668.07 Pass: Major Risk Pad 1 B 9 18-09GI VO 1401.52 1300.00 637.17 27.13 610.29 Pass: Major Risk Pad 1 8 CPF-1A CPF-1A VO 574.94 575.00 1622.44 10.30 1612.13 Pass: Major Risk Pad 1 8 WS-1Q WS-10 VO 3618.45 3350.00 244.71 131.87 118.82 Pass: Major Risk Pad 18 WS-11 WS-11 VO 499.97 500.00 551.05 8.91 542.14 Pass: Major Risk Pad 18 WS-1 WS-01 VO 642.09 650.00 648.24 11 .44 636.80 Pass: Major Risk Pad 18 WS-2 WS-2 VO 499.99 500.00 564.00 8.90 555.09 Pass: Major Risk Pad 18 WS-3 WS-03 VO 499.98 500.00 506.63 8.90 497.73 Pass: Major Risk Pad 1 8 WS-4 WS-04 VO 643.81 650.00 451.99 11.47 440.52 Pass: Major Risk Pad 1 B WS-5 WS-05 VO 800.00 825.00 392.08 13.94 378.15 Pass: Major Risk Pad 1 B WS-6 WS-06 VO 524.99 525.00 345.80 9.37 336.43 Pass: Major Risk Pad 1 B WS-7 WS-7 VO 1428.14 1525.00 178.75 30.75 149.18 Pass: Major Risk Pad 1 8 WS-8 WS-08 VO 622.98 625.00 251.89 11.13 240.76 Pass: Major Risk Pad 1 B WS-9 WS-09 VO 524.97 525.00 399.41 9.37 390.04 Pass: Major Risk Creoled by bmichoel For: S Cloninger Date plotted: 24-Jun-2003 Plot Reference '5 18-20 Ver#1.A. Coordinates are in feet reference slot #20. T ruE Vertical Depths ore reference Est RKB=89. ~ii5 Bt~f.'tIl;S Ir>;TU} 4600 4000 3400 3200 3800 3600 4400 4200 244.29 AZIMUTH 4827' (TO TARGET) ...Plane of Proposal... " , TRUE Structure : Pad 1 B ConocoPhillips Alaska, Inc. Well: 20 - ~;¡ ---- i_onOC0Phillips Field : Kuparuk River Unit Location North Slope, Alaska <- West (feet) 3000 2600 2000 2400 2200 2800 Base West Sak ~ 5/8 CSG ß ~'1 ?/'r.ß'~ C-80 TARGET LOCATION: 2593' FI~L, 104' FWL SEe. 9, T11N, R10E Begin 2/100 Drop C-40 E~gPofH~~op Base HRZ 7 INT CSG 1<-1 Top Kuparuk AS A~4 Target TO. 5 IJli~2e~i~~r TO LOCATION: 2639' FNL, 12' FEL SEe. 8, Ti 1N. R10E 1800 1600 Top West Sak 1400 1200 800 1000 ESTIMATED SURFACE LOCATION: 497' FNL, 823' FEL SEC. 9. T11N, R10E ~'l> ~rt 'P Begin 3/100 Turn Top Ugnu EOC 600 400 200 o Begin - 0 - 200 - 400 - 600 - 800 - 1000 (J) 0 C - 1200 -+ ::r r---. ---+, - 1400 ill ill -+ '--" - 1600 I V - 1800 - 2000 - 2200 - 2400 - 2600 - 2800 ~ -' EOC Created by bmichael For: 5 Cloninger Date platted: 24-Jun-2003 Pial Reference is 1 B-20 Ver#1.A. Coordinates ore in feet reference slot #20. True Vertical Depths are reference Est RKB~89. 4600 4400 ..·..-6200 ~··-6500 ~~8 INTI::(} 4200 3800 3600 4000 _-·.....-5000 .,,·..-5300 .._ -56'00 Structure : Pad 18 ConocoPhillips Alaska, Inc, Well: 20 Field : Kuparuk River Unit Location North Slope. Alaska <- West (feet) 3400 2800 2200 2600 2400 3200 3000 [i}r-- _--"-3800 _-,.... -4100 _-''..'4400 ,,-'..-4700 ___/4700 6> 2000 ",'·-3500 /..··'4400 1800 1600 ConocoPhillips 1400 1200 1000 800 600 400 200 I I I I I I I I G 0 fØ: ~62oØéJ _dY- 320Q_~gºº~·/ -1'700 3500·";,~õ~ / -" 380~./ ..., 1 700/ /",,'2000 _,..'....2000 //2300 .....2600 />/2900 /... 3200 B- ,-,....-3200 ../4100 260_~".-'- /....2900 ....·3200 .../3500 ,/3800 2300_--- ,. - 400 (!J 2300"-& _ 600 /5000 - l2600 4100 440º---- /' 4 ~_º_Q.........../ ....-aooô···· .....--3-300 ......--3biJO· .....~otf 680~/_...~~q,.o-/..- 6-z{)â' .. 2000 l 2300 /2600 ,/5300 ./2900 § 3200 ~ :i~2BB 63>900 ,/ 2900 /6200 " 2600 ./ 6500 ~/6800 2900 . 3800 ~ .. 3200 ¡ 4100 i 3500 ~ 4400 .. 4700 ,/3800 & . 5000 e .. 3500 - 1400 o 200 ---- - 800 - 1000 - 1200 tf) o C -+- :::r ,.--... -+. CD CD -+- '-..../ - 1600 I V - 1800 ~. - 2000 - 2200 - 2400 - 2600 Created by bmichoel For: S Cloninger Dote plotted: 24-Jun-2DD3 Plot Reference is 1 B-20 Ver# I_A Coordinates ore in feet reference slot #20. True Vertical Depths ore reference Esl RKB=89. "WJ.s INTH) --- Structure : Pad 1 B ConocoPhillips Alaska, Well: 20 Field : Kuparuk River Unit Location North Slope. Alaska 340 320 300 280 260 240 220 200 I !j) .800 . 700 . 600 (1300 2500 (ill () 2400 110~.. . 1200 . 1300 . 1400 &>' 180 160 CD--- - ---._L6£0 ,.#6~00 ...700 i800 /0900 ... 1000 230g__/--- ,,/¡'600 ,....-1700 ---~ <- West (feet) 140 120 100 80 60 40 20 -----._L~OO ----------------...1 400 ----------..__ 1 300 -.. 1200 ..,-.... 1100 ------------- --=$-300 ConocóPhillips o 20 40 60 80 100 120 6) 60 . 1600 - 40 . 1500 -- ~300 /800 ,/~JOO /.'/1000 /..../1100 _------//A2ÕÔO 21 00 ~</-- ___-////___-;~ 1 200 __r2-2Ûcr-- "" ----------- ..............¡ 300 """'1400 ....'1500 ¡f¡ 1 600 <!J . 1 400 - 20 . 1300 " 1200 ~300180ºA_@- 0 .-,-- ¡-g-oÖ - 20 40 ø - 60 -- i 1 400 - 80 . 1500 lJ) o c - :r ".--.." - CD CD - '--" - 100 I v ---- - 120 - 140 - 160 - 180 - 200 ) i : ConocoPhillips Alaska, Created by bmichael For: S Cloninger: Dote plotted: 24-Jun-2003 Plot Relerence is 1B-20 Ver#l.A. Coord'motes are in feet reference slot #20. ! Vert"lcol Depths ore reference Est RK8=89.! .I'{,I~' 'q:, \Irll BAK!R HUGHlõS INTEQ 0 - 400 - BOO - 1200 - 1600 - 2000 - ".--.. +- 2400 - Q) Q) '+- "--" 2BOO - ...c +- Q.. Q) 0 .3200 - 0 Ü .3600 - +- L.. Q) > 4000 - Q) :J L.. I- 4400 - I V 4800 - 5200 - 5600 - 6000 - 6400 - 6800 - 7200 400 Structure: Pad 1 B Well: 20 Field: Kuparuk River Unit Location: North Slope, Alaska i A Estimated RKB: 89' KOP .. 2.00 .. 4.00 6.00 DLS: 2.00 deg per 100 ft 8.00 Begin 3/100 Bid & Trn 12.92 15.86 18.77 21,71 DLS: 3.00 deg per 100 ft 24.66 27.62 Base Permafrost 30.58 33.56 39.51 45.48 EOC ') Inc. I I 244.29 AZIMUTH 4827' (TO TARGET) **.Plane of Proposal... Begin 3/100 Turn 50500~ ,r~p Ugnu EOC Top West Sak Base West Sak TANGENT ANGLE 50.16 DEG 9 5/8 CSG DLS: 2.00 deg per 100 ft TARGET ANGLE 25 DEG C-80 32.40 30.40 28.40 26.40 7 INT CSG~\. Cë::3 t:~ Conoco'Phillips Top HRZ EB~s;,fH~ZOP K-1 Top Kuparuk A5 A~ Target ~\. Miluveach TO. 5 1/2 Liner 1200 1600 2000 2400 2800 .3200 .3600 4000 4400 4BOO 5200 5600 6000 Vertical Section (feet) - > Azimuth 244.29 with reference 0.00 N, 0.00 E from slot #20 400 800 · .~ ) ConocoPhUlips ) #¿ ~4'_ Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: rlthomas@ppco.com June 25, 2003 Sarah Palin, Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 f"'-'ji¡ E-- ,,"" E~ ~ "V ff"""" 1;"'(':" '''''''''~, ' - f: ."" ~"~'"' '\ll,,,,,,,,~ ,."'''~ 1.\"",,, JUN 3 0 2003 Re: Application for Spacing Exception, producer 18-20 Alaska Oil 8, Ga~Þ Com;, Comrnission Am::hmage Dear Commissioner Palin: ConocoPhillips Alaska, Inc, hereby applies for a Spacing Exception an onshore production well, KRU 18- 20, a development well. The proposed 18-20 is designed a$ an infill Kuparuk A and C sand producer. This new well will recover A and C Sand waterflood and enhanced oil recovery (EOR) reserves that are located in a fault isolated area. Risked A and C Sand incremental reserves are 1.08 and 0.56 MMST80, respectively. These reserves are not recoverable with the current well pattern configuration. In addition, well 18-20 will provide additional implementation of the Kuparuk EOR project and will add a total of 363 MST8 of EOR reserves. The requested exception refers to the well spacing requirements specified in Rule 3 of Conservation Order 4328, which states: "Not more than one well may be drilled on any governmental quarter section...", because a portion of the pro$pective pay interval in 18-20 will lie within the NW 1/4 of Section 9, T 11 N, R10E, U.M., and that portion of 18-20 will be the second well drilled within that particular quarter section (the other well being the existing 18-13 production well). Property line considerations do not apply, as the 18-20 well bore will be in the main portion of the Kuparuk River Unit, and therefore will be more than 500 feet from a property line where ownership or landownership changes. Offset well distance requirements do no apply because the 18-20 well bore will lie more than 1000 feet from other wells completed within the pool. The portion of the 18-20 well bore that lies in Section 8, T11 N, R10E, U.M. does not require an exception because, per Rule 3 of CO 4328, an unre$tricted number of well$ may be drilled in that section. Adjusting the directional profile to move the productive interval completely into Section 8, T11 N, R10E is undesirable because there is a distinct possibility of the C4 target being completely faulted out of the well bore. The fault has an estimated throw of -20 feet at the top Kuparuk, and the C4 is estimated at -20 feet thick. If the C4 sand was completely faulted out, it would result in a loss of 34% of the projects reserves. The A4 target will likely be pushed to the West of the fault, which seems discontinuous and to be intermittently baffling in the lower Kuparuk in this area. This would likely impact recovery, if the well is on the West of the lower K faulting. Even though the well design requires us to perforate the Kuparuk C sand prior to running the single selective completion, we do not intend to produce or test the well until we receive a spacing exception. Please find attached for the review of the Commission the information required by 20 AAC 25.055 (d). We have included a plat showing the location of 18-20, all other completed and drilling wells on the property, and all adjoining wells within 1,000 feet. Also included i$ a copy of the notices sent by certified mail to our co-owners and the affidavit verifying that all facts are true. If you have any questions or require any further information, please contact Shane Cloninger at 265-6829. Sincerely, ~~ Randy Thomas GKA D9Hing Team Leader ') ) CHECKLIST - SPACING EXCEPTION APPLICATION OPERATOR ConocoPhillips Alaska PROPERTY ID/ LEASE S: ADL 466 & Inc, 4öb FIELD/POOL Kuparuk River Field/Kuparuk Oil PI/BH: ADL WELL NAME 18-20 VERTICAL DEVIATED EXPLORATORY DELINEATION DEVELOPMENT GAS OIL X X SURFACE LOCATION PRODUCTIVE INTERVALS (Top and Bottom) BOTTOM HOLE 497' FNL and 820' FEL, S, 9, T11 N, R1 DE, UM 2562' FNL and 181' FWL, S, 9, T11 N, R10E, UM 2590' FNL and 111' FWL, S, 9, T11 N, R1 DE, UM 2639' FNL and 12' FEL, S, 8, T11 N, R1DE, UM, Check applicable reason(s) for spacing exception per 20 AAC 25.055(a): (1) to drill a well for oil within 500 feet of a property line where ownership or landownership changes, (2) to drill a well for gas within 1500 feet of a property line where ownership or landownership changes, (3) to drill and complete more than one oil well in a governmental quarter X section; or to drill and complete an oil well closer than 1000' to any well drilling to or capable of producing from the same pool, (4) to drill and complete more than one gas well in a governmental section; or or to drill and complete a gas well closer than 3000' to any well drilling to or capable of producing from the same pool. Does the application contain: rI/ A brief explanation for why the operator has chosen to drill the specified location, A plat drawn to a scale of one inch equaling 2,640 feet or larger, showing the location of the well or portion of the well for which the exception is,^~2ught, all other ¡ completed and drilling wells on the property, and all adjoining properties and wells . within 1,000 feet of a well or portion of the well requiring the spacing exception that is drilling for oil or within 3,000 feet of a well or portion of the well requiring the spacing exception that is drilling for gas. The names of all owners, landowners, and operators of all properties within 1,000 \/ feet of a well or portion of the well requiring the spacing exception that is drilling for oil or within 3,000 feet of a well or portion of the well requiring the spacing exception that is drilling for gas, A copy of the notice sent by certified mail to the owners, landowners and operators / described above, the date of mailing, and the addresses to which the notice was sent. .; An affidavit by a person acquainted with the facts verifying that all facts are true and that the plat correctly portrays pertinent and required data. If the operator requests a variance from the notice requirements of 20AAC25.055(d), sufficient information to demonstrate that it is not feasible to comply with the notice requirements because of the complexity of ownership within the notice area. Spacing Exception Checklist and Transmittal Letter Checklist ') Subject: Spacing Exception Checklist and Transmittal Letter Checklist Date: Tue, 24 Jun 2003 16:22:52 -0800 From: $teve _ davie$@admin.state.ak.us CC: Tom Maunder <tom_maunder@admin.state.ak.us> Shane, The attached checklists should guide you as to what you need to provide in the spacing exception application for KRU 18-20. Overall guidance for your spacing exception application i$ contained in regulation 20 MC 25.055 (d). It can be found on the Commi$sion's web site at: http://www.state.ak.us/local/akpages/ADMIN/ogc/Regulations/art199.htm . I have also attached the text of this regulation to the end of this email. You will be requesting an exception to the well $pacing requirements $pecified in Rule 3 of Conservation Order 4328, which states: "Not more than one well may be drilled on any governmental quarter section...", because a portion of the prospective pay interval in 1 8-20 will lie within the NW 1/4 of Section 9, T 11 N, R10E, U.M., and that portion of 18-20 will be the second well drilled within that particular quarter section (the other well being the existing 18-13 production well). Property line considerations do not apply, as the 18-20 well bore will be in the main portion of the Kuparuk River Unit, and therefore will be more than 500 feet from a property line where ownership or landownership changes. Well off$et di$tance requirement$ do no apply because the 18-20 well bore will lie more than 1000 feet from other wells completed within the pool. The portion of the 18-20 well bore that lies in Section 8, T11 N, R10E, U.M. does not require an exception because, per Rule 3 of CO 4328, an unrestricted number of wells may be drilled in that section. Plea$e review the pertinent regulation$ and the text of Conservation Order 4328 that I sent earlier, but don't hesitate to call if you have any que$tion$. Sincerely, Steve Davie$ Petroleum Geologi$t Ala$ka Oil and Ga$ Conservation Commission Telephone: (907) 793-1224 Fax: (907) 276-7542 steve _ davies@admin.state.ak.us --------------------------------------------------------------------- 20 MC 25.055 DRILLING UNITS AND WELL SPACING. (a) The commission will, in its discretion, establish drilling units to govern well spacing and prescribe a spacing pattern by pool rules adopted in accordance with 20 MC 25.520. In the absence of an order by the commi$sion establishing drilling units or prescribing a spacing pattern for a pool, the following statewide spacing requirements apply: (1) for a well drilling for oil, a wellbore may be open to test or regular production within 500 feet of a property line only if the owner is the same and the landowner is the same on both sides of the line; (2) for a well drilling for gas, a wellbore may be open to test or regular production within 1,500 feet of a property line only if the owner is the same and the landowner is the same on both sides of the line; (3) if oil has been discovered, the drilling unit for the pool is a governmental quarter section; not more than one well may be drilled to 1 of 2 ') 7/25/20037:11 AM Spacing Exception Checklist and Transmittal Letter Checklist ') ) and completed in that pool on any governmental quarter section; a well may not be drilled or completed closer than 1,000 feet to any well drilling to or capable of producing from the $ame pool; (4) if ga$ ha$ been discovered, the drilling unit for the pool i$ a governmental $ection; not more than one well may be drilled to and completed in that pool on any governmental section; a well may not be drilled or completed closer than 3,000 feet to any well drilling to or capable of producing from the $ame pool. (b) A well may not begin regular production of oil from a property that is smaller than the governmental quarter section upon which the well is located or begin regular production of gas from a property that i$ $maller than the governmental section upon which the well is located, unles$ the interests of the person$ owning the drilling right$ in and the right to share in the production from the quarter section or section, re$pectively, have been pooled under AS 31.05.100. (c) A pooling agreement under AS 31 .05.100 must be filed with the commission before regular production from the affected property begins. (d) The commission will review an application for an exception to the provi$ions of this $ection in accordance with 20 MC 25.540. The applicant for an exception shall $end notice of the application by certified mail to the owners, landowners, and operators described in (1) of this subsection and shall furnish the commission with a copy of the notice, the date of mailing, and the addre$$es to which the notice was sent. The application must include (1) the name$ of all owner$, landowners, and operators of all propertie$ within 1,000 feet of a well drilling for oil or within 3,000 feet of a well drilling for gas for which an exception i$ $ought; (2) a plat drawn to a scale of one inch equaling 2,640 feet or larger, $howing the location of the well for which the exception is sought, all other completed and drilling well$ on the property, and all adjoining properties and wells; and (3) an affidavit by a per$on acquainted with the fact$, verifying that all facts are true and that the plat correctly portraY$ pertinent and required data. (e) Upon application by the operator, the commission will e$tablish notice requirements different from tho$e of (d) of thi$ section if the operator demonstrates to the commis$ion'$ $atisfaction that compliance with the notice requirements in (d) of thi$ $ection i$ not feasible because of the complexity of owner$hip within the notice area. History - Eff. 4/13/80, Register 74; am 4/2/86, Register 97; am 11/7/99, Register 152 Name: 030624 Template.tif [!¡030624 Template.tif Type: TIFF Image (image/tiff) Encoding: base64 .,.,. Name: 021 022_Spacing_Exception_CH ECKLI ST. doc 0021022 Spacing Exception CHECKLlST.doc Type: WINWORD File (application/msword) Encoding: base64 2of2 7/25/2003 7: 11 AM - ,,-- ~>~.~,~~jj~__':~c-þ~~¥~,==.o:< S~~:~';:~i:;d~~~f~-~:fØ~~-.j~J~{*:~i't:,~~~~~1-k~-1~1:o~'L~~~j~~~;~V:"~_'''-'~-_.~¡-_~3£-£0:~~~~~;-~''"''''..~.a~ ,:-- - ..--~_:- -. -'~~...-=...:__'"..,~ í S,K,Al..lSUe-QRAKE 1 050 ~ .CONOCOPHILLIPS ~ I 711GSTREET:.AT01530,.-f â:J "7/'1/')¿ ~ . ANCHORAGEAK99501 DATE . It/~ ' I ¿..¿...v'.-J 62-14/311 i~ " ~ 5~,~,:,: PAYT, .o"'"THE,, '".,.C"',."X-,,"I,,,Þl,'..,",','""'f'J.,,·..,,,',G,,·,.,', [),,', ,."'.,',15,"",..",..,',.",,"','""·,fl",·,·'·,.,.·,',',,',,,M,'·,.·'".s:,'"">tA-,',",'"',,,,.., .',';"., 1,' . f/c£¿cc, ',' .' "",.," ."'. ", ' I $ /00. 00 f,j ~¡r,¡ .oRDEROF/I(C r, ,',' , ,', I;' '/ ',' '/1 I ~ 18 ./!0~k£..i,Lcl~.~~/~øc- DOLLARS!TI ~-= ~ ~Ii ...., é.f/b ,,", .. ',', ,,' ,', ,'" , ~ ¡Ê,:,~ ~,',,'.", '<,'C',',"',·.,,',H',·, 'A.,',','·,',',',··S",",·,,',,',,' ',',e,.',",.,'"',,.. ,', C,h,', as 9M"an"h,',att,', an, B,ank, USA" ,N;"A,' VaJ,id,U,P,T.o5000DO,lIars !,J O~,:. ."'" ~" 2I1OWh~eCIa)'CenterDr..N....ark.DE'97".' 0/ .,. . ,.,', "///" c;¡ j ~,' I" .. ... ~~At/~ -~~ I ~ MEMO ,,', ~ e.¡ ti, , ,',' " ',',,' ',' " " ,",'" / i~ ~ -!'.:O ~ . .00 ........:2J.aOOOO...2 '( 2S?II~¡'~~.~< .""".,> ' ,'., ., , ,.' ,..,"~ ~1·_::~~';¿~k;~~~ ~-~o;i¡-~:.;-,d;;.'-:.;-~~?-_":~~~S5..'if~~LÄ~;o~~~~~~~~Q.~~~~"k.~~~#~R'-~~~~~~~W~?çõ".,;~-i;f-2;.:;~- ~~._~ -, -~. ~~-==~~~.:wf~-'.2..~.-.:.., TRANS)\i~,~ LETTER CHECK UST ) CIRCLE APPROPRIATE LETfER/PARAGRAPHS TO BE INCLUDED IN TRANSM11T AL LETTER WELL NAME , !3> - 20 PTD# () ",-:~5 ite.J CHECK WHAT APPLIES K Rev: 07110102 C\jody\templates - " ADD-ONS (OmONS) MULTI LATERAL (If API Dumber Jut two (2) dJ&IU are betweeD 60-(9) "CLUE" - - The permit is for a Dew weUbore segmeot of esiltlDg w. _. Permh No, API No. ProcluctioD -should coDbue to be reported as a rUbedoR of tb~ origiaa1 API 1I1UDber stated above.. - - - HOLE lD aeœrdaøee with 20 AAC 25.005(1), d records, data aDd lop acquired for the pDot , hole muat be clearly dilfereDtlated ill both Dame (Dame on permit plul PH) aDd API Dumber (50_ 70180) from reeorda, data aad Joe. acquired for weD (Dame OD permit). PD.A>T (PH) - - SPACING The permit Is approved subject to fuU EXCEPTION compUabce with 20 MC 25.055. Approval to ~S..¡... ð-p- J~,pe""ll II J øtl produce i. coDtinlellt UpoD ", ,-g issuaDce of . coaservatioll orderapproyig a ' 1~"ð~ spaclDg exceptloD. CqiAcX.o Fí.C·(~(f5 (ÇompaD'f Na9le) assumes the Uablllty of 811)' protest to the spacing e:scepdoa tbat may occur.. - . DRY DITCH SAMPLE AU dry diteh aamp1ë leta submitted i~ the· Commission must be in no greater thaD 30' sample intervals from below tbe permafrost or from where samples are fint caught and ' . 10' sample iDtervals tbroQgb target ZODeI. ) ) AFFIDA VIT TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION AFFIDAVIT OF SHANE D. CLONINGER STATE OF ALASKA THIRD JUDICIAL DISTRICT I, Shane D. Cloninger, declare and affirm as follows: 1. My name is Shane D. Cloninger. I am over 19 years old and have personal know ledge of the matters set forth herein. 2. I am a Drilling Engineer for the well operator, ConocoPhillips Alaska, Inc. 3. I am acquainted with the facts associated with the drilling of the IB-20 well. 4. I have reviewed the application submitted for the exception to 20 AAC 25.055 and all facts herein are true. 5. I have reviewed the plat attached and it correctly portrays pertinent and required data. ,....""..~. +.,~ DATED at Anchorage, Alaska this¿.b day of June, 2003. (j~PrØ ' Shane D. CIO~ '11, ~ SUBSCRIBED AND AFFIRMED before me at Anchorage, Alaska this 0<. ~ day of June, 2003. STATE OF ALASKA·. NOTARY PUBLIC .. Kathryn E. HOllstein. My Commiltion Expires Auqust 15, 2005 M ß-~ NOTARY PUBL~D FOR THE STATE OF ALASKA My commission expires '3 \ I '$ (""2. 0 e:. ~ / 1O) i \12 IH~ IH~2 I \81 ~ ~11 ~ I 1 I I I I I I I I I · I · . · I · I · I I ..,..._- -.- ~~ - ....,--.. - ... - oJ · I , IB-11 I 18-18 lA-I! 1 , IS-8S ! - IC-IS * '" IS-SSA I> IC~ --- ....--...--- ...----- --...--...---......- IF-tS IE-IB IE-I? / IE-IB IF-II IE-II IE-It { I / \ IF-IS ~ , \ 1112888 FEET" Ilr' 2'r8 FEET STATUTE "[LES ~ STATUTE "[LES 18-20 PTD#: 2031150 Administration Appr Date SFD 7/3/2003 Engineering Appr Date TEM 6/26/2003 Geology Appr Date SFD 6/23/2003 Geologic Commissioner: Company __.c~KQÇOPHILLlES-ALASKA INC Well Name: KUPARUK RIV UNIT 1 B-20 Program J2E..V_ Well bore seg Field & Pool _K..UEARUKBIVFR, KUEARUK R\LQLL - 490100 Initial Classrrype DFV I 1-01L- GeoArea _890 Unit 11160 On/Off Shore ~ Annular Disposal 1 P~unit fe~ ~ttaçhe.d _ _ . _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ .Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 _Le~s~_numb~r _apRrORriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .' _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y~s _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . 3 .Untque welt"-am~ .aod olunb_er _ _ _ _ _ . . . _ _ _ _ _ _ _ . . _ . . . _ _ _ . _ . . . . _ _ _ _ . . . _ _Y~$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . . _ _ _ . . . _ _ _ _ _ _ . _ . _ _ . . _ _ _ _ _ _ _ . . _ _ _ . _ _ _ _ . _ _ _ _ _ _ . . _ _ . _ _ _ 4 W~II JQcat~d in.a. define.d pool. . . . . . . . . . . . . _ _ . . . . . . . _ . . . . . . . . . . . . . . . . .Y~s . . . . . . . Gov.em~d by CQn_serv~ti.ol) Ord.er NQ. .432Et. . . . . . . . . . . . . _ _ . _ . . . . . . . . . . . . . . . _ . . . . . . . . . 5 .W~IIJQcated pr.oper distance. from driJling unitb.ound.ary_ . . . . . . . . . . _ . . . _ . . . _ . . . . .Y~s. . . . . . . SRa.cing exceptioo is.required. . RuJe.3.: . unLimited w~Us. il) Section 8,.butio section 9, driILing.unitis_a. . . . . 6 .Well Jocat~d prpp~r .distance_ from Qtoer WßI!s_ . . . . _ _ . _ . . _ . . . . . _ _ . . . . _ . . . . . . .Y~$. . . . . _ _ go.veml)1ental.qu~rter-$ectiQn_. This well. h.as top pro.ductive intervat ilJ NW.1.14 of.sßctipo g,_making. . _ . . . . . . _ 7 _S_ufficientacrß~9.e_aYailablein.drilJilJgun.it_ _ _............ _.... _... _..... _. No.. _ _ _ _. .ittheseCPl)qwell_col)1pletedin.s~çtioo9_(1.B_-13_i$Çilre.adycompletedJnNW.1!4.Qfsection9)-_. _ _..... _ _ _. 8 Jf.dßviated, .is. weJlbQre platincJudeq . _ _ _ _ . . . . . . _ _ _ _ _ _ . . _ . _ _ _ _ _ . _ _ _ . _ . . . .Y~$. . . _ . . _ 6123/Q3.: PJan.and pr.ofile ofweJI.nots.!Jbmitted_- Rece.ivßd 6/25/2QO.3, $F:Q . . . . _ . . . _ _ . . . _ . _ . . _ _ _ _ . . 9 _Opßr.ator only ~ff.eçted party. . . . . . _ _ _ . . . _ . . . . . _ _ . _ . _ . . _ . . . . . . . _ _ _ . . . .Y~s. . . _ . . . . . . _ . . . . . . _ . . _ _ _ _ . . _ _ _ . _ . . . _ . _ . _ . . _ . . . . . . . . . . . . . . . . . . . . . . . _ . . . _ . . . . . 10 _Oper.ator bas. appropriate_ bond in .fQrçe _ . . . _ _ _ _ . _ _ . . _ . . . . _ _ _ _ _ _ _ _ _ . _ _ . . . .Y ~$ . _ _ _ _ . . . . . . . . . . _ _ . _ _ . _ _ _ . . . . . _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . . . _ _ 11 P~r:rnÎt Gal) be issued wjtOQut co_ns~rvation Qrd~r. _ . . . _ _ _ _ _ _ . _ . _ . . . _ _ _ _ _ . . . . . No. _ _ _ _ _ . _ . . . . . . . _ . . _ . _ _ . . . .. _. _ _ . _ . _ _ _ _ _ . . . . . . _ . _ _ . _ . . . . . . . . . . _ _ . . . . _ _ . . _ _ . _ 12 pß rl1) it can be tS$ued wjtOQut ad.mÎnistrati\(e.apprpval . . . . . _ _ . . . . . _ _ _ . . . . . . _ _ _ . .Y~s . _ _ _ . . . . _ . . . _ . _ _ . _ . . _ _ . . . . _ . _ _ _ _ _ _ _ . _ _ _ _ . . . . . _ _ _ _ . . . . . . . _ . _ . . . . . . . . . . . 13 Can permit be approved before 15-day wait No 14 .WellJQcated within area and. strata authQrized by.lojectiolJ Ord~r # (putlO# in.cpmmeots).(FQr. .NA . . . _ . . _ _ _ _ . . . . . . . . . . . . . _ . . . . _ _ _ _ . _ . . . . _ . . _ _ . _ . . . . . . . . . . _ _ _ _ . _ . . _ . . . _ . _ . . _ . . 15 AJI w~lJs. wittli.n .114. ruile_area_of review jd~otifiec;! (Fpr ~eJVJc~ .~ell only). _ _ . _ _ _ _ _ . _ _ . _ . .NA . . _ . _ . . . _ _ _ . _ _ _ _ _ . . . . _ _ _ _ _ . . . _ _ . _ _ _ _ _ _ _ . _ . _ _ . . _ . _ . _ _ _ . _ . . . _ . . . _ . _ . _ _ . . _ . _ . . 16 Pre-proqu.cedinjector; duratiQn.ofprß-productionl~S$.than.3.months.(for_ser.vicewellQnJy).. _NA _.. _ _. _.. _.... _ _. _. _ _..... _ _ _ _ _.. _.... _... _ _.... _ _ _. _..... _. _... _.. _ _ _..... 17 .AGMP.F:indjng.ofCQn.sisteOGy.h.asbee.n.i$.sued.for.tbispr_olect.. _. _ _ _ _ _. _ _ _ _.... _ .NA...... _Pr~:eXÎstingp(oje.ct. _ _...... _.. _....... _ _. _.. _........... _..... _. _. '.. ...... . 18 _C.O{1qu.ctor string.prQvided . _ _ _ . _ _ . . . . . . _ _ _ . _ . . . . . . . _ . _ _ . _ . _ _ . . . . . . . .Y~s . _ . . _ . . . _ . _ . _ . . _ . _ . . . . . _ . _ . . . . _ . _ _ _ . _ _ _ . . . . . . . . . _ . _ . _ . . . . . . . . _ _ . _ . _ _ . . . _ . . . 19 _S_urfacß.ca~ing.PJQtect$.all.knownUSQWs _..... _. _.. _.... _ _ _. _. _ _. _ _.. _..NA... _. _ . Allaq.uifers ex.empted 40 CFR H7..1.02_(b)(3) _........ _ _..... _... _. _ _. _. _ _ _ _ _......... 20 .CMTv.oLadequate.tocirc.uLate.o.n_cond.uctor.&su.rf_C$g _ _ . . . . . . . _. . . _ _ _ _. . . . _ . . .Y~s. _ _ . . . . . . . . . . . . . . . . . . . . . _ . . . . . . _ _ . _ _ _ . . . . . . . . _ . _ _ _ . . . . . . . _ _ . _ _ .. . _ _ . . _ _ . . . . . 21 _CMT v.oL adequate.to tie-inJQng .string to.s!Jr::f C&g. . . _ _ . . . . _ _ _ . _ . _ _ _ . _ _ . . . . . . . NA . . _ _ _ . . Ann.utar diSP.oSql rn.ay ultimately be re~Yested-_ . . _ . . . . . . . . . _ _ _ . _ _ . . _ . . . . . _ _ _ . .. . . . . . . . _ . 22 _CMTwiIlGoYer.all!<lJo.w.n.pro.duGtiYeoQri;ZQn_s_. _ _ _ _ _ _.... _.... _ _...... _... _ .Y~s. _............ _ _ _ _. _ _...... _. _ _ _ _ _ _. _ _...... _. _ _ _...... _.. _. _ _. _........... 23 _C.asiog de_sigos adequate fp( C..T., B _&. Rerruafr_ost . . . . . . _ . . _ . . ,. _ _ . _ . _ . . _ _ _ . . y~s . . . _ _ _ _ . _ . . _ . . . _ . _ _ _ . . . . . . . . . _ . _ _ . . . ., . . . _ _ . _ . . . . . . . _ _ . . _ . . . . . . . _ . _ _ . . . _ _ . . . 24 .A.dequate.t~n.kage.oJ re_serve pit _ . _ . _ _ _ _ _ _ . . _ . . . . . . _ . . . . . _ _ _ _ . _ . _ _ . _ . .Y~$ . _ . _ _ . . ß.ig ßQUiRP~d with. steel pits, N.OJesßNe pit plann_e<;t.. Waste to.Clas.sJI.well._ ~Q aRPrQved an.n!JI.!JS oll1.a.. _ . _ ,. 25 Jf.a_re-.drill.. has_a 1.0:4.03 fQr abandon.me_nt beßO apPJQved . . . . _ _ . . _ _ _ _ _ . _ .. _ _ . . . . NA. . . . . . . . . _ _ _ . . _ _ _ . _ _ _ _ . . . . . _ _ . _ _ _ _ . . . _ _ . . _ . _ _ _ _ . _ _ _ _ _ _ . _ . . . . . . . . . _ _ _ . . _ _ . . . . 26 _A.dequate.~ellbore ~eparÇ1ljo_n.propp~e.d. _ _ . _ _ . . _ _ . . . _ . . . _ _ _ . . . _ _ _ . _ _ . _ . _ .Y~$ . _ . . . . _ prp~ilJ'ltty an~IY$i$ provide.d, Glo$es.t apprQaçb ts_33'.@ 92€i'.. . _ . _ . . . _ _ . _ . . . . _ . . . _ _ _ _ _ _ . _ . . . _ 27 Jf.djv~r:ter Jeq.uired, dQes jt .meet regu.lations_ _ _ _ _ _ _ _ _ . _ _ _ . _ _ _ _ _ _ . . _ . _ . . . . . . .Y_es _ . _ _ _ . '. . . . . . . _ . . _ . . . _ . _ . _ _ _ . . . . _ . _ _ _ _ . _ . _ . . . _ _ _ _ _ . . . _ . _ _ . _ . . . . . . _ . _ _ . . . . . _ . 28 _DriLliog flujd.RrQgrql1) schelJ'latic.&eq.uipJistadequate. . . . . . . . _ . _ _ _ _ _ _ _ _ _ . . . . . . Yes. . . . _ . _ Maxexpected_BHP. 1.1.9. EMW. _PJannedMW.up.12.2, . _ . . _ . _ . _ _ . _ _ . . . _ _ . _ . _ _ _ _ _ . _ _ _ _ . . . . 29 _B.oPEs,_d_o.they meetreguJa_tion . . . . _ . ,. . . _ . _ . . . . . . . _ . . . _ . _ . . _ _ _ . . _ _ . . .Y~s . . _ _ . . . . . . _ . . . _ _ _ _ . . _ . . . . . _ _ . . _ . _ _ _ _ _ _ . . . _ . _ _ _ . _ . . _ . _ . _ . . . . . . _ _ _ _ _ . . . _ _ . . ,. . 30 _B.oPE_press ratiog appropriate; .t~stto_(put psig in .cpmments). . . . . . _ _ . . . _ _ _ , _ _ . . _ y~s . . . . . _ . MAS!? calculate_d_at 3227 'psi, 35QO.p$i.appr_oprjate_. _~p.Cp Ji~ely tp te.stto .50QO_ Rsi_- _ . . . _ . _ _ _ _ _ . . _ . . . . 31 .C.hoke.ruqnjfolc;l cQl1)pJie$. w/APLR~-53 (May 84)_ _ _ . _ _ . _ . . . . . . . _ . . . . . _ _ _ _ . _ _ y~s _ _ . . _ . _ _ . . . . _ _ _ _ . _ _ _ . _ . . _ . . _ . _ . _ . _ _ _ . . . . . . _ _ _ _ . . . . _ _ _ . . . . . . . . . _ _ _ _ . . . . _ . . . . 32 .WQrk will OÇC_Ur withoyt.operation.shutdo.w.n_ _ _ _ . _ . _ . _ . . . . . . . . . _ _ . . . _ _ . . . _ . .Y~s _ . _ . . . _ . _ _ . . . . _ _ . _ _ _ _ _ . . . _ . . . _ _ _ _ . . . _ . . . . _ _ _ _ _ _ _ _ _ _ . _ . . . . _ . _ . _ _ . . . . _ . . . . . . . 33 J$. pre$.ence. Qf H2S gas. Rrobable _ . . . _ _ _ _ _ _ _ _ _ _ _ . _ . . _ . . _ _ _ . _ . . . . . . . . . _ No_ _ . . _ _ ., . Drjlling mud .shQuJd. RrecJu.de H2S on the rig.. Rig js_e_quippe_dwitb sen.sors .aod alarms.. _ _ _ _ . . _ _ . _ . . _ . _ _ 34 Meçba.nical.cOlJd.itioo p{ wells within AOR verified (For_ s_ervice welJ on.ly). _ _ _ . _ . . . _ _ _ . . _NA _ _ _ ,. ,. . . _ . _ . . . . _ . _ . . . . _ . . . . . . . . . . . . . _ _ _ . _ . . . . _ _ _ _ _ _ . . _ . . . _ _ . . . _ _ _ _ _ _ . . _ _ . . . . 35 P~rmitcanbets$u.ed.w!Q.hydr.ogen.s.ulfidel)1eas.!Jre$. _....... _ _ _ _ _ _ _. _.. _.... _N.o. _ _. _.. .01Js_etw~lIsjA-25,.1.B:0.1.&1.B.-t3_measyred193,98,&_7.DPPIJ'l.H_2S..resp_ectiveIY,.iIJAIJ9.ust2.D02__.. _ _..._ 36 _D_ata_pr~selJted. Qn_ Rote_ntial oveJRre$.sure .ZQne$ _ . . . . _ . . . . . _ . ., . _ _ _ _ _ _ _ _ . _ . . . .Y~s . . _ _ _ . . I;xpeçted r~sel'\lojr pre.$$uJe i$ .11.9 ppg I;MW; KIJP. wiIJ be driJled. with_12..2_ppg (n.!Jc;I. _ . . _ . . . . _ _ _ . _ . . . . _ 37 _S~ismic.analysjs. Qf shallow gas.zpoes_ . . _ . . _ _ _ _ . . _ . . . . _ . _ _ _ _ _ _ . . _ . . . _ _ _ _NA _ . . _ _ . . . . . . _ . . . . . . . . _ _ _ . . . _ . . _ . . . _ _ _ _ . . _ . . . _ . _ _ _ _ . . . _ . _ . _ . . . . _ _ _ _ _ . . . _ _ . . . . 38 _Sßabed .condjtiolJ survey.(if off-ShPre) . _ _ _ _ _ . _ _ . _ _ . . . . . . . . _ . . . . _ _ . _ _ . . _ . NA . _ _ . . . _ . . . . . . . _ _ _ _ . _ . . . . . _ . . _ _ _ _ _ . _ _ . _ . . . _ . _ . _ . . . _ _ . _ . . . . . . . _ _ _ _ _ _ _ . . . _ . _ . . 39 _ CQnta.ct l1am.elptlon.e.for_wee~ly progre~s_reRort$ [exploratory _only]. . . . _ .. _ _ _ _ _ . _ . . _ . NA . . . . . . . _ . . . . . _ _ _ _ _ . _ . . _ . _ . . . _ _ _ _ _ _ _ . . . _ _ . . . _ . . . . _ _ _ . _ . . _ _ _ . _ . _ . _ . . _ _ . _ . . . . . o o ( ( Date: Engineering Commissioner: Date Spacing exception required: well may not be tested or produced until the exception is approved. Public Commissioner Date Rßt< 7/j03 ') Welll-1istory File APPENDIX Information af detailed nature that is not particulariy germane to the Well Pennitting Process but is part of the history file, To improve the readability of the Well History file and to sim'plify finding infamlation, information of this nature is accumulated at the end of the file under APPEN,DIX. No special effort has been made to chronologically organize this category of information. '~ ~~'~~Y\~ Aiaska O~·~ & Gs.~, CCf¡~· Commi~n Anchor~ RECE\VED AUG 2. 6 2.003 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE # REMARKS: 5222.0 8005.0 8636.0 9.625 7.000 12.250 8.500 7.000 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) # WELL CASING RECORD 88.90 60.90 9 11N 10E # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN MWD RUN 4 4 G. SUTING F. HERBERT MWD RUN 3 3 C. MEYER F. HERBERT JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: LDWG File Version 1.000 Extract File: LISTAPE.HED !! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! TAPE HEADER KUPARUK RIVER UNIT MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1B-20 500292316400 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 22-AUG-03 *** *** LIS COMMENT RECORD 01 **** TAPE HEADER **** LDWG 03/08/22 AWS 01 ;¿o~ò -f' **** REEL HEADER **** LDWG 03/08/22 aCB'-liS ') " ) GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 19' 40.285" LONG: W149 DEG 35' 51.339" LOG MEASURED FROM D.F. AT 88.9 FT. ABOVE PERM. DATUM (M.S.L.) , COMMENTS: (1) Baker Hughes INTEQ runs 1 and 2 utilized a Directional Only service from 138 - 5230 feet MD (138 - 4014' TVD). (2) Baker Hughes INTEQ run 3 utilized a Multiple Propagation Resistivity (MPR) and Gamma Ray with Near Bit Inclination services from 5230 - 8015 feet MD (4014 - 6032' TVD) , (3) Baker Hughes INTEQ run 4 utilized the slimhole Advantage Porosity Logging Service (APLS) which includes the Optimized Rotational Density (ORD), Caliper Corrected Neutron (CCN), along with MAP (Modular Annular Pressure) and MPR Resistivity services from 8015 - 8636 feet MD (6032 - 6592' TVD). (4) Per ConocoPhillips Alaska instructions, the Gamma Ray curve from this log is the depth reference for this well. As such, no depth shifts have been applied, REMARKS: (1) The interval from 138 - 5230 feet MD (138 - 4014' TVD) was drilled with directional tools. No formation evaluation logging was done in this interval. (2) Depth of 9 5/8" Casing Shoe-Logger: 5222 feet MD (4009' TVD) Depth of 9 5/8" Casing Shoe-Driller:5222 feet MD (4009' TVD) (3) Depth of 7" Casing Shoe-Logger: 8001 feet MD (6020' TVD) Depth of 7" Casing Shoe-Driller: 8005 feet MD (6023' TVD) (4) The Photoelectric data has been effected by barite in the mud system. (5) The interval from 8582 to 8636 feet MD (6544-6592' TVD) was not logged due to sensor-bit offset at TD. $ Tape Subfile: 1 86 records.,. Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** ! !!!!!!!!!!! !!!! !!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILE001.HED FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ ) clipped curves; all bit runs merged. ,5000 START DEPTH 5151. 0 STOP DEPTH 8636,0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 3 4 # REMARKS: MERGE TOP 5151. 0 7973,0 MERGE BASE 7973,0 8636,0 MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. NEUTRON-DENSITY TOOLS (CCN-ORD) WERE NOT USED ON RUN 3, CCN & ORD DATA IS EMPTY (NULL VALUES) ABOVE THE 7" CASING POINT (8005' MD). $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT IB20 5.xtf 150 conocoPhillips Alaska, Inc. IB-20 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ---------------------------------------------------- ODEP GR RPD RPM RPS RPX RHOB DRHO PEF NPHI ROP FET MTEM GR RPD RPM RPS RPX RHOB DRHO PEF NPHI ROP FET MTEM GRAM RPD RPM RPS RPX BDCM DRHM DPEM NPCKSM ROPS RPTH TCDM * FORMAT RECORD (TYPE# 64) 0,0 0.0 0.0 0.0 0.0 0.0 0.0 0,0 0.0 0.0 0,0 0.0 Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet log header data for each bit run in separate files. 3 .2500 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: 2 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILEOl1.HED *** LIS COMMENT RECORD *** 1024 LDWG .002 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 418 records.,. Tape Subfile: 2 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5151.000000 8636,000000 0.500000 367 Total Data Records: ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 RHOB MWD 68 1 G/C3 4 4 7 DRHO MWD 68 1 G/C3 4 4 8 PEF MWD 68 1 BN/E 4 4 9 NPHI MWD 68 1 PU-S 4 4 10 ROP MWD 68 1 FPHR 4 4 11 FET MWD 68 1 HR 4 4 12 MTEM MWD 68 1 DEGF 4 4 ------- 48 0.500 * F FRAME SPACE = Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 ) ) ) # FILE SUMMARY VENDOR TOOL CODE START DEPTH MWD 5151.0 $ STOP DEPTH 7973.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RESIST, GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # ) 17-JUL-03 MSB 18704 6.75 MPR MEMORY 8015.0 5151. 0 7973.0 o 24.6 51.4 TOOL NUMBER DAS 1363 MPR 9838 SRIG 31880 8,500 5222.0 LSND 9.55 .0 .0 300 .0 ,000 .000 .000 .000 134,0 .0 .0 .0 .00 .000 .0 o BIT RUN 2 (MWD Run 3) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: REMARKS: ) ) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1B20.xtf 150 ConocoPhillips Alaska, I 1B-20 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0,0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0,0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 TOOL NUMBER DAS 10034690 24.2 27.7 MSB 18704 4.75 TC MEMORY 8636.0 7973.0 8636.0 o 22-JUL-03 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DIR DIRECTIONAL # # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8636,0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ START DEPTH 7973.0 log header data for each bit run in separate files. 3 .2500 ) 4 !!!!!!!!!!!! !!! ! !!! LDWG File Version 1.000 !!! !!!!!!!!! !!! !!!! Extract File: FILE012.HED *** LIS COMMENT RECORD *** 1024 LDWG .006 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 694 records,., Tape Subfile: 3 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5151.000000 7973.000000 0.250000 595 Total Data Records: 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 ) CCN ORD MPR GRAM $ SDN 68110 SDN 68110 MPR 54694 SRIG 58109 CAL. COR. NEUTRON OPT. ROT. DENSITY MULT, PROP. RESIS. GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 7.000 8005.0 # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 12,20 ,0 ,0 300 .0 .000 ,000 .000 .000 139.0 .0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): ,00 ,000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): ,0 o # REMARKS: BIT RUN 3 (MWD Run 4) , GR/MPR/oRD/cCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/CC) DRHM - DENSITY CORRECTION (G/CC) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN IB20.xtf 150 ConocoPhillips Alaska, I IB-20 ) FN COUN STAT Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0,0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0,0 RACH RACH RAS 0.0 RASH RASH RACSHM 0,0 BDCM BDCM BDCM 0.0 DRHM DRHM DRHM 0,0 DPEM DPEM DPEM 0,0 NPCK NPCK NPCKSM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 68 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 14 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 BDCM MWD 68 1 G/C3 4 4 11 DRHM MWD 68 1 G/C3 4 4 12 DPEM MWD 68 1 BN/E 4 4 13 NPCK MWD 68 1 PU-S 4 4 14 ROPS MWD 68 1 FPHR 4 4 15 RPTH MWD 68 1 MINS 4 4 16 TCDM MWD 68 1 DEGF 4 4 ------- 64 ) J Total Data Records: 190 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7973.000000 8636.000000 0,250000 feet **** FILE TRAILER **** Tape Subfile: 4 300 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 03/08/22 01 **** REEL TRAILER **** LDWG 03/08/22 AWS 01 Tape Subfile: 5 2 records", Minimum record length: Maximum record length: 132 bytes 132 bytes