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Home My WebLink About201-088Originated: Delivered to:12-Nov-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 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 1D-30 50-029-22965-00 910358412 Kuparuk River Leak Detect Log Field- Final 14-Oct-25 0 12 1D-30 50-029-22965-00 910358412 Kuparuk River Multi Finger Caliper Field & Processed 15-Oct-25 0 13 1D-30 50-029-22965-00 910390851 Kuparuk River Packer Setting Record Field- Final 31-Oct-25 0 14 1E-02 50-029-20472-00 910390619 Kuparuk RiverMulti Finger CaliperField & Processed 28-Oct-25 0 15 1E-36 50-029-22927-00 910357198 Kuparuk River Tubing Cut Record Field- Final 19-Oct-25 0 16 2U-06 50-029-21282-00 910390614 Kuparuk River Multi Finger Caliper Field & Processed 19-Oct-25 0 17 3K-20 50-029-23019-00 910390195 Kuparuk River Packer Setting Record Field- Final 22-Oct-25 0 18 3R-17 50-029-22242-00 910433126 Kuparuk River Packer Setting Record Field- Final 11-Nov-25 0 1910PLEASE 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:200-104180-050198-213185-019201-088192-005T41088T41088T41088T41089T41090T41091T41092T41093Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.11.12 11:46:38 -09'00'3K-2050-029-23019-00 910390195KuparukRiverPacker Setting RecordField- Final22-Oct-2501201-088 Originated: Delivered to:9-Oct-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 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 2P-422A 50-103-20400-01 910312860 Kuparuk River Multi Finger Caliper Field & Processed 23-Sep-25 0 12 2P-422A 50-103-20400-01 910313140 Kuparuk River Multi Finger Caliper Field & Processed 28-Sep-25 0 13 2X-12A 50-029-21189-01 910262801 Kuparuk River Leak Detect Log Field- Final 26-Aug-25 0 14 3G-07A 50-103-20127-01 910313294 Kuparuk RiverLeak Detect LogField- Final 14-Sep-25 0 15 3K-20 50-029-23019-00 910312855 Kuparuk River Multi Finger Caliper Field & Processed 26-Sep-25 0 16 3K-32 50-029-22763-00 910292590 Kuparuk River Multi Finger Caliper Field & Processed 31-Aug-25 0 17 3Q-07 50-029-21682-00 910313132 Kuparuk River Tubing Cut Record Field- Final 28-Sep-25 0 18 3Q-09 50-029-21674-00 910313102 Kuparuk River Plug Setting Record Field- Final 13-Sep-25 0 19 3T-617 50-103-20918-00 910346072 Kuparuk River Radial Bond Record Field & Processed 25-Sep-25 0 110 1B-10 50-029-20656-00 910325714 Kuparuk RiverLeak Detect Log with IntelliScopeField & Processed 16-Sep-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:T40970202-067195-176190-085201-088197-076186-194186-186225-053181-135T40974T40974T40975T40976T40977T40978T40979T40980T409813K-2050-029-23019-00910312855Kuparuk RiverMulti Finger CaliperField & Processed26-Sep-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.10.09 13:02:18 -08'00' Originated: 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 2P-419 50-103-20483-00 910080528 Kuparuk River Multi Finger Caliper Field & Processed 7-Jun-25 0 12 2P-429 50-103-20378-00 910080397 Kuparuk River Multi Finger Caliper Field & Processed 8-Jun-25 0 13 2T-38A 50-103-20229-01 910106462 Kuparuk River Plug Setting Record Field- Final 8-Jun-25 0 14 2Z-07 50-029-20946-00 910026798 Kuparuk River Plug Setting Record Field- Final 10-May-25 0 15 3K-20 50-029-23019-00 910080196 Kuparuk River Packer Setting Record Field- Final 18-May-25 0 16 3N-12 50-029-21582-00 910080396 Kuparuk River Multi Finger Caliper Field & Processed 3-Jun-25 0 17 3N-12 50-029-21582-00 910080396 Kuparuk River Plug Setting Record Field- Final 3-Jun-25 0 18 3N-12 50-029-21582-00 910080396 Kuparuk River Plug Setting Record Field- Final 4-Jun-25 0 19 3N-12 50-029-21582-00 910080396 Kuparuk River Plug Setting Record Field- Final 6-Jun-25 0 110PLEASE 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:T40597T40598T40599T40600T40601T40602T40602T40602T40602204-017201-102197-205183-064201-088186-0796/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.20 08:47:18 -08'00'201-0883K-2050-029-23019-00 910080196KuparukRiverPacker Setting RecordField- Final18-May-2501 STATE OF ALASKA AAA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon H Plug Perforations LJ Fracture Stimulate LJ Pull Tubing U Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Tubing Patch 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development Q Exploratory ❑ 201-088 3.Address: PO Box 100360 Stratigraphic H Service ❑ 6.API Number: Anchorage,AK 99510 50-029-23019-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025519 KRU 3K-20 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk Oil Pool 11.Present Well Condition Summary: Total Depth measured 12,692 feet Plugs measured N/A feet true vertical 6,870 feet Junk measured N/A feet Effective Depth measured 12,692 feet Packer measured 12,212 feet true vertical 6,870 feet true vertical 6,460 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 158 16" 190 190 Surface 7,672 7-%" 7,706 4,138 Intermediate Production 12,660 5-1/2'x 4-1/2"x 3-'W 12,692 12,692 Liner Perforation depth Measured depth 12,270- 12,438 feet SCANNED J.4 w , .. h,I;n True Vertical depth 6,509-6,653 feet Tubing(size,grade,measured and true vertical depth) 3-W L-80 12,229 6,474 Packers and SSSV(type,measured and true vertical depth) Seal Assembly 12,212 6,460 Upper Patch Packer Paragon-II 12,102 6,368 Lower Patch Packer Paragon-II 12,134 6,395 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A N/A N/A - Subsequent to operation: N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development Service ❑ Stratigraphic H Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil H Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG H GINJ H SUSP❑ SPLUG H 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Travis SmithContact Name: Rachel Kautz/Travis Smith Authorized Title: Well Integrity Supervi or Contact Email: N2549 c(�.conocophillips.com j�l/ Authorized Signature: r% �/‘ ‘‘ 4 Date: 44 Contact Phone: 659-7126 Form 10-404 Revised 4/2017 L 02/I 1 ,� Submit Original Only 014/ RBDMS L(/JAN 1 1 2{1U • • 101-' . . RECEIVED ConocoPhillips f U Alaska AN 20f8 P.O. BOX 100360 OG CC ANCHORAGE,ALASKA 99510-0360 January 8, 2018 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner French: Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set in producer KRU 3K-20 (PTD#201-088). The existing tubing POGLM patch was pulled and replaced with a standard retrievable patch. Please contact Rachel Kautz or myself at 659-7126 if you have any questions. Sincerely, r </jej Travis Smith Well Integrity Supervisor ConocoPhillips Alaska,Inc. • • Mikis Recent Well History &Wens 3K-20 ConocoPhilltps Legal WellName API/UWI Field Name 3K-20 5002923019 KUPARUK RIVER UNIT Well Type Orig KB/RT(ft) Well Status Development 68.60 PROD Start Date Last 24hr Sum 12/30/2017 PULLED 3"TTS TEST TOOL @ 12,102'RKB. JOB COMPLETE. 12/29/2017 COMBO MIT,TBGXIA PASS 2500PSI 3BBLS TO PUMP UP, BLEED BACK 2.2BBLS DSL,TBG&IA @ 1000PSI JOB COMPLETE 12/29/2017 BULLHEAD 100 BBLS CISW AND 45 BBLS F/P DOWN IA. WITH CMDFRE! SET UPPER 2.72"PIIP PACKER PATCH ASSEMBLY MID ELEMENT @ 12,102'RKB. SET 3"TTS TEST TOOL IN UPPER PACKER. MITT TBG TO 2500 PSI(PASS) LRS TO CMIT. IN PROGRESS. 12/28/2017 MEASURED BHP @ 12,104'RKB(1298 PSI) MITT TBG TO 2000 PSI(PASS) PULLED TTS TEST TOOL& UPPER 2.72"PIIP PACKER POGLM ASSEMBLY @ 12,104'RKB. IN PROGRESS. 12/27/2017 SET 3"TTS TEST TOOL IN UPPER PACKER @ 12,104'RKB. PULLED GLV @ 11,507'RKB&SET OV. PULLED GLVs @ 10,205',7821'&4462'RKB AND REPLACED WITH NEW. IN PROGRESS. Page 1/1 Report Printed: 1/8/2018 KUP PROD • 3K-20 ConocoPhillips ° Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Incl C) MD(ROB) Act Btm(ftKB) -ionoe1� 500292301900 KUPARUK RIVER UNIT PROD 67.18 7,897.24 12,706.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3K-20,122018352:44 PM SSSV:NIPPLE 90 1/12/2017 Last WO: 68.60 8/9/2001 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date __...,.,...___ Last Tag:RKB 12,492.0 10/21/2017 Rev Reason:GLV C/O,PULL POGLM,SET 3" pproven 1/2/2018 HANGER,292- -�1 �� TTS&PATCH ASSEMBLY,PULL 3"TTS Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 32.0 190.0 189.9 151.53 X-65 WELD ,,,,,,I, r Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread - SURFACE 75/8 6.875 34.1 7,706.2 4,137.8 29.70 L-60 BTCM Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 51/2 4.950 32.2 12,691.7 6,870.3 15.50 L-80 BTCM _5.6x4.5x3.5@12190' CONDUCTOR;32.0-190.0 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 3 1/2 2.992 29.3 12,228.5 6,474.4 9.30 L-80 EUE 8rd Completion Details NIPPLE;521.0 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 29.3 29.2 0.57 HANGER 31/2"x11"FMC GEN VTbg Hanger w/31/2'L-80 EUE 2.992 8rd Pin 521.0 519.5 8.06 NIPPLE 31/2"Camco'DS'nipple w/2.875"No-Go profile 2.875 GAS LIFT;4,461.6 _ 12,166.2 6,421.6 32.60 NIPPLE 3 1/2"Camco'D'Nipple w/2.750"No-Go profile 2.750 `I 12,210.8 6,459.3 31.81 LOCATOR Baker 4.5"No-Go locator 3.000 J 12,212.0 6,460.4 31.79 SEAL ASSY 4"x 3"Baker GBH-22 15'seal assy 3.000 • • Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 12,102.0 6,367.9 33.85 PATCH 1 11/16"SHORN&PATCH ASSEMBLY=2.72" 12/29/2017 1.610 SURFACE;34.1-7,706.2 ASSEMBLY PIIP PACKER(CPP35151)27.78'x 2 1/16" SPACER PIPE&ANCHOR SEAL ASSEMBLY (CPAL35078)33.14'OAL/1.61"MIN ID GAS LIFT;7,821.2 i, £ 12,134.0 6,394.6 33.17 PATCH 2.72"P2P W/AGGRESSIVE SLIPS(#CPP35137/ 10/29/2017 1.625 4.01'OAL/1.625"ID) 12,492.0 6,699.0 31.38 RETAINER CEMENT RETAINER-SQZ'D CEMENT THRU 7/21/2001 0.000 L_ PERFS Perforations&Slots GAS LIFT;10,204.6 Shot Dens Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 12,270.0 12,280.0 6,509.8 6,518.3 UNIT B,3K- 7/15/2002 6.0 CMT 2.5"HC DP PJ Chrgs; 20 SQZ 60 deg ph GAS LIFT;11,506.5 12,385.0 12,405.0 6,607.8 6,624.8 A-3,A-2,3K- 3/16/2010 6.0 CMT 2.5"Millenium HMX DP, 20 SQZ 60 deg phase 12,386.0 12,396.0 6,608.6 6,617.1 A-3,3K-20 7/15/2002 6.0 CMT 2.5"HC DP PJ Chrgs; SQZ 60 deg ph 12,418.0 12,438.0 6,635.9 6,652.9 A-2,3K-20 8/9/2001 6.0 APERF 2.5"HC DEP HSD PJ HMX PATCH ASSEMBLY;72,102.0 - GAS LIFT;12,116.5 1• Stimulations&Treatments • 1 Proppanr Designed(Ib) I Proppant In Formation(Ib) (Date 8/12/2001 Stimulations&Treatments ii Vol Clean Pump PATCH;12,734.0 1I I Stg 6 I Top(ftKB) Btm(ftKB) I Date I Stim/Treat Fluid (bbl) Vol Slurry(bbl) 1 12,418.0 12.438.0 8/12/2001 ll Cement Squeezes Top(TVD) Btm(ND) Top(ftKB) Btm(ftKB) (10(9) (ftKB) Des Start Date Com NIPPLE;12,766.2 �. 12,245.0 12,522.0 6,488.5 6,724.6 CMT SQZ 7/17/2001 Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(In) Sery Type Type (ie) (psi) Run Date Com 1 4,461.6 2,700.6 Camco KBG-2- 1 GAS LIFT GLV INT 0.156 1,375.0 12/27/2017 9 2 7,821.2 4,184.8 Camco KBG-2- 1 GAS LIFT GLV INT 0.188 1,398.0 12/27/2017 9 LOCATOR;12,210.8 NIII 3 10,204.6 5,237.0 Camco 'KBG-2- 1 GAS LIFT GLV INT 0.188 1,390.0 12/27/2017 11,S.19 4 11,506.5 5,920.6 Camco KBG-2- 1 GAS LIFT OV INT 0.250 0.0 12/27/2017 SEAL ASSY;12,212.0 9 11 5 12,116.5 6,380.0 Camco KBG-2- 1 GAS LIFT OPEN 10/28/2017 9 iNotes:General&Safety CMT SOZ;12,270.0-12,280.0 End Date Annotation 7/17/2005 -NOTE:TBG x IA LEAK APPEARS TO BE BELOW 11570'SLM o. 3/4/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 CEMENT SQZ;12,245.0 568 01 CMT SQZ;12,386.0-12,396.0 CUT SQZ;12,385.0-12,405.0 gWig�y ..-;:i,W 4 V FRAC;12,418.0 RI Li APERF;12,418.0-12,438.0 Q 51 RETAINER;12,492.0 '+k VIVA PRODUCTION 5.6x4.503.5®12190';32.2-- r 12,691.7 RECEIVED STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMISSION NOV 2 7 2017 REPORT OF SUNDRY WELL OPERATIONSA �j 1.Operations Abandon LI Plug Perforations H Fracture Stimulate U Pull Tubing ® Fi H ❑ Operations s utdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Tubing Patch E 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska,Inc. Development E Exploratory ❑ 201-088 3.Address: PO Box 100360 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99510 50-029-23019-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025519 KRU 3K-20 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk Oil Pool 11.Present Well Condition Summary: Total Depth measured 12,692 feet Plugs measured N/A feet true vertical 6,870 feet Junk measured N/A feet Effective Depth measured 12,692 feet Packer measured 12,212 feet true vertical 6,870 feet true vertical 6,460 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 158 16" 190 190 Surface 7,672 7-%" 7,706 4,138 Intermediate Production 12,660 5-%"x 4-1/2'x 3-%" 12,692 12,692 Liner Perforation depth Measured depth 12,270- 12,438 feet True Vertical depth 6,509-6,653 feet Tubing(size,grade,measured and true vertical depth) 3-%" L-80 12,229 6,474 Packers and SSSV(type,measured and true vertical depth) Seal Assembly 12,212 6,460 Upper Patch Packer Paragon-II 12,104 6,370 Lower Patch Packer Paragon-II 12,134 6,395 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): :,r cf SCANNED 1 2 2 0-F Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development❑., Service H Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 2 Gas H WDSPL H Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG H GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Rachel Kautz Contact Name: Rachel Kautz/Travis Smith Authorized Title: Well Integrity Supervisor Contact Email: N2549(@conocophillips.com Authorized Signature: /JPP//�.s� ,y Date: //—7 y"/ " Contact Phone: 659-7126 Form 10-404 Revised 4/2017 VT-t- 12/71<. Submit Original Only ir(AN RED MS V/ NOV 2 2017 • • �►' . . RECEIVED ConocoPhilhps Alaska NOV L 7 2017 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 /oGCC November 19, 2017 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner French: Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch with POGLM set in producer KRU 3K-20 (PTD# 201-088). Please contact Travis Smith or myself at 659-7126 if you have any questions. Sincerely, / Rachel Kautz Well Integrity Supervisor ConocoPhillips Alaska, Inc. Recent Well History 3K-20 C nocooPhillips Legal WellName API/UWI Field Name 3K-20 5002923019 KUPARUK RIVER UNIT Well Type Orig KB/RT(ft) Well Status Development 68.60 PROD Start Date Last 24hr Sum 11/4/2017 (AC EVAL):TIFL(PASSED). 10/30/2017 2.72"P2P(#CPP35139),SPACER PIPE, POGLM(INT LATCH- 1/4"PORT OV, IN CENTER OF POGLM),SPACER PIPE,ANCHOR LATCH(#CPAL35069/30.89'OAL/22.5'FROM TOP OF PKR TO MIDDLE OF POGLM)MID ELEM @ 12,104'RKB. SET TEST TOOL IN PKR.MIT TBG TO 2500(PASS).PULLED TEST TOOL.READY FOR TIFL. 10/29/2017 SET 2.72"P2P W/AGGRESSIVE SLIPS(#CPP35137)MID-ELEM @ 12,134'RKB.SET TEST TOOL IN PKR.PUMP 120 BBLS DIESEL TO LOAD TBG x IA.CMIT TO 2500(PASS).PULLED TEST TOOL.IN PROGRESS. 10/28/2017 SET CATCHER @ 12,166'RKB. PULLED EXTENDED PKG DV @ 12,116'RKB. PULLED CATCHER.BRUSHED& FLUSHED PATCH INTERVAL FROM 12,086'TO 12,151'RKB.DRIFTED 2.74"x25'DMY PATCH TO 12,166'RKB. (TOOLS COMING BACK FULL OF SAND).IN PROGRESS. Page 1/1 Report Printed: 11/13/2017 KUP PROD • 3K-20 ConocoPhillips t Well Attributes Max Angle&MD TD Alaska,INC. Wellbore API/UWI Field Name Wellbore Status II ncl 7) MD(ftKB) Act Blm(ftKB) o", yMes 500292301900 KUPARUK RIVER UNIT PROD 67.18 7,897.24 12,706.0 ,a., Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) )Rig Release Date 3K-20,11/17/20172'42'42 PM SSSV:NIPPLE 90 1/12/2017 Last WO: 68.6011 8/9/2001 Vertical schematic(actual) Annotation Depth(ftKB) End Data Annotation Last Mod By End Date ........................................., Last Tag:RKB 12,492.0 10/21/2017 Rev Reason:TAG,H2S,GLV C/O,SET PATCH pproven 11/17/2017 HANGER;292- let Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 32.0 190.0 189.9 151.53 X-65 WELD Casing Deseription OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE _ 75/8 6.875 34.1 7,706.2 4,137.8 29.70 L-80 BTCM Casing Description OD(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 51/2 4.950 32.2 12,691.7 6,870.3 15.50 L-80 BTCM aaa,5.6x4.5x3.5@12190' CONDUCTOR;32.0-190.0 ., Tubing Strings Tubing Description I String Ma...I ID(in) I Top(ftKB) I Set Depth(It..I Set Depth(TVD)(...I WI(Ib/ft) I Grade I Top Connection TUBING 3 1/2 2.992 29.3 12,228.56,474.4 9.30 L-80 EUE 8rd Completion Details NIPPLE;521.0VI Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Com (in) $-- 29.3 29.2 0.57 HANGER 3 1/2"x 11"FMC GEN V Tbg Hanger w/3 1/7'L-80 EUE 2.992 8rd Pin 521.0 519.5 8.06 NIPPLE 3 1/2"Cameo'DS'nipple w/2.875"No-Go profile 2.875 GAS LIFT;4,461.6 12,166.2 6,421.6 32.60 NIPPLE 31/2"Camco'D'Nipple w/2.750"No-Go profile 2.750 12,210.8 6,459.3 31.81 LOCATOR Baker 4.5"No-Go locator 3.000 12,212.0 6,460.4 31.79 SEAL ASSY 4"x 3"Baker GBH-22 15'seal asst' 3.000 ', Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (") Des Com Run Date ID(in) 12,104.0 6,369.6 33.80 PATCH 2.72"P2P(#CPP35139),SPACER PIPE,POGLM 10/30/2017 1.625 SURFACE;34.1-7,708.2 • W/POGLM (INT LATCH-1/4"PORT OV IN CENTER OF POGLM),SPACER PIPE,ANCHOR LATCH (#CPAL35069/30.89'OAL/22.5'FROM TOP OF I PKR TO MIDDLE OF POGLM) 2 I GAS LIFT;7,821 111 12,134.0 6,394.6 33.17 PATCH 2.72"P2P W/AGGRESSIVE SLIPS(#CPP35137/ 10/29/2017 1.625 4.01'OAL/1.625"ID) 12,492.0 6,699.0 31.38 RETAINER 'CEMENT RETAINER-SQZ'D CEMENT THRU 7/21/2001 0.000 PERFS GAS LIFT;10,204.6 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) Shot Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 12,270.0 12,280.0 6,509.8 6,518.3 UNIT B,3K- 7/15/2002 6.0 CMT 2.5"HC DP PJ Chrgs; 20 SQZ 60 deg ph GAS LIFT;11.50E5 12,385.0 12,405.0 6,607.8 6,624.8 A-3,A-2,3K- 3/16/2010 6.0 CMT 2.5"Millenium HMX DP, 20 SQZ 60 deg phase 12,386.0 12,396.0 6,608.6 6,617.1 A-3,3K-20 7/15/2002 6.0 CMT 2.5"HC DP PJ Chrgs; SQZ 60 deg ph 12,418.0 12,438.0 6,635.9 6,652.9 A-2,3K-20 8/9/2001 6.0 APERF 2.5"HC DEP HSD PJ PATCH W/POGLM;12,104.0, HMX GAS LIFT;12,116.5 Stimulations&Treatments Proppanl Designed(Ib) IProppant In Formation(Ib) (Date 8/12/2001 Stimulations&Treatments PATCH;12,134.0 St 0 TopftKB elm ftKB Dale Stim/Treat Field Vol Clean Pump gI (ftKB) (ftKB) I (bbl) Vol Slurry(bbl) 1 12,418.0 12,438.0 8/12/2001 Cement Squeezes NIPPLE;12,166.2 To(p ND) 0101(TBV)D) 11, Top(ftKB) Btm(ftKB) Des I Start Date 1 Com 12,245.0 12,522.0 6,488.5 6,724.6 CMTSQZ 7/17/2001 Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(RKB) (RKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Com 1' 4,461.6 2,700.6 Comm KBG-2- 1 GAS LIFT GLV BTM 0.156 1,351.0 8/12/2017 ' 9 I2 7,821.2 4,184.8 Cameo KBG-2- 1 GAS LIFT GLV BTM 0.156 1,309.0 8/12/2017 LOCATOR;12,210.8 9 11 3 10,204.6 5,237.0 Comm KBG-2- 1 GAS LIFT GLV BTM 0.188 1,340.0 8/11/2017 9 SEAL ASSY;12,212.0 "` 4 11,506.5 5,920.6 Cameo KBG-2- 1 GAS LIFT GLV BTM 0.188 1,333.0 8/11/2017 9 5 12,116.5 6,380.0 Cameo KBG-2- 1 GAS LIFT OPEN 10/28/2017 9 CMTSQZ;12,270.0-12,280.0 Notes:General&Safety ...!:i' i End Dale Annotation 7/17/2005 NOTE:TBG x IA LEAK APPEARS TO BE BELOW 11570'SLM CEMENT SQZ;12,245.0 RKB 3/4/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 CMT SQZ;12,386.0-12,396.0 1` RI CMT SOZ;12,385.0-12,405.0 �y FRAC:12,418.0 M M APERF;12,418.0-12,438.0 i>,` 's i RETAINER;12,492.0 ". :jiII'% PRODUCTION 5.6x4.5x3.5(d 12190';32.212,691.7 Imag~,' '"roject Well History' File Cover ~' ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~D.L- ~)~ Well History File Identifier Organizing l~o,,~:~ [] RESCAN ~ Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: AL DATA Diskettes, No. ~ [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL~INDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL,~~)NINDY Scanning Preparation _~ x30= ~O BY: BEVERLY ROBIN VINCENT SHERYL~WINDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other = TOTALPAGES ~~ DA'I'E: ~~/O~~S/ ~ Production Scanning Stage I PAGE COUNT FROM SCANNED F~LE: ........ ~~.. PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION' ~,~'" YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES (SCANNING IS COMI~LETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO RESCANNEDB~': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 26, 2011 r Commissioner Dan Seamount U- Alaska Oil and Gas Commission 333 West 7 Avenue, Suite 100 Alaska Oil & n Anchorage, AK 99501 Conte_ "'lSSip a, i Commissioner Dan Seamount: K c�o 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 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 10/18, 10/19 and, 10/21, 2011. 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 Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, _° � DE 1 3 Z U 1 AtZri Martin Walters ConocoPhillips Well Integrity Projects Supervisor e • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 10/26/11 2L, 3K, 3M & 3Q PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 2L -301 50103205880000 2081920 10" N/A 10" N/A 1.7 10/18/2011 r) . 3K -20 50029230190000 2010880 SF N/A 14" N/A 1.7 10/19/2011 3K -24 50029229350000 1982490 SF N/A 24" N/A 3.5 10/19/2011 3M -01 50029216600000 1870120 SF N/A 12" N/A 5.95 10/21/2011 3M -03A 50029216960100 2081790 SF N/A 18" N/A 5.1 10/21/2011 3M -08 50029217090000 1870280 SF N/A 17" N/A 2.85 10/21/2011 3M -11 50029217180000 1870380 SF N/A 26" N/A 4.25 10/21/2011 3M -21 50029217390000 1870660 SF N/A 15" N/A 3.4 10/21/2011 3Q -03 50029222210000 1911260 SF N/A 18" N/A 3.45 10/19/2011 30-07 50029216820000 1861940 SF N/A 17" N/A 4.68 10/21/2011 3Q -08A 50029216810100 1971930 SF N/A 15" N/A 3.55 10/21/2011 30-09 50029216740000 1861860 SF N/A 13" N/A 4.4 10/21/2011 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 23, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 3K -20 _.:_ r ; ` ti Run Date: 8/21/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3K -20 Digital Data in LAS format, Digital Log Image file + C1 �7 , 1 CD Rom 50- 029 - 23019 -00 l 1 Bottom Hole Pressure Survey Log 1 Color Log 50- 029 - 23019 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: a � --2 Signed: IL,0 Oit.0 ALASK~ AND GAS CONSERVATION COMMIS~1 ~~~~ REPORT OF SUNDRY WELL OPERATIONS . ~~ _ _ ,,,,,,, 1. operations Performed: Abandon Repair w ell Rug F~rforations Stimulate " er Alter Casing ~ Pull Tubing ~ Perforate New Pbol Waiver " Ti ~~~OIYI~IISSIOfI Change Approved Program ~ Operat. Shutdow n Perforate Re-enter Suspended W 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory 201-088 3. Address: Stratigraphic Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23019-00 7. Prop@rty Designation: 8. Well Name and Number: \ ADL 25519 ~ 3K-20 9. Field/Pool(s): Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 12706 feet Plugs (measured) 12492' true vertical 6883 feet Junk (measured) None Effective Depth measured 12492' feet Packer (measured) true vertical 6699' feet (true vertucal) Casing Length Size MD TVD Burst Collapse CONDUCTOR 158 16 158' 158' SURFACE 7637 7.625 7706 4137' PRODUCTION 12121 5.5 12190 6442' PRODUCTION 434 4.5 12624 6812' PRODUCTION 67 3.5 12691 6870' Perforation depth: Measured depth: 12270'-12280', 12385'-12405'. 12418'-12438' True Vertical Depth: 6510'-6518', 6608'-6625', 6636'-6653' ~;^ ~"°yy~y5' ~~~'~ ~ ~~ ~~~~ Tubing (size, grade, MD, and TVD) 3.5, L-80, 12229' MD, 6474 TVD Packers & SSSV (type, MD, and TVD) no packer NIPPLE - 3 1/2" Camco'DS' nipple w/ 2.875" No-Go profile @ 521 MD and 520 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 11011e Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 412 1646 4 -- 165 Subsequent to operation 410 1651 4 -- 164 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory Development Service . Well Status after work: Oil Gas WDSPL Daily Report of Well Operations XXX GSTOR "! WAG ~""" GASINJ ~` WINJ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce (7a 265-6471 Printed Name John Peirce Title Wells Engineer Signature ~. Phone: 265-6471 Date Form 10-404 Revised 7/2009 R~D~ ~ ~ ~ ~o~~F~~ Submit Original Only 3K-20 Well Events Summary DATE SUMMARY 3/3/10 TAGGED @ 12458' SLM. GAUG~TBG TO 2.78" TO D NIPPLE @ 12128' S~ 12166' RKB; 850# P/U WT. READY FOR E/L. 3/16/10 PERFORM REPERF OF THE A3 SAND FROM A DEPTH OF 1~R~i~-1 40 '._TAG FILL AND CONFIRM TD OF 12462' WITH BOTTOM OF THE PERFORATING GUN. PERFORATIONS WERE MADE WITH MILLENIUM HMX DP 2 1/2" , 6 SPF , 60 DEG PHASE PERF GUN. TUBING PRESSURE WAS 600 AND REACHED 1000 PSI ON TRIP OOH. ° `. ~ . ~UtlOC4P~1t~~1~-S r HANGER. 25 32-192 NIPPLE 521 GFlS SURFACE,- 33-7.706 GAS LIFT, _ ],821 GAS LIFT, 10,205 GAS LIFT. 11,506 GAS LIFT, 2.1'.J 12.166 - LOCATOR, 12.211 SEAL ASSV, 12.212 CEMENT SOZ. 12.'2x5 APERF, 122]0-12 280 APERF, 12.386-12,396 RPERF, 12385-12 405 APERF, FRAC, 12.418 A RETAINER, t2,asz CEMENT SOZ. 12.520 PROOUCrION. az-1 zssz ~ TD. 12,]06 '~ 500292301900 Ic t KUP RIVER UNIT 3K-20 cna Mme ra JnJ y - am MLJ {pP nJ uate notai on I e l NIPPLE 7 (7 1/9/2009 Last WO I 6860 8/9/2001 5SSV Last Mod .. E d Date A Cation 'i Depth (ft KB) Entl D i Annotation ( _1G Rev Reason~PERFORATIONS Imosbor 3/20/2010 Last lag~SLM 12462.0 3/1C . l;asingStrings . Casing Descr pt on String 0... Stripy ID ... Top (ftK6) Set Depth (t... SetDapth (ND) . .String Wl...;S~ IString Top Thrd CONDUCTOR 16 157J fit 32.0 192.0 191.9 151.53 X-65 WELD _ Casing Description String 0... Siring ID ... Top (ftK8) Set Depth (f... Set Depth (ND) ...String Wt....String ... String Top Thrd SURFACE 7518 6.87` 33.4 7,706.2 4,137.5 29.70 L-80 BTCM Casing Description String 0... String ID ... Top (HKB) Set Depth (f... Set Depth (ND) ...'String Wt... IString ...IString Top Thrd PRODUCTION 51;2 4.5CSti 32.2 12,691.7 6,870.3 15.50 L-80 BTCM Tubing Strings T Erng Des pt on Str ng 0... Str g ID ._ Top (ftK8) Set Depth (f... Set D pth (ND) . '~Shing Wt... Str ng ... String Top Thrtl 12 29.3 12.228.5 6 414.4 _._y 9.30 L 80 EUE Srd I UBING '. 3 1/2 _ lion Details __ ___„____ Com le _ - 'iTap Depth _ (ND) Top Intl Nomi... (ftK6) Top (ftK6) (°) Item D crlption Comment ID (in) I 29.3 29.3 5.27 HANGER 3 112" x 11" FMC GEN V Tbg Hanger wl 3 1/2" L-80 EUE Srd Pin 2.992 521.0 579.5 8.06 NIPPLE - 3 112" Camco'DS' nipple w/ 2.875" No-Go profde 2.875 12,166.2 6.421.5 31.83 NIPPLE 3 1/2" Camco'D' Nipple w/ 2.750" No-Go profile 2.750 12,270.8 6.459.3 31.72 LOCAI OR Baker 4.5" No-Go locator 3.000 _._ _-- 12.212.01 6.460.4 31.72' SEAL ASSb' 4" x 3" Baker GBH-22 15'seal assy 3.000 ~- eretrievable plugs, valves, pumps, fish,. etc.) <; Other In Hole {Wirelin _ Top Depth J l (TVD) '.Top !pol TOp (ftK6) (HKB) (I Des 1 r: Comment Run Data ID (in) ~q ~ 72 492 6 69&0 ~ 51 ,8 ~ RE I a.i r II I ; Set cement retainer thru squeezed peds 7/21/01 7/21/2001 0.000 _ _. __.. Perforations & Slots . .. _ . snot! ~ ~ Top (TVD) Btn~: TL _~1 Dens Top (HKB) Bhn (kKB). (ftK8) 1111(61 Zone Date (s H... Type Comment 12,270 12,280 6,509.8 15.578. i UNIT B, 3K-20 7/15/2002 6.0 APERF 2.5" HC DP PJ Chrgs; 60 deg ph 12,385 12,405 6,607.8 6.624,9 A-3, A-2 3K-20 3116!2010 6.0 RPERF 2.5" Millenium HMX DP, 60 deg phase 12,386 12,396 6,608.6 F,.f,17.1 A-3, 3K-20 '17/75/2002 6.0 APERF 2.5" HC DP PJ Chrgs; 60 deg ph 15/9/2001 6.0 APERF 125" HC DEP HSD PJ HMX 12,418 12,438 6,635.9 1' I .'';; A-2, 3K-20 .. ;Stimulations 8 Treatments ;. _ Bofiorn ... ' Min Top Maz Btrn Top Depth Depth Depth Depth (ND) (TVD) (HK6) (ftK6) (ftK6) IHK 61 Type Date __ Comment 12438.0 6.635.9 E3. fi`25 FRAC 8/12/2007 INITIAL A-SAND FRAC, 213,0007116!20 72.418.0 1 ~ CARBOLITE, 10 PPA ON PERFS Cement Squeezes ,~ .,`'~ ~ ' 'Top Depth Blen Gepth _ _ (ND) 17'VD) TOp (ftK8) Btm (ftK6) (HKB) IfIKE) Description Start Date Comment 12,245 0. 12246.0 6.488.5 € 489..'. Cement Squeeze _ 12,520.0 125220 6. /22.8 (S. 12.6 S Cement Squeeze Notes: General & Safety _ ~~ ^?'M= Entl Data Annotation 7;17/2005 NO fE: TBG x IA LE,4F: !>PPEARS TO BE BELOW 11570' SLM 314!2010 (NOTE: VIEW SC FIENIATIC wIAlaska Schematic9.0 I Mandrel Details - ~ _ ~ _ - _ Port Top Depth Top (TVD) Intl OD Vaive Latch Size TRO Run Stn Top (ftK61 (HKB) (') Make Motlel Pn) Serv TYPe TYPe (in) (PSI) Run Date Cam 1 4467.6 2,700.6 63.14 Cnrtlcc KBG-2-9 1 GAS LIFT DMY BTM ,0.000 0.0 6/2/2002 2 7,827.2 4,184.8 66.38 Carncc, IK8G-2-9 1 GAS LIFT GLV BTM ,0.188 1,358.0 5/16/2002 3 70,204.6''. 5,239.3 66.24 Camco KBG-2-9 1 GAS LIFT GLV BTM 10.188 1,347 0 5/16/2002 4 71,506.5 5,920.8 49.05 Camco KBG-2-9 1 GAS LIFT GLV BTM 0.250 1 440.0 5116/2002 1 5 12,116.5 ~~ 6,380.0 33.47 Camco KBG-2-9 1 GAS LIFT OV BTM 0.250 0.0 8/4/2005 ~ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 3K-20 Run Date: 3/16/2010 March 19, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3K-20 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-23019-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 ~~ ~~~ ~ ~~~~ ti rafael.barreto ~ ` Date: BAR ~ 3 201 Signed: • Co . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage. Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage. AI( 99518 Fax: (907) 245-8952 1) 2) 3) 4) 5) 6) 7) 1 Report / EDE 3K - 20 Caliper report 23-Ju1-07 SCANNED AU G 0 3 2007 QÖ(-Ó7>75 \ :tt l S""3D ( Signed: Œ.PW ,. E'~"'V'En' REC ;/~~J! Date : J:JL. 3 1 Z007 Print Name: ~ ~r r....tLAIL Mll.(AAAÚ.R,tA Alaska Oil & Gas Coos. commission Anchcfag6 PROACTIVE DIAGNOSTIC SERVICES. INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHoNE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D:\Master _Copy _00 ]DSANC-2OxxIZ _ WordlDistributionlTransmittaC SheetsITIIIIISIIÚt_ OriginaI.doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Sum.mary Company: Log Date: Log No. : Run No.: Pipe1Desc.: Pipe1 Use: ConocoPhillips Inc July 23, 2007 9503 1 3.5" 9.3 lb. L-80 EUE 8RD Tubing Well: 3K-20 Field: Kuparuk State: Alaska API No.: 50-029-23019-00 Top Log Intvl1.: Surface Bot. Log Intvl1.: 12,240 Ft. (MD) Inspection Type: COMMENTS: Corrosive & Mechanical Damage Inspection This caliper data is tied into the TTL @ 12,228' (Drillers Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the 3.5" tubing logged is in good to fair condition, with a maximum recorded penetration of 26% @ 7,412'. No other significant wall penetrations are recorded. An area of deposits is recorded from 11,780' to 12,034', with a Minimum 10 of 2.28" recorded @ 11,875. There are no areas of significant Cross Sectional Wall loss recorded throughout the tubing. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Corrosion ( 26%) Jt. 235 @ 7,412 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (>11%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: Deposits Deposits Deposits Deposits Deposits Min 10 = 2.28" Min 10 = 2.28" Min 10 = 2.30" Min 10 = 2.30" Min 10 = 2.30" Jt. Jt. Jt. Jt. Jt. 377 @ 378 @ 376 @ 379 @ 380 @ 11,875 Ft. (MD) 11,925 Ft. (MD) 11,856Ft. (MD) 11,940 Ft. (MD) 11,981 Ft. (MD) I Field Engineer: S. Carpenter Analyst: J. Thompson Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford! TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Fíeld Office Phone: (907) 659-2307 Fax: (907) 659-2314 c9ö( - D"6~ :tt. S&> ( I I Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (13.7' - 12228.2') I I I I I I I GLM 1 I Well: Reid: Company: Country: Survey Date: Approx. Too! Deviation 3K-20 Kuparuk ConocoPhillips Alaska Inc USA july 23, 2007 Approx. Borehole Profile 14 1583 3153 4731 Q¡ 6290 .!:} æ: E :;¡ .£ Z C GLM 2 ~ 7871 I I I GlM 3 I GlM 4 GlM 5 I I Bottom of Survey'" 386.3 9424 11005 Damage Profile wall) I Tool Deviation (degrees) 50 12228 100 DS Report Overview Body Region Analysis I Well: Field: Company: Country: 31<-20 Kuparuk ConocoPhil!ips Alaska Jnc USA July 23,2007 MFC 24 No. 40665 1.69 24 1- Thom son Survey Date: Tool Type: Tool Size: No. of Anal st: I Tubing: Nom.OD 3.5 ins Weight 93 f Grade & Thread L-80 EUEBRD Nom. Upset 3.5 ins Upper len. 6.0 ins Lower len. 6.0 ins Nom.lD 2.992 ins I Penetration and Metal loss (% wall) Damage Profile (% wall) I penetration body o 1 metal loss body SO penetration body metal loss body 100 400 300 200 100 0 o to 1% I I 1 to 10% 10 to 20 to 40 10 over 20% 40% 85% 85% I o o GlM 1 I Damage Configuration ( body ) 200 GlM2 150 100 50 GlM3 o isolated general line ring hole /poss pitting corrosion corrosion eúITOsìon îbl€ hole GlM4 GlM 5 Bottom of Survey = 3863 o Analysis Overview page 2 I I I I Well: Field: Company: Country: I I I I I 3K-20 K uparuk ConocoPhillìps Alaska !nc USA Minimum Survey Date: Tool: Tool Size: Tubing 1.D.: 7/23/2007 MFC 24 No 40665 1.69 inches 2.992 inches Minimum Measured Diameters (In.) 1.69 1.79 1.89 1.99 2.09 2.19 2.29 239 2.49 259 2.69 2.79 2.89 2.99 1 16 26 36 46 56 66 76 86 96 106 116 126 136 143 153 163 173 .. 11 183 E 193 :; Z 203 .... i 233 243 250 260 270 200 290 300 310 320 327 337 347 357 365 374 364 386 I JOINT lATION S Pipe: Body Wall: Upset Wall: Nomina! 1.0.: 3.5 in 9.3 ppf L-80 EUE8RD 0.254 in 0.254 in 2.992 in Well: Field: 3K-20 Kuparuk ConocoPhillips Alaska Inc USA July 23, 2007 Country: Survey Date: I Joint Jt. Depth Pen ::;~y Pen . :\>le ta I Min. _,:;l!Ie No. (Ft.) !.D. Comments 10f' \ 10 ;"'" 100 (irK) (ins.) (Ins.) 0 5 1 14 0 0.04 Hi Ii Shallow corrosion. 1.1 61 () 2 UP 1.2 63 0 :lP t±= 73 ittirw. 10'i hallow corrosion. 4 1 ,'i 2.94 Shallow corrosion. 5 163 I oen Z.(¡4 6 198 0.03 2.94 Shaliownittim;,. 7 229 8 r Shallow corrosion. 9 Shallow corrosion. 10 323 (] Shallow corrosion. 11 1'i4 (I 2.94 Shallow corrosion. 12 3116 (] 0.04 1 2.94 Shallow nitl:ÍrjQi. 13 417 (J 0.04 II 2.94 Shallow corrosion. 14 448 ~9 I 2.95 Shallow corrosion. 15 480 2515 Shallow corrosion. 15.1 511 2.95 PUP 15.2 517 I 2.88 DS NIPP¡ F 15.3 520 0 =! 16 =Hf94 PUP "ttiOQi . 16 S7"i 0 10 4 2.92 17 5'>6 1 2.94 Shallow corrosion. 18 587 o.en ¡ 2.95 Shallow 19 619 ii 2.95 Shal!ow 20 650 2.94 Sh"lIow N'lfrosion. 21 681 I· 2.94 Shallow nittirn>. 22 712 ¡ 2.94 Shallow corroSion. 23 744 1 .~ 2.95 Shallow corrosion. 24 775 -0:04 I 4 2.94 Shallow corro..ion. ')<¡ 807 0.04 1 4 2.94 Shallow corrosion. 26 838 II 2.94 Shallow nittinQ. 27 869 1: ! 2.94 Shallow çorrosion. 28 900 ¡ 2.96 Shallow corrosion. 29 932 1 2.93 Shallow oiUinll. 30 963 0.04 2.96 Shallow níffirw. 31 995 !. 0.0312 6 32 1023 0.04 15 I ~Sha¡¡OW corrosion. 33 1054 i 0.02 9 2.95 34 1085 1 0.04 I C( 2.94 Shallow corrosion. 35 1116 0.03 '13 2.94 Shallow corrosion. 36 1148 ( . ~95 37 1179 .95 3R 1211 .......J .94 39 1241 .93 Shallow corrosion. 40 1272 ~ 41 1303 0.03 42 1334 0.04 Shallow 43 1366 0.03 Shallow nitl:inQ. 44 1396 0.03 ( 45 1428 0.04 1 ( 2.931 Shallow niWnQi I I I I I I REPORT INTTABULATfON SHEET Pipe: Body Wall: Upset Wall: Nomina! 1.0.: 3.5 in 9.3 ppf L·80 fUE8RD 0.254 in 0.254 in 2.992 in Well: Field: 3K-20 Kuparuk ConocoPhillips Alaska inc USA July 23, 2007 Country: Survey Date: I Joint Jt. Depth PerL Pen. Pen< 1.\;\el211 Min. ~ No. (Ft.) Body i.D. Comments (% wall) (Ins.) (Ins.) (Ins.) 0 50 100 46 1458 ì :±±Htf Shallow n¡ttino. 47 1490 1 48 1521 1 Ii 2.95 49 1552~ 2.94 50 1583 i ( 2.% 51 1615 2.93 Shallow corrosion. 52 1645 ~ :>.95 Shallow Corrosion. 53 1677 ~ 54 1708 0.03 1 5') 1740 0.03 j 2.94 56 1771 0.03 p fËt 57 1803 I 58 1834 ±Ii 2.95 59 1865 295 60 1896 2.96 61 1927 ~1 I 62 1959 ) ] 11 63 1991 '. i 9 64 2022 I I 65 2053 Shallow.-.ittino. 66 2085 2.95 67 2116 () 0 2.93 Shallow "ittina. 68 2148 Q 2.95 69 2179 0.041 2.95 Shallow corrosion. 70 2211 0.03 1 I 2.% 71 2242 0.02 2.95 72 2274 0.02 2.95 73 2305 0.03 2.96 I 74 2336 ~ : 2.94 Shallow corrosion. 75 2367 () 2.95 76 7399 0.04 2.95 Shallow nittino. 77 2431 0.02 2.96 711 2462 0.03 2.95 79 2493 0.02 1 2.94 80 2525 0.03 2.96 Shallow corrosion. 81 2556 I I 2.96 82 2588 2.95 Sr.a ow corrosion. 83 2620 ~ r.a nW corrosion. 84 2651 h" ow corrosion. 85 2683 corrosion. 86 2714 ï1"i)A 2.95 fu mAl corro"ion. 87 2746 OOLl. 2.94 Shallow corrosion. 88 2777 om : 2.95 89 2812 ( ~ =+1= ~ C i 2.95 Shallow corrosion. 90 2844 ~ 2.94 Shallow nittino. 91 2875 0.04 2.95 Shallow corrosion. 92 2907 0.03 1) 6 2.95 Shallow nittíno. 93 2937 <) 13 4 2.94 Shallow "iWno. 94 2966 2.9.1 Shallow corrosion. 95 2997 ,4 ! {, 7 Q') Shallow "ittina. I Body Metal loss Body Page 2 I I I PDS REPORT JOINT TABULATION Pipe: BodyWa!l: Upset Wall: NominaII.D.: 3.5 in 93 ppf 1.-80 EUE8RD 0.254 in 0.254 in 2.992 in We!!: Field: 3K-20 Kuparuk ConocoPhimps Alaska inc USA July 23,2007 Country: Survey Date: I Joint Jt. Depth Pen. Pen. Pen. Melal Min. . Profile No. (Ft.) 'I Body 1.0. Comments wall) (Ins.) (Ins.) (Ins.) 0 50 100 96 3028 I 0 0.03 12 Shallow oirtiOtr. 97 3060 I 0 ~ 2.95 Shallow nittínQ. 98 3091 n 2.94 Shallow corrosion. 99 1122 n 0.03 2.95 Shallow corrosion. 3153 0 0.03 ,- 4 2.94 101 3185 0 0.03 2.92 102 3214 0 0.04 2.94 Shallow corrosion. 103 3245 1 0.03 f* 104 3276 I I 0.03 105 3307 106 3338 2.94 107 3369 10 401 ( 14 ! Shallow corrosion. 432 I 111 349'5 Shallow nittínQ. 112 3526 0 003 î13 3557 0 0.03 ¡.¡ 2.95 Shallow corrosion. 114 3"88 n 0.04 6 2.95 Shallow oittim!. îî5 3620 ( 0.03 2.95 116 3650 ( 0.0 2.95 117 3682 0.0 2.96 Shallow corrosion. îî8 3713 2.93 119 3744 2.93 120 3775 2.96 ShaJiow nittim1:. 121 3807 2.95 122 3836 I 2.95 Shallow oittim¡:. 123 3868 0.03 1 6 2.95 124 38q9 0.03 ( 2.93 Shallow çorrosiQf1. 125 3930 0.03 2.95 Shallow corrosion. 126 3962 0.03 2.95 Shallow Dittin~. 127 3993 0.02 2.93 128 4023 0.04 ( 2.94 Shallow corrosion. 129 4055 0.03 j 2.96 Shallow oittiml. 130 0.03 2.94 131 4118 (¡en 2.95 Shallow corrosion. H2 4149 i 2.96 Shallow corrosion. 133 4181 2.95 Shallow corrosion. 134 4212 2.95 Shallow nittintr. 135 4243 2.92 136 4275 0.03 ( 2.95 137 4306 0.04 ji 4 2.93 Shallow corrosion. 138 4338 0.03 1 4 2.95 Shallow corrosion. 139 4369 0.03 I 9 2.95 Shallow corrosion. 140 4400 . 2.95 141 4433 .03 t 2.95 141.î 4464 2.97 PUP 141.2 4469 ii 0.04 ( N/A GI.M 1 (Latch @ 12;30) 14î.3 4476 ( 2.95 PUP ·tting. 1\1 142 4482 ( 2.94 Shallow corrosion. I I I I I I I I I Body Meta! Loss Body Page 3 I I JOINT TABULATION SH I Pipe: Body Wall: Upset Wall: Nomina! 1.0.: 3.5 in 9.3 ppf l-80 EUE8RD 0.254 in 0.254 in 2.992 in Well: 3K-20 I Company: Country: Survey Date: ConocoPhillips Alaska Inc USA July 23, 2007 I I Joint Jt. Depth Pere Pen. PerL le1etal Min. n. ."L ,v"'''' No. (ft.) Upset Body LD. Comments (% I~ (Ins.) 0 100 143 ~w oo"",ion. 144 4545 Shallow oittirnl. 145 4576 .91 ~ 4608 o 1 2.95 ShaHow corrosion. 4639 n 0.03 1 C1 7 2.95 Shallow oÎttin2. 4671 0.03 2.95 4700t 0.04 2.96 Sha!low corrosion. 150 47.11 0.03 2.96 151 4763 0.04 2.94 corrosion. 152 4794 0.03 2.93 151 4825 0.03 1t 5 2.94 154 4856 0 0.03 2.94 155 488R n 0.03 t 2.93 Shallow corrosion. 156 4919 n 0.04 2.95 Shallow corrosion. ~ 4951 n ~ 2.95 158 4982 2.93 Shallow corrosion. 159 I <;011 0.03 2.93 160 5045 0.01 t 2.92 161 S076 I tlt Shallow 162 5107 0 (, Shallow oittin2. 163 5137 0 6 2.94 164 5168 0 6 2.94 Shallow corrosion. 165 5200 n 2.93 Shallow corrosion. 166 5231 0 2.93 167 ')260 2.95 168 5291 0.03 W 2.94 169 5323 0.03 11 6 2.94 170 5354 0.04 116 I 6 2.94 Shallow corrosion. 171 5386 0.03m S 2.93 Shallow corrosion. 172 5417 g:g~ :7 2.93 Shallow pittim.. 173 5449 2.95 174 5480 0.04 IS 2.95 Shallow corrosion. 175 5511 0.03 12 2.94 176 5542 0.03 1 2.95 177 5<;73 0.03 1 TIt Shallow DiWoo. 178 0.04 H Sha!low corrosion. 179 5635 0.04 . 2.94 Sh,dlow nittinº. 180 5666 0.04 2.93 Shallow corrosion. 181 5698 0.03 2.94 Shallow corrosion. 182 5729 0 0.03 2.95 =i= 5760 0 0.03 2.94 Shallow corrosion. 184 5791 o ±iì1t 2.94 Shallow corrosion. 1 5822 0 2.92 Shallow corrosion. 186 5853 o 1. 2.93 Shallow corrosion. 187 5884 0.03 2.93 Shallow corrosion. It. Deposits. 188 5915 ( 0.04 2.95 Shallow corrosion. 189 5947 ( 0.04 2.95 Shallow corrosion. 190 5978 ( 0.04 2.93 Shallow DiUim;I. 191 6010 C 0.03 1 2.94 Shallow oiWrnl. 192 6041 C 0.04 1 ( 2.95 Shallow corrosion. ! I I I I Page 4 I PDS REPORT JOINT TABULATION S Pipe: Body Wail: Upset Wail: NominaII.D.: 3.5 in 9.3 ppf l-80 EUE8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3K-20 Kuparuk ConocoPhillîps Alaska Inc USA July 23, 2007 I Joint Jt. Depth Pen, PerL .'vletal Min. .~ ""' , '",'He No. (Ft.) IJpse! 1.0. Comments 101 ..,~!I\ \f<> ""'''! (Ins.) (Ins.) 0 100 193 fiOT? n 1\ 7 2.94 194 6 2.93 195 6135 0.03 6 m iWnlI. 196 6165 I 0.03 197 6196 I 0.04 198 ;~~~ I rUli fi 199 6258 I 1 6 2.93 I 200 6290 I 6 2.94 I ,h"Un\M corrosion. 201 6321 I 1 ' fi corrosion. 202 6352 n fÌn4 1 9 2.94 Shallow corrosion. 203 6384 0 I 0.04 1 r¡ 2.94 Shallow corro"ion. 204 6415 ~ 2.95 (;1,0 I.."., corrosion. 205 2.911 '",0 ¡,,\AI corrosion. ")6 $1$ . 00311 - 2.911 ittÎnQ. 207 0.04 ¡ 16 208 6540 corrosion. 209 6572 corrosion. 210 6603 Shallow corrosion. 211 6634 0.05 9 Shallow corrosion. 212 fififi'i 0.03 I 2.96 ittim!. 213 661.}7 I 2.94 Sh;¡lIow corrosion. 214 6728 2.92 Shallow nittiruI. 215 6759 10 2.94 i 216 6791 2.95 Shallow corrosion. 717 ¡:; 1 I 2.94 =w oittim;¡. 218 Ii 'i2 ¡ I 2.95 w corrosion. l=lli=J h RA 0.03 2.94 6915 0.04 I 2.94 Shallow corrosion. 221 6946 0.04 I 2.94 Shallow corrosion. 222 6977 om 4 2.94 223 700R 0.04 I 2.94 itti nil. 224 7039 0.03 I 2.95 225 7071 I 2.93 Shallow o¡ttim~. 226 7102 ill Shallow corrosion. 227 7133 Shallow corrosion. 228 7164 ¡ 2.95 corrosion. 229 7196 2.94 Shallow corrosion 230 7227 2.95 Shallow oiWn2. 231 7258 0 2.93 Shallow corrosion. 232 7290 2.93 ShallQw corrosion. 233 7320 2.93 234 7351 2.94 Shallow 235 71R2 ( 0.07 2.92 236 7413 I 1m 2.95 ShaUow corrosion. 237 7444 ( 2.94 238 7475 2.93 Shallow corrosion. 239 7507 2.95 240 7538 0.04 .4 2.93 Shallow 241 7570 0.0414 7 2.94 "hallow corrosion. 242 7601 0.02! B I 2 2.95 ! I Page 5 I JOINT TABULATION I Pipe: Body Wall: Upset Wall: Nominal LD.: 3.5 in 93 ppf L-80 EUE8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: 3K-20 I ConocoPhíllips Alaska Inc USA ,uly 23, 2007 Survey Date: I Joint It. Depth Pen :;:~~ PerL I ¡\¡Ieial Min. Profile No. 1.0. Comments ("/" (Ins) (ins.) (Ins.) 0 50 100 243 7633 0.02 p ; 1293 244 7664 ~ 245 7695 246 7727 247 7759 OIl ß ~ 7790 OIl "¡-",!iow còrrosinn. 7821 ~nn 2.96 PUP 248.2 7827 0 ·Ii GLM 2 (Latch @ 9:30\ lØi 249 I () ,,~,~¡¡.;...;~;- corrosion. 250 I ri 2.93 251 i 2.91 252 7934 h 2.94 Shallow nittina. 253 7965 0 ;7 2.95 254 I 79% 5 Shallow corrosion. 255 ! 8027 f.j 256 , Shallow corrosion. '-- 257 8089 T 003 11 t-... 258 8121 m n 259 8153 2.93 Shallow corrösion. 260 8184 2.94 261 8215 i 2.94 Shallow corr"sion 262 8246 !iìiì~ II 2.95 263 8278 =#= 2.92 264 8308 In 192 Shallow nittin<>. 265 8340 1 2.95 266 8371 2,<11 Shailow 267 840 1'1 / q4 Shallow corrosion. /68 $" /.93 269 2.93 Shallow r¡ittîn2 270 8496 2.95 271 8527 2.94 Shallow nittin<>. 272 8559 0.03 2.93 273 8590 0.02 2.94 274 8621 11m ì 2.91 Lt. DenosÎts. 275 8653 om 2.94 276 884 II' 2.93 Shallow nitiinQ. 277 p 5 ¡ 2.93 Shallow corrosion. 278 p if> I 2.95 279 11 '7 I \4 4 2.95 Shallow nìuina. 280 8807 11 2.95 281 8838 2.9'1 ?f\2 8R69 1qil 283 8899 ! iUIJ C 2.92 284 8930 I i iUrl 1 2.92 Shallow nittin!!I. Lt. Denosits. 285 8960 o. is ¡Üt1- I 2.93 Shallow corrosion. 286 8991 f) hi!. { 192 Shallow nittino-. 287 9021 0.04 6 2.94 Shallow corrosion. 288 qf!'if! 0 O.~ ~1 ? q1 289 9076 IJ 0.0 I 2.93 Shallow corrosion. I I I I I II I I 6 JOINT TABULATION Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf l-80 EUE8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Coun try: Survey Date: 3K-20 Kuparuk ConocoPhmips AlasKa Inc USA July 23, 2007 Pen. Pen. Metal Min. Body !.D. (Ins.) (los.) 290 911? 0 (Ii 2.93 Sh"lIow corrosion. ~ 91431 0.04 2.92 Shallow corrosion. 293 9203 I ~ in". I L Denosits. ~:1 ;~;; ~ 296 9298 I ¿ 2.92 Shallow corrosion. 297 9329 2.'11 298 9361 0.03 ? CIA Shallow corrosion. 299 9393 0.03 2.92 300 9424 * 2.92 ~g~ ~*~ ;:nI1~!Qt ~ G~~~~~:::: 304 w niffinO'. 305 9580 306 2.94 Sh"lIow corrosion. 307 9642 0 2.93 Shallow corrosion. 308 9674 I 2.94 Shallow 309 9705 t H 2.93 Shallow corrosion. 310 9736 I " 2.93 311 9768 t ~ Shallow corrosion. 312 9799 t ~ Shallow "ittim:>. 313 9830 (0. 2.94 Shallow corrosion. 314 986? 7 2,/:)4 Sh"Uow corrosion. 315 9893 11 iqL¡,T corrosion. 316 9924 "I 4 2.94 corrosion. 317 9956 >1 4 2.92 Shallow corrosion. ~ 9987 0 "2.93 Shallow corrosion. 319 10017 í 2.93 320 10049 0.0311 2.CI,1 Shallow corrosion. 321 10080 0.0313 I 2.93 Shallow corrosion. 322 10111 0.03 10 I 2.92 323 10143 0 ..03 2.94 Shallow corrosion. 324 10172 n 2.94 1324.1 11g2g~ H= ~~r 10214 n 2.93 325 10220 0 0.02 2.93 326 10251 0 0.04** 2.93 Shallow corrosion. 327 102R? i 0.03 ¡ 2.93 328 10314 i t 0.0313 2.94 Shallowcorrosioo. 329 10345 ( 0.05 B 2.94 Shallow corrosion. 330 10377 ( 12.94 331 10409 ( 1j93 332 10440 ( 2.94 . 333 10471 ( 2 corrosion. 334 10503 (I 2 corrosion. 335 10535 I 0.0 1 (, 2.93 PitlinQ. 336 10566 I 0.041. 6 2.93 ¡ Sh"l!nw corrösion. Jt. Depth Pen (Ft.) ~~~~(;t Joint No. Comments I PUP Lt. GI M 3 (latch @ 3:0Oì PUP I 7 I 10/ .~I:;-'''''': \ '" ..a."1 o 100 I I PDS JOINT TABULATION SH I Pipe: Body Wall; Upset Wall: Nominal LD.: 3.5 in 93 ppf l-80 EUE8RD 0.254 in 0.254 in 2. 992 in Well; field: Company: Country: Survey Date: 3K-20 Kuparuk ConocoPhiUips A!aska ¡nc USA July 23, 2007 I Joint Jt. Depth y=:' Pen. Pen. . .'v1etal Min. Damag e Profile No. (ft.) !.D. Comments (% wall) (Ins.) (Ins.) 0 50 100 337 10597 1" 7 2. corrosion. 338 10629 " 7 2.94 Shallow 339 10661 ~ :ili Shallow corrosion. 340 10692 Shallow corrosion. 341 10724 0.0 2.94 Shallow corrosÎnn. 342 10755 0.03 11: ¡:; 2.94 Shallnw corrosion. 343 10786 2.93 I;h"lfnw corrosion. 344 10818 ( !".¡ ! 1', 2. Shallow corrosion. 345 10848 t 346 10880 t 2.94 <:;h"lInw corrosion. 347 10911 2.92 "luUnw nittina. 348 10943 2.94 Shallow corro"ion. 349 10974 2.92 350 1 lOr:; t """i1"õ1 10 I 2.93 tlli= . 1 137 1 1118 2.92 353 1 t199 ?92 354 11 31 2.91 355 111 62 n 0.03 11'-1 2.94 Shallow "'¡ttin"'. 356 11193 0 2.91 Shallow corrosion. 357 11224 0 2.92 I;h"lInw corrosion. 358 11255 2.93 Sh"Unw corrocion. 159 11286 2.92 Shallow corr....sion. 360 11317 2.94 Shallow corrosion. 361 11348 0.03 ~ 362 11380 t 0.03 í Shallow corrosion. 363 11411 0.04 2.93 Shallow corm"inn. 364 11442 0.03 1 2.93 365 11473 æl 2.92 Shallow I ittina 365.1 11504 2.92 PUplr f ¡"'''''sits. 365.2 11512 o i N/A r.lM A latch @ 4:00\ 3653 11517 i 0.03 1 4 2.92 PUP ittina. 366 11523 t 0.04 t t 2.93 Shallow corrosion. 367 11554 0.03 1 2.94 Shallow nittin"'. 368 11585 0,03 ¡~ 2.95 369 11619 ( 0.0 2.94 370 11649 0 2.93 Shallow corrosion. 371 11680 L1 2.92 Shallow corrosion. 372 11711 n Ii; -i\i)í; 1 L1 2.92 Shallow corrosion. U. Denosíts. 373 11743 ! OO? III j1ì line corrosion. It. Denosits. 374 11775 0.02 R ) Deoosits. 375 11803 { im It Deoosits. 376 11833 ( 7:30 Denosits. 377 11863 2.27 Denosits. 378 11894 2.28 Denosits. III 379 11925 0.03 2.30 Deoosits. 380 11952 0.03 2.30 Deoosits. 381 11984 ~ 2.31 Deoosits. 382 12015 { ( 1 I ?« i Deoosits. 383 12050 0 0.04 Hi! 2.84 Shallow nitl:ìnŒ. U. Denosits. I I I I I Body Metal loss Body Page 8 I REPORT JOINT TABULATION I Pipe: Body Wall: Upset Wall: Nomina! 1.0.: 3.5 in 9.3 ppf 1.-80 EUE8RD 0.254 in 0.254 in 2.992 in Well: Field: Company: Coun try: Survey Date: 3K-20 Kuparuk ConocoPhillips Alaska Inc USA July 23, 2007 I Joint No. Comments I Page 9 - Wen: Field: Company: Country: Tubin : - 3K·20 Kuparuk ConocoPhillips Alaska Inc USA 3.5 ins 9.3 f L·80 EUE8RD for Joint 235 Toof "" 55 Nominal fD "" 2.992 Nominal 00 "" 3.500 Remaining wall area"" 95 % Tool deviation"" 86 0 - S Report ross Sections Survey Date: Tool Type: Tool Size: No. of fingers: Anal st: depth 7411 ft Finger 21 Penetration"" 0.066 ins 0.06 "" 26"/" Wall Penetration HIGH SIDE"" UP Cross Sections page 1 - - - P S Repo ross s Well: Field: Company: 3K·20 Kuparuk ConocoPhillips Alaska ilK USA 3.5 ins 9.3 f L·80 EUE8RO Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Tubin: for Joint 3 ft Tool "' 50 NomínallO"' 2.992 NQmina! 00 '" 3.500 Remaining wall area'" 100 % Tool deviation'" 49 0 Finger 9 Projection'" -0.463 ins Deposits Min 10'" 2.28 ins HIGH SIDE '" UP Cross page 2 - - - Well: Field: Company: Country: Tubin : 3K-20 Kuparuk ConocoPhillips Alaska inc USA 3.5 ins 9.3 f L-80 EUE8RD Tool speed = 55 Nominal 10 = 2.992 Nominal 00 = 3.500 wan area = 99 % Tool deviation = 45 0 - - PDS Report Survey Date: Tool Type: Tool Size: No.ofFingers: Anal st: son 1 1 ft Finger 21 Projection = -0.419 ins Deposits Min 10 = 2.28 ins HIGH SIDE = UP page 3 - s I I I SURFACE (0--7706, 00:7.625, Wt:29.70) I , RooUCTlON (0--12190, 00:5.500, Wt15.50) I I KRU 3K-20 NIP I 12166- 12167, 00:4.540) , RooUCTlON 12190--12624, 00:4.500, eezed I Tn. 12228-12229, 00:4.000) I Pert I 12270- 122M} Pert I 123<16-12300} Perf 12418-12438) I FRAC 12418-12438) Perf 12520-12522} RETAINER I 124:92-12522, 00:3.500) . . ~ ConocoPhillips Alaska JUl I) 3 Z007 & P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 2, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Có ~O\~ Oq, SCANNED JUL () {) 20t)? Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. 4i~ M.J. Loveland ConocoPhillips Well Integrity Supervisor {..-----~ . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/1/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft na gal 1 C-19 203-054 28" none 28" na 12 6/24/2007 1 C-123 201-084 22" none 22" na 24 7/1/2007 1C-127 201-114 18" none 18" na 12 7/1/2007 1 C-133 201-077 16" none 16" na 8.5 7/1/2007 -- ~~ 27" na 10 --- .i( _Hi i.. ....- 3K-12 186-165 6" none 6" na 3 6/24/2007 3K-19 201-108 6" none 6" na 3 6/24/2007 3K-20 201-088 4" none 4" na 1 6/24/2007 3K-23 197-097 8" none 8" na 5 6/24/2007 3K-24 198-249 4" none 4" na 1 6/24/2007 3K-25 198-081 6" none 6" na 3 6/24/2007 3K-26 197-077 8" none 8" na 5 6/24/2007 3K-27 197-046 6" none 6" na 3 6/24/2007 3K-31 198-082 8" none 8" na 5 6/24/2007 3K-34 198-077 7" none 7" na 4 6/24/2007 3K-35 197-109 3" none 3" na 2 6/24/2007 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFichc\CvrPgs _ Inserts\Microfilm _ Marker.doc Permit to Drill 2010880 DATA SUBMITTAL COMPLIANCE REPORT 7~30~2003 Well Name/No. KUPARUK RIV UNIT 3K-20 Operator CONOCOPHILLIPS ALASKA INC MD 12706 - TVD 6883 - Completion Dat 8/9/2001. Completion Statu 1-OIL Current Status 1-OIL UIC N APl No. 50-029-23019-00-00 REQUIRED INFORMATION Mud Log No Sample No Directional Survey No- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH / Dataset Name Scale Media No Start Stop CH Received Number Comments Ver LIS Verification Ver LIS Verification L D Cement Bond Log/ 5 PSP/SCMT MWD Survey , Cement Bond Log 5 1 582 12706 Open 4/19/2002 ~72 1 547 12663 Open 12/28/2001 ~3 FINAL 11990 12564 CH 7/13/2001 FINAL OH 7/18/2001 FINAL 12050 12495 CH 9/14/2001 11990-12564 Color Print MWD Survey, Digital Data 12050-12495 Color Print Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/(~ Chips Received? Analysis R~.n~.iv~.d ? Daily History Received? ~.~/N Formation Tops ~.~/N Comments: Compliance Reviewed By: ................ .~ Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 Augustl4,2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 3K-20 (201-088) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operations on the KRU well 3K-20. If there are any questions, please contact me at 263-4574. Sincerely, Wells Team Leader Phillips Drilling MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 3854' FNL, 4959' FEL, Sec. 35, T13N, R9E, UM At top of productive interval 191' FSL, 1232' FEL, Sec. 25, T13N, R9E, UM At effective depth At total depth 5018' FNL, 1078' FEL, Sec. 25, T13N, R9E, UM 5. Type of Well: Development _X Exploratory __ Stratigraphic _ Service_ (asp's 529307, 6008416) (asp's 538294, 6012506) (asp's 538445, 6012576) 6. Datum elevation (DF or KB feet) RKB 34 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3K-20 9. Permit number / approval number 201-088 / 10. APl number 50-029-23019 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 12706 feet Plugs (measured) 6883 feet Effective depth: measured 12440 feet Junk (measured) true vertical 6655 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 158' 16" 3 cu yds High Early 158' 158' SURFACE 7637' 7-5/8" 642 sx AS Lite, 315 sx LiteCrete 7706' 4137' pRODUCTION 12121' 5-1/2" 220 sx GasBIok 12190' 6442' PRODUCTION 434' 4-1/2" included above 12624' 6812' PRODUCTION 67' 3-1/2" included above 12691' 6870' Perforation depth: measured ' ' ' 12418: ,:: 12438,, 12520 .:i 2522; 12245, ~ ii 22461:12270~: :1 ~280, i :i~386! ~ 12396' true vertical 6636, ::665:3,,6723, ' 6725,6489:,=6490,.6510.:~ 6518,6609-:6617: ;,.! ~ ...- :'?.' '~, · . ~, .,r I '" ',"' :: :' :::: : :: ,;," ~i" ~ ?ii~I , Tubing (size, grade, and measured depth) 3~1...2". 9.3~. L-80 Tbg @ 12228' MD. ; ::::; ; ;:;; i::: : :; :: ;; '::' 'i:". '..i' .,,','~. Packers & SSSV (type & measured depth) No packer CAMCO 'DS' NIPPLE W/NO GO pRoFILE @ 521' MD. · . 13. Stimulation or cement squeeze summary Intervals treated (measured) :i N/A: Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations X .: :OiI :i ~.X ::: Gas :: :: :: suspended :i : ::Servce :water njector i ;: : 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Carl Mike Mooney 263-4574 Signed /4//'.'////~/'//z~'~ Title: Wells Team Leader Date Michael Mooney ,' Prepared by Sharon Al/sup-Drake 263-4612 I '- t. _.) ~ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 3K-20 Event History 07/15/02 PERFORATED: 12270'-12280' AND 12386'-12396' 6 SPF POWER JET, TAGGED TD AT 12408' (10' FILL ABOVE TOP A2 PERF). Page 1 of 1 8/13/2002 WELL LOG TRANSMITTAL To: State of Alaska January 29, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 3K-20, AK-MM-10173 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3K-20: Digital Log Images 1 CD Rom. To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska December 21,2001 MWD Formation Evaluation Logs 3K-20, AK-MM- 10173 1 LDWG formatted Disc with verification listing. API#: 50-029-23019-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AN'l) RETURNIN'G A CoPY OF THE TRANSMITTAL LETTER TO THE ATTENTION' OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: RECEIVED DEC 2 8 2001 Anc~,omge 8/24/2001 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. t398 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD Color 1C-111~-~0/.-/c~ 21363 SCMTIJEWELRY 07130101 3K-20 <~O/-O~'~ 21364 SCMT 07/29/01 1 I,,tl=.' IVED Alaska Oil & Gas Cons, ~3mm~ss~o, Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Anchorage PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 September 6, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED SEP 07 2001 Alaska Oil & Gas Cons. Commission Anchorage Subject: Completion Report for 3K-20 (201-088) Dear Ms. Commissioner Taylor: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kupamk well 3K-20. If you have any questions regarding this matter, please contact Todd Mushovic at 265-6974. Sincerely, C. R. Mallary Drilling Engineering Supervisor PAI Drilling CRM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [~] Gas E] Suspended E] Abandoned D service D 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 201-088 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-23019-00 4. Location of well at surlace ................ ~ ~' 9. Unit or Lease Name 1422' FSL, 319' FWL, Sec. 35, T13N, R9E, UM (ASP: 529307, 6008417)' '" -" ' ' . · Kuparuk River Unit ~" '~i 10. WellNumber At Top Producing Interval 191' FSL, 1232' FEL, Sec. 25, T13N, R9E, UM (ASP: 538294, 6012506) i ...... L.- .... } ., 3K-20 At Total Depth ! ....... ."~-~/-')- ...... I 11. Field and Pool 261' FSL, 1080' FEL, Sec. 25, T13N, R9E, UM (ASP: 538445, 6012576): --"~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 34 feetI ADL 25519, ALK 2555 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susa. Or~ Aband. 115. Water Depth, if offshore 16. No. of Completions May 28, 2001 June 9, 2001 ~.x~ I N/A feet USE 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 12706' MD /6883' TVD 12492' MD /6699' TVD YES r~l No ~]I N/A feet MD 2040' 22. Type Electric or Other Logs Run GR/Res/PWD, SCMT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 151.5# X-65 Surface 158' 24" 3 cu yds High Early 7.625" 29.7# L-80 Surface 7706' 9.875" 642 sx AS Lite, 315 sx LiteCRETE 5.5" 15.5# L-80 Surface 12190' 6.75" 220 sx GasBLOK 4.5" 12.6# L-80 12190' 12624' 6.75" included above 3.5" 9.3# L-80 12624' 12691' 6.75" included above cement retainer set at 12492' 24. Pedoratlons open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 12228' N/A 12418' - 12438' MD 6636' - 6653' TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12520' - 12522' MD 6723' - 6725' TVD 4 spf / DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12245' - 12246' MD 6489' - 6490' TVD 6 spf , see attachment see attachment 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) August 26, 2001 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 8/28/2001 13.9 hrs Test Period > 1729 724 36 124I 408 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Ipress. 242 psi 1417 24-Hour Rate > 2759 1447 62 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/ARECEIVED . ,SEP 0 7 2001 ORIGINAL, Alaska 0il & I~as Cons. Commission · Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ArtfihQj~ In duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 12203' 6453' Base Kuparuk C 12255' 6497' Top Kuparuk A 12365' 6591' Base Kuparuk A 12510' 6714' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby ce~h~d COITeCt to the best of my knowledge. Questions? Call Todd Mushovic 265-6974 Signed i Title Dflllin,q En,qineerin,q Supervisor Date C. R. Mallary INSTRUCTIONS Prepared by Sharon A//sup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be Separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 PHILLIPS ALASKA INc. Page 1 of 5 Operations Summar RepOrt Legal Well Name: 3K-20 Common Well Name: 3K-20 Spud Date: 5/28/2001 Event Name: ROT- DRILLING Start: 5/22/2001 End: 6/13/2001 Contractor Name: Nabors Rig Release: 6/13/2001 Group: Rig Name: Nabors 16E Rig Number: 16E Sub ~ DeSCriptiOn Date From - To : HOurs Code Code Phase ~ of Operations 5/24/2001 18:00 - 20:00 2.00 MOVE DMOB MOBMIR Nippled down 20" surface stack, rigged down cellar and removed stack. 20:00 - 00:00 4.00 MOVE DMOB MOBMIR Removed cattle chute, placed on Iow boy truck, moved rockover tank and ballmill to staging area, prepare floor for skidding in, blow down and take apart injection line. Prepare rig to be split. 5/25/2001 00:00- 03:00 3.00 MOVE DMOB MOBMIR Prep floor for skid, disconnect eletrical lines & lower grasshopper. Skid rig floor, prep to split modules. 03:00 - 05:30 2.50 MOVE DMOB MOBMIR Raise modules & pull mats, drive power module around corner of 1J ~ad. Pull bubble on OD's of sub, pull sub off 1J-10. PJSM. 05:30- 12:00 6.50 MOVE DMOB MOBMIR L/D BOP stack in carrier, insatalled rear booster wheel asy on sub, remove left aux wheel assy from sub & installed on front of sub module. 12:00- 16:00 4.00 MOVE DMOB MOBMIR Finished installation of aux axle on front of sub. Air up tires, work on getting back aux axle to turn with auto control, get electrician to fix, moved sub module in front of power module. PJSM. Move rig onto main road. 16:00 - 00:00 8.00 MOVE MOB MOBMIR Moved Rig 16E from 1J pad to KOC, approx 8 miles. Air up tires & check rig at KOC. 5/26/2001 00:00- 06:00 6.00 MOVE MOVE MOBMIR Moved sub & power module from K.O.C. to CPF-3. '06:00- 07:30 1.50 MOVE OTHR MOBMIR Waited on traffic per security. 07:30 - 11:00 3.50 MOVE MOVE MOBMIR Move sub & power modules f/CPF-3 to 3K pad. (Distance of move from 1J-10 to 3K-20 = 19.0 miles ). 11:00 - 12:00 1.00 MOVE OTHR MOBMIR Intsalled bolts in spreader links, inspected wheels & tires. 12:00 - 18:00 6.00 MOVE OTHR ' MOBMIR Took off rear bolster, put on connecting links, tighten bolts on planetariums, clean out pipe shed, prepare cellar for picking up BOP's, work with mechanic on inspection gear ends of NO. I & NO. 2 mud pumps, unload eqpt. 18:00 - 00:00 6.00! MOVE POSN MOBMIR Uncradled BOP's, set back in place, picked up surface stack, set diverter riser on well. Moved rig over 3K-20 conductor, place mats under rig, positioned motor module to marry up with sub module, skid rig floor. 5/27/2001 00:00 - 01:30 1.50 MOVE POSN MOBMIR Please Note: RKB - landing ring = 34.10 ft. 16" Conductor Driven to 158'. Finished skidding rig floor over 3K-20 conductor. INstalled cattle shute, spot power module & pin to sub module. 01:30 - 05:30 4.00 MOVE RURD MOBMIR Installed had rails, suitcase covers, & boiler exhaust stacks, flip top of beaver slide & pin to rig floor. Connect service lines to rig floor, spot ball mill & mckover tank. Install scaffold ladders in cellar area, closue up cellar doors, install 4" annulus valves, energize drawworks & topdrive. 05:30 - 08:00 2.50 MOVE RURD MOBMIR Connect flowline & augers, connect service lines in stair tower. Conect csg fillup & kill lines under rig floor. Install beam clamps on sub. 08:00 - 12:00 4.00 DRILL RIRD SURFAC N/U diverter system & start mixing spud mud. Rig back onto dayrate contract at this stage. 12:00 - 14:30 2.50 DRILL RIRD SURFAC Finish diverter system, hook up hydraulics, load pipe shed & mixing spud mud. 14:30- 16:30 2.00 DRILL RIRD SURFAC After observing direction of diverter line, decided it was un-acceptable. Disconnected diverter line and rotated diverter +/- 180 degrees & re-installed diverter. Was pointing towards camp and would block all egress if emergency did occur. Now pointing to the NW area of pad. 16:30- 19:30 3.00 DRILL PULD SURFAC PJSM - rigged up to pick up drillpipe. Inspected topdrive, P/U 5" drillpipe. Rabbitting all pipe. 19:30 - 20:00 0.50 WELCTL BOPE SURFAC AOGCC supervisor (Jeff Jones) witnessed diverter test & accumulator test, OK. 20:00 - 00:00 4.00 DRILL PULD SURFAC Continue P/U 5" drillpipe. Printed: 7/13/2001 10:16:25 AM PHILLIPS ALASKA INC. page 2 of 5 Operations Summary Report Legal Well Name: 3K-20 Common Well Name: 3K-20 Spud Date: 5/28/2001 Event Name: ROT- DRILLING Start: 5/22/2001 End: 6/13/2001 Contractor Name: Nabors Rig Release: 6/13/2001 Group: Rig Name: Nabors 16E Rig Number: 16E Date From To HOurS: code:i Sub Phase Description of c3n ~i ' COde ,-.,,er-t,ons . 5/28/2001 00:00 - 05:00 5.00 DRILL PULD SURFAC Finished P/U 5" dp + HWDP + 1 jar & acclerator. Held Shallow Gas Diverter Drill. 05:00 - 07:00 2.00 DRILL TRIP SURFAC Picked up BHA & TIH. Tagged fill inside 16" conductor @ 112' RKB. 07:00 - 07:30 0.50 DRILL CIRC SURFAC Circulated and checked flowline, diverter valve, etc for leaks, OK. 07:30 - 10:00 2.50 DRILL DRLG SURFAC Spudded well, cleaned out conductor from 112 - 190'. ART=1.25 & AST=0 hrs. 10:00 - 10:30 0.50 DRILL SURV SURFAC Circulated clean. PJSM - R/U to run Sperry Gyro. 10:30 - 11:00 0.50 DRILL SURV SURFAC Ran Gyro Survey @ 141' = 2.75 deg / 282 deg AZ. 11:00 - 11:30 0.50 WALTON OTHR SURFAC Waiting on gas lift pressure on the 3K-1 producer adjacent to 3K-20 conductor to bled down. 11:30 - 12:00 0.50 DRILL SURV SURFAC Re-ran gyro survey @ 141', same as before. 12:00 - 13:30 1.50 DRILL TRIP SURFAC POOH & L/D mud motor. TIH with mule shoe in order to get a gyro survey closer to the conductor shoe (all of this extra work is due to the driven conductor having built angle and almost the absolute worst direction - we are very close to 3K-1 hardline.) 13:30 - 14:00 0.50 DRILL SURV SURFAC Ran gyro survey @ 170' = 3 deg / 285 deg AZ. 14:00 - 16:00 2.00 DRILL TRIP SURFAC POOH, L/D stabilizer & muleshoe, P/U mud motor and bit, reset motor bend setting from 1.5 to 1.8 degrees. Ran check shot gyro @ 80' = 0.75 deg / 171 deg AZ (this done mainly to get toolface lined up as we have to steer immediately out of the shoe). TIH to bttm. 16:00 - 00:00 8.00 DRILL DRLG SURFAC Finished cleaning out conductor f/190-192' (1 minute). Directionally drilled f/192 - 436' in a series of sliding and rotating increments. Surveying initially after sliding 62' ( survey pt = 48' behind bit ). Until we were comfortable that we had things lined out and safely aimed away from crossing any hardlines we moved the survey frequency out from the 15' stations we were gyroing. ART= 0.5 hrs AST=1.75 hrs. 5/29/2001 00:00 - 03:00 3.00 DRILL DRLG SURFAC Drill f/436' to 582' AST= 1/2 hr ART= 3/4 hr Gyro= 1 hr 03:00 - 04:00 1.00 DRILL TRIP SURFAC Blow down lines, POOH to BHA 04:00 - 06:00 2.00 DRILL PULD SURFAC Handle BHA, Change bend on motor f/1.8 t/1.5, Pick up MWD & test same - No good 06:00 - 07:30 1.50 DRILL PULD SURFAC Wait on MWD from another rig 07:30 - 10:00 2.50 DRILL PULD SURFAC Pick up MWD & LWD tools, Program same 10:00 - 12:00 2.00 DRILL TRIP SURFAC RIH & Test Sperry- Sun tools @ 250', Check survey @ 540' 12:00-00:00 12.00 DRILL DRLG SURFAC Drill f/ 582' to1656' AST=63/4hrs ART=3hrs 5/30/2001 00:00 - 18:00 18.00 DRILL DRLG SURFAC Drill f/1656' to 3538' AST=2.25 hrs ART=9.75 hrs 18:00 - 18:30 0.50 DRILL CIRC SURF^C 'Pump sweep & Circ. hole clean 18:30 - 21:30 3.00 DRILL WIPR SURFAC Monitor well, Wipe hole to 200'- No tight spots or swabbing 21:30 - 22:00 0.50 RIGMNT RSRV SURFAC Service top drive, Check override clutch 22:00 - 23:30 1.50 DRILL WIPR SURFAC RIH to 3538'- No problems 23:30 - 00:00 0.50 DRILL CIRC SURFAC Circ. btm's up 5/31/2001 00:00 - 21:00 21.00 DRILL DRLG SURFAC Drill f/3538' to 5980' AST=2.75 hrs ART=13.25 hrs 21:00 - 22:00 1.00 DRILL CIRC SURFAC Pump sweep & Circ. hole clean, Monitor well 22:00 - 00:00 2.00 DRILL TRIP SURFAC PJSM, Pump dry job, POOH- 30K tight spot @ 4765' 6/1/2001 00:00 - 05:30 5.50 DRILL TRIP SURFAC POOH- Pump out f/4200' to 4010' due to swabbing, Lay down UBHO sub, Change Bit & motor AKO to 1.15 05:30 - 06:30 1.00 DRILL PULD SURFAC Down load MWD/LWD, Change Pulsar sub, Reprogram MWD/LWD 06:30 - 07:30 1.00 RIGMNT RSRV SURFAC Service top drive, Adjust brakes on drawworks 07:30 - 12:00 4.50 DRILL TRIP SURFAC RIH w/BHA & test Sperry-Sun tools-OK, RIH to 5980'- Took weight f/4300' to 5300' 12:00 - 13:00 1.00 DRILL CIRC SURFAC Circ. Btm's up prior to drilling 13:00-00:00 11.00 DRILL DRLG SURFAC Drill f/5980' to 7116' ART= 7.25 hrs AST=l.75hrs 6/2/2001 00:00 - 05:30 5.50! DRILL DRLG SURFAC Drill f/7116' to 7717' ART-- 3.25 hrs AST= ..75 hrs. TVD 4143. 05:30 - 07:00 1.50' DRILL CIRC SURFAC Circ. sweep. Circ. hole clean. Printed: 7/13/2001 10:16:25 AM PHILLIPS ALASKA INC. page 3 of 5 OperationS Summary Report · Legal Well Name: 3K-20 Common Well Name: 3K-20 Spud Date: 5/28/2001 Event Name: ROT- DRILLING Start: 5/22/2001 End: 6/13/2001 Contractor Name: Nabors Rig Release: 6/13/2001 Group: Rig Name: Nabors 16E Rig Number: 16E Sub. Date From-TO Hours Code COde Phase Description of Operations ~ 6/2/2001 07:00 - 07:30 0.50 DRILL ClRC SURFAC Monitor well, (static). Pump dry job. Blow down T.D. 07:30 - 12:00 4.50 DRILL TRIP SURFAC POOH. Pull slow to avoid swabbing. SLM. Pulled good. Took good fill. 12:00 - 13:00 1.00 DRILL PULD SURFAC Set back HWDP. L/D stab., set back flex DC. :13:00- 13:30 0.50 DRILL OTHR SURFAC Sperry Sun download MWD. 13:30- 14:30 1.00 DRILL PULD SURFAC L/D BHA, reset motor. 14:30- 15:00 0.50 RIGMNT RSRV SURFAC Rig service. Top drive service. 15:00- 15:30 0.50 DRILL PULD SURFAC P/U hole opener BHA. 15:30 - 18:30 3.00 DRILL TRIP SURFAC RIH, fill pipe as necessary. Pipe went in good. 18:30- 22:00 3.50 DRILL ClRC SURFAC Tag bottom @7717. Break circulation. Circulate sweep around.- Trip gas 400 units, Circ. and Cond. per mud man specs. Monitor well, OK. 22:00- 00:00 2.00 DRILL TRIP SURFAC Pump dry job. POOH. Pipe pulling good. Taking proper fill. 6/3/2001 00:00 - 03:00 3.00 DRILL TRIP SURFAC POOH & Lay down holeopener- Hole in good shape 03:00 - 14:30 11.50 CASE RUNC SURFAC PJSM, Rig & Run 7-5/8" csg. to 7706'- circ. btm's up @ 2500' & 5000' 14:30 - 15:00 0.50 CASE RUNC SURFAC Pick up csg. hanger & cmt. head 15:00- 18:00 3.00 CEMEN' 'ClRC SURFAC Cim. & cond. mud f/cmt, job 18:00 - 22:00 4.00 CEMEN'I'PUMP SURFAC Pump 20 bbls CW100, Test lines to 3500 psi, Pump 20 bbls CW100 followed by 50 bbls MudPUSH @ 10.5 ppg, Drop btm plug, Mix & Pump 642 sxs lead cmt. @ 10.7 ppg followed by 315 sxs tail cmt. @ 12.0 ppg, Drop top plug, Displace cmt & bump plug w/10 bbls wash water followed by 341.9 bbls mud, Had 210 bbls cmt returns to surface w/ good returns thru out job, CIP 2155 hrs 22:00 - 00:00 2.00 CEMEN* 'PULD SURFAC Wash & Clean cmt. out of Diverter Stack, Flow line & Shakers, Lay down cmt. head, Landing jt, Elevators & Bails 6/4/2001 00:00 - 01:30 1.50 WELCTL NUND PROD Nipple down & remove diverter stack 01:30 - 02:00 0.50 WELCTL NUND PROD Nipple up wellhead & test to 1000 psi- OK 02:00 - 07:00 5.00 WELCTL NUND PROD Nipple up BOP stack, Riser, Choke & kill lines 07:00 - 14:00 7.00 WELCTL BOPE PROD Rig & Test all BOP equip, to 250/5000 psi, Hydril to 250/3500 psi- Witnessed and approved by AOGCC, Lay down test equip., Install wear bushing 14:00 - 22:30 8.50 DRILL PULD PROD PJSM, Lay down 5" HWDP, Jars & 5" DP out of derrick 22:30 - 00:00 1.50 DRILL PULD PROD PJSM, Pick up 4" DP & Stand back in derrick 6/5/2001 00:00 - 05:00 5.00 DRILL PULD PROD Pick up 4" DP & Stand back in derrick 05:00 - 09:30 4.50 DRILL PULD PROD Pick up 6-3/4" BHA, Set & orient motor & MWD, Program & test MWD/LWD 09:30- 15:00 5.50 DRILL PULD PROD RIH & pick up 4" DP 15:00 - 17:00 2.00 RIGMNT RURD PROD Cut & slip drilling line 113', Service top drive, Drawworks & adjust brakes 17:00 - 20:00 3.00 DRILL PULD PROD RIH & pick up 4" DP to 7606' 20:00- 20:30 0.50 DRILL ClRC PROD Circ. btm's up f/csg, test 20:30 - 21:30 1.00 DRILL OTHR PROD Rig & test 7-5/8" csg. to 3000 psi f/30 min.- OK 21:30 - 23:30 2.00 DRILL DRLG PROD Drill out Float collar @ 7616', Cmt. & Shoe @ 7706', Drill 20' new hole 23:30 - 00:00 0.50 DRILL ClRC PROD Pump sweep & circ. hole clean f/FIT 6/6/2001 00:00- 00:30 0.50 DRILL ClRC PROD Finish circ. & cond mud f/LOT 00:30 - 01:30 1.00 DRILL FIT PROD Perform FIT of 14.0 ppg EMW, Press well to 1200 psi w/8.4 ppg mud @ 4151 TVD 01:30 - 02:00 0.50 DRILL DEQT PROD Perform PWD base line test 02:00 - 03:30 1.50 DRILL DRLG PROD Drill f/7737' to 7954' ART= 1.25 hrs AST= 0 hrs 03:30 - 04:30 1.00 DRILL DEQT PROD Perform CASANDRA check shot surveys (12 surveys Total) 04:30 - 00:00 19.50 DRILL DRLG PROD Drill f/7954' to 9630' ART= 12.5 hrs AST= 3.75 hrs 6/7/2001 00:00- 14:00 14.00 DRILL DRLG PROD Drill f/9630' to 10835' ART= 7.25 hrs AST= 2.5 hrs 14:00 - 15:00 1.00 DRILL ClRC PROD Pump sweep, Circ. hole clean, Monitor well Printed: 7/13/2001 10:16:25 AM PHILLIPS ALASKA INC' page 4 of 5 ) Operations Summary Report Legal Well Name: 3K-20 Common Well Name: 3K-20 Spud Date: 5/28/2001 Event Name: ROT- DRILLING Start: 5/22/2001 End: 6/13/2001 Contractor Name: Nabors Rig Release: 6/13/2001 Group: Rig Name: Nabors 16E Rig Number: 16E SUb Phase Description of Operations Date From To HOurs Code COde 6/7/2001 15:00 - 17:00 2.00 DRILL WIPR PROD Pump dry job, Pull to shoe - No tight hole, Good fill 17:00- 17:30 0.50 RIGMNT RSRV PROD Service top drive 17:30 - 19:00 1.50 DRILL WlPR PROD RIH to 10835' - Hole in good shape 19:00 - 00:00 5.00 DRILL DRLG PROD Drill f/10835' to 11220' ART= 2.25 hrs AST= 1.5 hrs 6/8/2001 00:00 - 11:30 11.50 DRILL DRLG PROD Drill f/11220' to 11860' ART= 4 hrs AST= 4.5 hrs - Increased mud weight to 10.0 ppg 11:30 - 13:30 2.00 DRILL :CIRC PROD Pump sweep, Circ. & cond. mud f/LOT 13:30 - 16:00 2.50 DRILL WIPR PROD POOH to shoe @ 7706'- No tight hole 16:00 - 16:30 0.50 DRILL CIRC PROD Circ. btm's up prior to LOT 16:30 - 17:30 1.00 DRILL FIT PROD Rig & perform FIT of 14.0 EMW w/10.0 ppg mud, 1285 psi @ 6173' TVD 17:30 - 20:00 2.50 DRILL WIPR PROD RIH to 11860'- Hole in good shape 20:00 - 00:00 4.00 DRILL DRLG PROD . Drill f/11860' to 12087' ART= 1.5 hrs AST= 2 hrs 6/9/2001 00:00- 09:00 9.00 DRILL DRLG PROD Drill f/12087' to 12524' ART= 3.5 hrs AST= 3 hrs 09:00 - 10:30 1.50 DRILL CIRC PROD Had 2000 units connection gas f/12467', Back ground gas 300-400 units, Check flow OK, Weight up mud f/10.5 ppg to 10.8 ppg 10:30- 13:30 3.00 DRILL DRLG 'PROD Drill f/12524' to 12706' TD ART= 2.25 hrs AST= 0 13:30- 14:30 1.00 DRILL CIRC PROD Circ btm's up 14:30 - 16:00 1.50 DRILL WlPR PROD Monitor well, Wipe hole 10 stands- hole in good shape 16:00 - 18:00 2.00 DRILL CIRC PROD Pump sweep, Circ. hole clean- Trip gas 250 units 18:00 - 21:00 3.00 DRILL WIPR PROD Monitor well, Pump dry job, Wipe hole to shoe- Hole in good shape 21:00 - 22:00 1.00 RIGMNT RSRV PROD Service top drive, Drawworks, Blocks & crown 22:00- 00:00 2.00 DRILL WlPR PROD RIH- No problems 6/10/2001 00:00 - 02:00 2.00 DRILL ClRC PROD Pump sweep, Circ. hole clean- Trip gas 300 units 02:00 - 08:30 6.50 DRILL TRIP PROD Monitor well, POOH (SLM-no correction)- Hole in good shape 08:30 - 12:00 3.50 DRILL PULD PROD Lay down BHA & down load MWD/LWD 12:00 - 13:30 1.50 CASE RURD PROD Pull wear bushing, Rig to run 3-1/2" & 4-1/2" csg., PJSM 13:30 - 15:00 1.50 CASE RUNC PROD Pick up 3-1/2" float joints & 4-1/2" csg. 15:00 - 16:30 1.50 CASE RURD PROD Rig to run 5-1/2" csg.. Pick up fill up tool 16:30 - 00:00 7.50 CASE RUNC PROD Run 5-1/2" csg.- break circ. every 2500' 6/11/2001 00:00 - 00:30 0.50 CASE CIRC PROD Circ. btm's up @ 7-5/8" csg. shoe 00:30 - 05:00 4.50 CASE RUNC PROD Run 5-1/2" csg.- Break circ. every 2500' 05:00 - 05:30 0.50 CASE RURD PROD Make up hanger, Landing jt., Cmt. head 05:30 - 10:30 5.00 CEMEN'i'CIRC PROD Circ. & cond. mud f/cmt, job, Circ. btm's up @ 3 bpm @ 1100 psi- Initially loosing 60 bph- losses decreased to no losses by btm's up, Increase rate to 5 bpm @ 1200 psi, began Iossing mud at any rate over 5 bpm, lost total of 84 bbls mud 10:30 - 13:30 3.00 CEMEN'I' PUMP PROD PJSM, Batch mix cmt., Pump 40 bbls CW100, Test lines to 4000 psi, Drop btm plug, Pump 50 bbls MudPUSH @ 12.0 ppg, Pump 47 bbls (220 sxs) GasBLOK cmt. @ 15.8 ppg, Drop top plug, Displace crnt. w/ total of 299.3 bbls mud, Did not bump plug, Had good circ thru out job, no noticable losses, CIP @ 1325 hrs 13:30 - 14:30 1.00 CEMEN'I'PULD PROD Rig down cmt. equip., Lay down landing jt.( Note- noticed small flow from 5-1/2" x 7-5/8" ann. when layed down landing jt.), Drain & wash BOP stack 14:30 - 15:30 1.00 CMPLTN NUND PROD Install GEN V packoff & test to 5000 psi- OK 15:30 - 17:30 2.00 CMPLTN RURD PROD PJSM, Rig to run completion string 17:30 - 00:00 6.50 CMPLTN RUNT PROD Pick up & run completion string 6/12/2001 00:00- 06:00 6.00 CMPLTN RUNT CMPLTN Run 3-1/2" completion string, Tag CSR 06:00- 07:00 1.00 CMPLTN CIRC CMPLTN Circ. btm's up 07:00- 08:30 1.50 CMPLTI~ DEQT CMPLTN Rig & test 5-1/2", 4-1/2", 3-1/2" csg.- no-good 08:30 - 09:30 1.00 CMPLTI~ DEQT CMPLTN Stab into CSR, Test 5-1/2" x 3-1/2" ann. to 2000 psi f/30 min.- OK 09:30 - 10:30 1.00 RIGMNT RSRV CMPLTN Service top drive & drawworks Printed: 7/13/2001 10:16:25 AM PHILLIPS ALASKA INC. Page 5 of 5 Operations Summar Report Legal Well Name: 3K-20 Common Well Name: 3K-20 Spud Date: 5/28/2001 Event Name: ROT- DRILLING Start: 5/22/2001 End: 6/13/2001 Contractor Name: Nabors Rig Release: 6/13/2001 Group: Rig Name: Nabors 16E Rig Number: 16E : ~ : Code COdeSub phase Date :From;,To: Hours ' Description ofOn~ i_.__rat.ons i 6/12/2001 10:30 - 12:30 2.00 WALTON ORDR CMPLTN Wait on orders on csg. test options 12:30 - 13:30 1.00 CMPLTN SOHO CMPLTN Space out tbg., Pick up tbg. hanger & landing jt. 13:30 - 17:00 3.50 CMPLTN CIRC CMPLTN Change over 10.8 ppg mud to sea water (Note; After filling tbg. with sea water, stabed into CSR & observed tbg. for flow- Well static, pull out of CSR), Displace tbg. w/10.8 ppg mud & Land tbg. & seal assembly into CSR- Observe well- Static 17:00 - 18:00 1.00 CMPLTN RURD CMPLTN Drain BOP, Lay down landing it., Set BPV, Clear floor 18:00- 22:00 4.00 CMPLTN NUND OMPLTN Nipple down BOP 22:00 - 00:00 2.00 CMPLTN NUND CMPLTN Install & nipple up tree, Pull BPV, Install 2 way check, Test tree to 250 3si Iow & 5000 psi high 6/13/2001 00:00 - 01:00 1.00 CMPLTN SEQT CMPLTN Finish testing tree to 250 psi Iow & 5000 psi high, Remove 2 way check, Install BPV 01:00 - 01:30 0.50 CMPLTI~ RURD CMPLTN Rig to lay down 4" DP f/derrick 01:30 - 12:00 10.50 CMPLTI~ PULD CMPLTN PJSM, Lay down 4" DP & Clean mud pits - Released rig at 1200 hrs 6/13/2O01 Printed: 7/13/2001 10:15:25 AM Date Comment 3K-20 Event History 07/17/01 07/20/01 SQUEEZE PERFS SHOT. LOWER INTERVAL: 12520'-12522' .USED 2 FT GUN HC BH CHGS 60/120 PHASING 4SPF. UPPER INTERVAL: 12245'-12246'. USED 1 FT GUN HC DP CHGS 6SPF 60/120 PHASING. [PERF] ATTEMPTED TO SET BAKER PKR AT 12,492'. LAUNCHED TWO BALLS AND ONE FOAM PAD IN BEHIND BALLS. ALSO TAGGED TD AT 12,588' CORRECTED CTMD, IN THE EVENT OF SHOVING THE ACTUATOR INTO SPOTTING POSITION. NO LUCK. POOH PREP TO HAVE TOOL RE-DRESSED IN PRUDHOE. D 07/21/01 SET CEMENT RETAINER @ 12,492'. SQUEEZED ROUGHLY 1.3 BBLS OF CEMENT THROUGH PERFORATIONS, AFTER LOADING LINER ANNULUS AND EXCEEDING FRAC PRESSURE. (SHUT IN BOTTTOM HOLE HOLE PRESS WAS 3297 PSI]. OUR PRESS FOR SQUEEZE WAS 2065 PSI OVER FRAC PRESS. FRAC P 07/25/01 DRIFTED TBG 2.73" & TAGGED CMT RET @ 12507' RKB, NO PROBLEM. 2 ATTEMPTS TO MIT TBG 3000 PSI, FAILED. [TAG, MIT] 07/29/01 SCMT, LOGGED TIE IN AND BASE PASS, PRESSURED UP WELL TO 2000#, LOGGED MAIN AND REP. PASSES, POOH, NOTIFIED DSO OF STATUS RDMO, LEFT WELL SI. [OTHER STIM] 08/01/01 POST SQZ INJECTIVITY TEST; 0.47 BPM @ 3000 PSI. PUMPED 14 BBLS DIESEL OVER 30 MINUTE PERIOD AT CONSTANT RATE AND PRESSURE. [MIT, PT TBG-CSG, CEMENT-POLY SQUEEZE] 08/03/01 DUMP BAILED 6' OF SAND ABOVE CEMENT RETAINER @ 12,490'WLM, ALSO DUMP BAILED ONE BAILER FULL OF LATEX MATERIAL ABOVE SAND, PT TUBING TO 3000#, LEAKED OFF 200# AFTER 30 MINUTES [MIT] 08/08/01 DUMP BAILED 2 GAL CEMENT SLURRY ON RETAINER @ 12497' WLM. 08/09/01 PERFORATED ONE INTERVAL 12418'-12438' W/2-1/2" HSD-WL-DP, 2506 P J, HMX, 6 SPF GUNS. [PERF] 08/12/01 PUMPED INITIAL A SAND FRAC. PLACED 213M# BEHIND PIPE, 10 PPA AT PERFS, 101% OF DESIGN. FLUSHED TO COMPLETION, LEFT 1020# IN WELLBORE. [FRAC-REFRAC] 08/13/01 PERFORMED A FCO TO 12,488.8' CTMD. RETURNS 1-1 + ALL DAY. FREEZE PROTECT WELL TO 3000'. LEAVE WELL SHUT IN FOR FLOW LINE HOOK UP TO PRODUCTION, PLUS WIRELINE GL INSTALATION. INJECTIVITY TEST = .5 BPM TO 3000# WHP. DROP TO .5 BPM 3500# SHUT DWN. PRESS 08/14/01 TAGGED @ 12253' RKB, EST. 185' FILL. REC. SAMPLE OF POSSIBLE FM FINES & CARBOLITE. MEASURED BHP @ 12244' RKB: 3465 PSI. PULLED DV @ 4461' RKB. IN PROGRESS. [PRESSURE DATA] 08/15/01 SET l"X 1/4" OV @ 4461' RKB. [GLV] Page 1 of 1 9/5/01 09-Jul-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Survey Re: Distribution of Survey Data for Well 3K-20 Dear Dear Sir/Madam: Enclosed are two survey hard copies and I disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 12,706.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED 'JUL 1 8 2001 Almka 0il & Gas Cons. C~~n Anchorage DEFINiTiVE Kuparuk River Unit North Slope, Alaska Kuparuk 3K, Slot 3K-20 3K-20 Job No. AKZZ10174, Surveyed: 10 June, 2001 SURVEY REPORT July, 2001 Your Reft API.500292301900 Surface Coordinates: 6008416.53 N, 529306.84 E (70° 26' 02.6603" N, 149° 45' 39.9117" VIO Kelly Bushing: 68.60ft above Mean Sea Level ~]'R i L L I N I~ =; E R V I C: E 5 A Halliburton Company Survey Ref: svy9573 KuparUk River Unit Measured Depth (ft) Incl. 532.00 8.000 560.56 8.010 652.02 10.770 745.73 14.770 834.73 19.160 65.000 60.85O 65.130 65.190 66.130 931.55 23.150 67.340 1022.30 27.210 66.320 1113.93 30.540 62.280 1208.60 34.240 62.110 1304.63 38.310 62.440 Sub-Sea Depth (ft) 461.77 490.05 580.27 671.65 756.75 847.03 929.14 1009.38 1089.30 1166.71 1401.52 43~050 62.910 1240.16 1491.83 48.090 63.330 1303.36 1589.21 50.740 63.080 1366.71 1682.07 55.500 65.310 1422.43 1774.66 59.500 67.230 1472.17 1867.72 64.590 67.350 1962.04 64.080 67.790 2055.11 -66.410 68.120 2148~20 66.400 68.890 2243.39 66.060 68.890 2339.14 65.790 69.840 2433.30 65.590 69.130 2528.36 65.520 69.160 2622.26 64.970 68.010 2715.85 64.720 68.610 2809.71 - 64.530 66.820 2903.95 63.680 66.020 299&70 63.710 65.840 3092.08 63.960 65.780 3184.00 63.710 65.680 VertiCal Depth (ft) Sperry-Sun Drilling Services Survey Report for 3K-20 Your Ref: API-500292301900 Job No. AKZZlO174, Surveyed: lO June, 2001 -Local COordinates Northings - Eastings (ft) (ft) 530.37 5.32 N 19.08 E 558.65 7.13 N 22.62 E 648.87 13.83 N 35.94 E 740.25 22.52 N 54.73 E 825.35 33.20 N 78.40 E North Slope, Alaska Kuparuk 3K 915.63 46.97 N 110.50 E 997.74 62.18 N 145.98 E 1077.98 81.43 N 185.79 E 1157.90 105.08 N 230.64 E 1235.31 131.50 N 280.92 E 1308.76 160.48 N 337.02 E 1371.96 189.61 N 394.53 E 1435.31 222.95 N 460.54 E 1491.03 255.23 N 527.40 E 1540.77 286.62 N 598.88 E 1515.78 1584.38 318.35 N 674.69 E 1556.63 1625.23 350.78 N 753.27 E 1595.60 1664.20 382.50 N 831.60 E 1632.86 1701.46 413.76 N 910.97 E 1671.23 1739.83 445.14 N 992.24 E 1710.29 1778.89 475.94 N 1074.05 E 1749.05 1817.65 506.02 N 1154.42 E 1788.39 1856.99 536.82 N 1235.29 E 1827,71 1896.31 567.96 N 13t4.67 E 1867.49 1936.09 599.27 N 1393.39 E 1976.32 631.42 N 1471.86 E 2017.48 665.33 N 1549.55 E 2059.46 699.98 N 1627,11 E 2100.64 734.32 N 1703.56 E 2141.17 768.23 N 1778.77 E 1907.72 1948.88 1990.86 2032.04 2072.57 Global Coordinates Northings Eastings (ft) (ft) 6008421.92 N 529325.90 E 6008423.75 N 529329.43 E 6008430.50 N 529342.72 E 6008439.27 N 529361.48 E 6008450.04 N 529385.11 E 6008463.93 N 529417.16 E 6008479.28 N 529452.58 E 6008498.69 N 529492.31 E 6008522.52 N 529537.06 E 6008549.14 N 529587.25 E 6008578.33 N 529643.23 E 6008607.69 N 529700.62 E 6008641.29 N 529766.50 E 6008673.83 N 529833.24 E 6008705.50 N 529904.59 E 6008737.53 N 529980.27 E 6008770.27 N 530058.72 E 6008802.30 N 530136.93 E 6008833.87 N 530216.18 E 6008865.56 N 530297.33 E 6008896.69 N 530379.02 E 6008927.08 N 530459.27 E 6008958.20 N 530540.01E 6008989.65 N 530619.27 E 6009021.27 N. . 530697.86 E 6009053.73 N 530776.20 E 6009087.95 N 530853.77 E 6009122.89 N 530931.18 E 6009157.54 N 531007.50 E 6009191.74 N 531082.58 E Dogleg Rate (°/'~00ft) 2.023 3.111 4.269 4.942 4.145 4.499 4.210 3.909 4.243 4.902 5.591 2.728 5.474 4.660 5.471 0.685 2.524 0.758 0.357 0.949 0.719 0.079 1.257 0.639 1.735 1.182 0.173 0.274 0.289 Vertical Section 19.58 23.55 38.45 59.15 85.12 120.04 158.64 202.84 253.45 310.15 373.19 437.60 511.47 585.69 663.76 745.90 830.87 915.32 1000.53 1087.52 1174.76 1260.39 1346.78 1431.94 1516.57 1601.32 1686.10 1771.03 1854.84 1937.34 Comment Tie on to Gyro DrillQuest 2.00.08.005 July, 2001 - 4:05 Page 2 of 7 SperrY'Sun Drilling Services Survey Report for 3K-20 Your Ref: AP1-500292301900 Job No. AKZZ10174, Surveyed: 10 June, 2001 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 3278.73 63.420 65.890 2114.75 2183.35 3369.90 63.900 65.710 2155.20 2223.80 3469.70 64.120 65.460 2198.93 2267.53 3560.45 64.240 65.260 2238.46 2307.06 3654.27 64.670 66.490 2278.92 2347.52 3748.76 64.850 66.880 3643.37 65.080 66.570 3937.51 64.510 66.090 4029.83 63.840 65.670 4124.77 63.710 65.910 4219.93 63;700 4314.17 63.300 4409.27 63.280 4505.07 63.080 4599.11 62.950 65.630 65.550 66.040 65.910 66.210 2319.21 2359.24 2399.33 2439.55 2481.50 2523.66 2565.71 2608.45 2651.68 2694.35 2735.23 2777.12 2819.23 2861.16 2903.59 4689.43 63.230 65.540 4782.72 63.410 65.330 4877.41 63.780 66.330 4971.93 63.550 66.990 5067.57 63.780 67.080 2387.81 2427.84 2467.93 2508.15 2550.10 2592.26 2634.31 2677.05 2720.28 2762.95 2803.83 2845.72 2887.83 2929.76 2972.19 Local Coordinates Northings Eastings (ft) fit) 803.02 N 836.51N 873.59 N 907.65 N 942.25 N 976.07 N 1009.95 N 1044.14 N 1078.10 N 1113.03 N 1148.04 N 1182.89 N 1217.72 N' 1252.53 N 1286.54 N 1319.45 N 1354.11N 1388.83 N 1422.39 N 1455.84 N 5160.76 63.770 66.650 2944.77 3013.37 1488.68 N 5257.09 63.630 66.370 2987.45 3056.05 1523.10 N 5346143 64.100 68.410 3026.80 3095.40 1553.93 N 5444.39 63.640 67.390 3069.95 3138.55 1587.02 N 5536.03 63.290 66.610 3110.89 3179.49 1619.05 N 67.060 67.320 66.890 67.890 67.610 3222.91 3263.87 3306.06 3348.94 3389.07 1856.13 E 1930.65 E 2012.34 E 2086.59 E 2163.84E 2242.33 E 2321.08 E 2399.09 E 2474.93 E 2552.61E 2630.41E 2707.21E 2784.69 E 2862.78 E 2939.37 E 3154.31 3195.27 3237.46 .3280.34 3320.47 5632.82 63.400 5724.02 63.220 5817.34 63.030 5913.00 63.700 6004.20 64.100 3012.88 E 3088.69 E 3166.06 E 3243.84 E 3322.76 E 3399.64 E 3478.84 E 3552.87 E 3634.36 E 3709.83 E 1653.08 N 1684.67 N 1717.05 N 1749.93 N 1780.94 N 3789.36 E 3864.47 E 3941.15 E 4020.09 E 4095.89 E Global Coordinates Northings (fi) 6009226.84 N 6009260.62 N 6009298.02 N 6009332.37 N 6009367.27 N 6009401.41 N 6009435.59 N 6009470.09 N 6009504.35 N 6009539.58 N 6009574.89 N 6009610.05 N 6009645.18 N 6009680.30 N 6009714.60 N Eastings (ft) 531159.80 E 531234.19 E 531315.73 E 531389.85 E 531466.97 E 531545.32 E 531623.93 E 531701.81E 531777.52 E 531855.06 E 531932.72 E 532009.38 E 532O86.73 E 532164.68 E 532241.13 E 6009747.81N 6009782.76 N 6009817.79 N 6009851.66 N 6009885.41N 6009918.56 N 6009953.29 N 6009984.41N 6010017.82 N 6010050.15 N 6O1OO84.49 N 6010116.37 N 6010149.06 N 6010182.24 N 6010213.55 N 532314.51E 532390.18 E 532467.42 E 532545.07 E 532623.86 E 532700.60 E 532779.67 E 532853.58 E 532934.94 E 533010.28 E 533089.67 E 533164.66 E 533241.21E 533320.02 E 533395.70 E Dogleg Rate (°/'~OOft) 0.365 0.555 0.315 0.238 1.269 0.419 0.384 0.761 0.833 0.265 0.264 0.431 0.461 0.241 0.316 0.731 0.279 1.023 0.671 0.255 0.414 0.298 2.116 1.046 0.852 0.431 0.322 0.459 '1.168 0.518 North Slope, Alaska Kuparuk 3K Vertical Section Comment 2022.17 2103.87 2193.58 2275.27 2359.91 2445.37 2531.08 2616.25 2699.35 2784.52 . 2869.83 2954.17 3039.12 3124.62 3208.42 3288.96 3372.31 3457.12 3541.82 3627.51 3711.10 3797.45 3877.61 3965.50 4047.46 4133.95 4215.41 4298.63 4384.10 4465.95 f8 July, 2001-4:05 Page 3 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 3K-20 Your Reft API-50029230'!900 Job No. AKZZ'IOf74, Surveyed: '10 June, 200'1 Kuparuk River Unit Measured Depth- (E) 6100.88 6194.55 6288.76 6382.76 6477.09 6572,37 6667.52 6763.23 6858.18 6944.00 7039.22 7132.31 7226.78 7321.68 7412.52 Incl. 63.640 63.340 63.990 63.490 63.170 63.090 62.940 63.510 63.3OO 63.410 64.370 64.580 64.940 64.750 64.380 7504.71 7599.69 7646.85 7753:22 7802.92 7897.23 7991.61 8087.90 8181.70 8277.57 8374.45 8472.71 8568.32 8665.14 8757.90 64.580 64.400 -64.030 65.940 66.190 67.180 64.810 65.410 63:940 64.230 62.940 63.840 65.130 65.010 63.620 67.710 67.220 68.030 67.490 68.000 68.180 68.100 67:610 66.820 67.260 66.930 66.590 66.110 66.310 66.720 66.570 67.040 66.75O 66.900 65.190 65.450 65.850 63.57O 63.600 65.030 68.410 68.570 68.740 64.930 63.290 Sub-Sea Depth (ft) 3363.04 3404.85 3446.65 3488.24 3530.58 3573.64 3616.82 3659.93 3702.44 3740.93 3782.83 3822.95 3863.23 3903.57 3942.58 3982.30 4023.21 4043.72 4088.7O 4108.86 4146.19 4184.58 4225.11 4265.23 4307.13 4350.24 4394.25 4435.44 4476.26' 4516.47 Vertical Depth (ft) 3431.64 3473.45 3515.25 3556.84 3599.18 3642.24 3685.42 3728.53 3771.04 3809.53 3851.43 3891.55 3931.83 3972.17 4011.18 4050.90 4091.81 4112.32 4157.30 4177.46 4214.79 4253.18 4293.71 4333.83 4375.73 4418.84 4462.85 4504.04 4644.86 4585.07 Local Coordinates Northings Eastings (ft) (ft) 1813.93 N 1846.05 N 1878.19 N 1910.10 N 1942.02 N 4176.17 E 4253.59 E 4331.67 E 4409.70 E 4487.71 E 4566.56 E 4645.26 E 4724.40 E 4802.68 E 4873.31 E 4952.07 E 5029.25 E 5107.53 E 5186.13 E 5261.37 E 1973.74 N 2005.31N 2037.52 N 2O70.40 N 2100.32 N 2133.60 N 2166.75 N 2201.02 N 2235.68 N 2268.37 N 2301.35 N 2335.11N 2351.77 N 2389.71N 2408.15 N 5337.75 E 5416.54 E 5455.60 E 5544.21E 5585.72 E 2444.31N 2479.86 N 2517.17 N 2554.89 N 2592.26 N 5664.41E 5742.95 E 5821,92 E 5897.85 E 5975.56 E 2626.56 N 2658.77 N 2690.18 N 2724.71N 2761.20 N 6055.24 E 6136.97 E 6217.33 E 6298.03 E 6373.24 E Global Coordinates Northings 6010246.85 N 6010279.28 N 6010311.73 N 6010343.94 N 6010376.17 N 6010408.19 N 6010440.07 N 6010472.60 N 6010505.78 N 6010535.98 N 6010569.57 N 6010603.02 N 6010637.61N 6010672.56 N 6010705.55 N Eastings (fi) 533475.85 E 533553.15 E 533631.09 E 533709.00 E 533786.88 E 533865.61E 533944.18 E 534023.20 E 534101.35 E 534171.86 E 534250.49 E 534327.54E 534405.68 E 534484.14 E 534559.26 E 6010738.83 6010772.90 6010789.72 6010828.00 6010846.61 6010883.08 6010918.93 6010956.56 6010994.58 6011032.25 6011066.86 6011099.39 601.1131.11 6011165.96 6011202.75 N 534635.50 E N 534714.16 E N 534753.15 E N 534841.61E N 534883.05 E N 534961.61E N 535040.01E N 535118.83 E N 535194.61E N 535272.17 E N 535351.71E N 535433.32 E N 535513.56 E N 535594.12 E N 535669.18 E Dogleg Rate (°/'~OOft) 0.485 0.567 1.034 0.741 0.590 0.188 0.175 0.751 0.776 0.476 1.055 0.399 0.597 0.277 0.576 0.262 0.485 0.960 1.800 3.185 1.080 2.541 2.236 1.567 1.375 3.396 0.927 1.359 3.571 2.187 North Slope, Alaska Kuparuk 3K Vertical Section Comment 4552.70 4636.48 4720.87 4805.12 4889.36 4974.28 5059.00 5144.39 5229.27 5305.95 5391.43 5475.42 5560.87 5646.77 5728.79 5811.98 5897.68 5940.14 6036.51 6081.93 6168.54 6254.75 6342.07 6426.80 6512.99 6599.73 6687.48 6773.65 6861.41 6944.97 f8 July, 2001 - 4:05 Page 4 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 3K-20 Your Ref: API-500292301900 Job No. AKZZlO174, Surveyed: lO June, 2001 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 8853.84 62.370 60.250 4560.04 4628.64 8949.37 62.760 61.030 4604.05 4672.65 9050.84 63.400 60.190 4649.99 4718.59 9144.00 64.010 60.540 4691.26 4759.86 9243.88. 62.240 58.480 4736.41 4805.01 57.220 57.350 59.720 59.610 62.740 62.920 '62.800 65.060 63.770 63.520 9338.11 62.850 9432.05 63.360 9529.84 62.380 9626.17 62.840 9720.59 62.120 9818.36 62.820 9913.70 64.100 10009.3t 63.900 10104.47 64.520 10198.19 65.360 Local Coordinates Northings Eastings Northings (ft) (ft) (ft) Global Coordinates 2801.61 N 6448.54 E 6011243.46 N 2843.18 N 6522.44 E 6011285.32 N 2887.58 N 6601.26 E 6011330.03 N 2928.88 N 6673.86 E 6011371.61N 2974.07 N 6750.63 E 6011417.10 N 10296.77 63.980 65.260 10391.49 61.660 67.810 10487.81 62.530 66.750 10583.85 63.480 66.420 10681.11 61.130 66.500 4779.86 4848.46 3018.56 N 6821.42 E 4822.35 4890.95 3063.84 N 6891.91 E 4866.95 4935.55 3109.27 N 6966.13 E 4911.27 4979.87 3152.47 N 7039.95 E 4954.90 5023.50 3192.84 N 7113.30 E 6011461.87 N 6011507.43 N 6011553.15 N 6O11596.64 N 6011637.30 N 5000.09 5068.69 3232.43 N 7190.43 E 6011677.19 N 5042.69 5111.29 3271.34 N 7266.33 E 6011716.39 N 5084.61 5153.21 3309.10 N 7343.51 E 6011754.46 N 5126,01 5194.61 3346.10 N 7420,79 E 6011791.77 N 5165.71 5234.31 3383.79 N 7496.86 E 6011829.75 N 5207.89 5276.49 3422.31 N 7577.20 E 5251.16 5319.76 3455.87 N 7654.47 E 5296.24 5364.84 3488.75 N 7732.98 E 5339.83 5408.43 3522.76 N 7811.51 E 5385.03 5453.63 3557.15 N 7890.45 E 10779.93 59.220 67.020 5434.17 5502.77 10874.23 59.540 67.180 5482.21 5550.81 10971.11 57.590 66.950 5532.73 5601.33 11067.42 55.570 67.470 5585.77 5654.37 11164.87 53.140 67.890 5642.56 5711.16 67.140 66.000 64.600 63.760 64.490 5696.18 5754.88 5814.77 5876.03 5942.10 3590.98 N 3622.56 N 3654.77 N 3685.91N 3715.99 N 7969.22 E 8043.98 E 8120.10 E 8194.21E 8267.46 E 3743.61N 3774.62 N 3806.14 N 3837.21N 3868.02 N 8334.18 E 8405.77 E 8474.32 E 8538.57 E 8602.07 E 11254.82 53.670 11352.45 52.420 11448.79 50.700 11542.85 48.020 11639.54 45.760 5764.78 5823.48 5883.37 5944.63 6010.70 Eastings (ft) 535744.32 E 535818.06 E 535896.71E 535969.14 E 536045.73 E 536116.35 E 536186.66 E 536260.70 E 536334.35 E 536407.54E 536484.51E 536560.26 E 536637.29 E 536714.42 E 536790.35 E 6011868.59 6011902.45 6011935.64 6011969.95 6012004.66 6012038.80 6012070.67 6012t03.17 6012134.61 6012164.97 6012192.85 6012224.15 6012255.94 6012287.26 6012318.32 N 536870.53 E N 536947.67 E N 537026.05 E N 537104.45 E N 537183.26 E N 537261.89 E N 537336.52 E N 537412.52 E N 537486.50 E N 537559.63 E N 537626.25 E N 537697.71E N 537766.14 E N 537830.27 E N 537893.65 E Dogleg Rate (°/lOOft) 3.109 0.832 0.971 0.736 2.554 1.352 0.557 2.378 0.488 3.037 0.734 1.347 2.135 1.384 0.928 2.122 3.425 1.327 1.035 2.417 1.986 0.369 2.023 2.145 2.518 0.892 1.584 2.117 '2.929 2.401 North Slope, Alaska Kuparuk 3K Vertical Section Comment 7030.23 7114.67 7204.78 7287.93 7376.48 7459.30 7542.17 7628.50 7713.54 7797.00 7883.58 7968.76 8054.65 8140.30 8225.14 8314.21 8398.45 8483.53 8569.10 8655.21 8740.92 8822.05 8904.68 8985.04 9064.18 9136.36 9214.37 9289.82 9361.16 9431.71 18 July, 2001-4:05 Page 5 of 7 DrillQuest 2. 00. 08,005 Sperry-Sun Drilling Services Survey Report for 3K-20 Your Ref: AP1-500292301900 Job No. AKZZ10174, Surveyed: 10 June, 2001 Kuparuk River Unit Measured Depth Incl. (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) Local Coordinates Global Coordinates Northings · Eastings Northings Eastings (ft) (ft) (ft) (ft) 11734.96 42.760 65.660 11829.91 39.620 65.680 11927.39 37.870 65.430 12023.56 35.780 65.650 12119.62 33.420 65.680 12216.49 31.710 64.420 12312.40 31.490 63.740 12405.51 31.650 64.460 12502.49 31.350 64.620 12598.21 30.800 65.970 6010.43 6081.88 6157.90 6234.88 6313.94 6395.58 6477.27 6556.60 6639.29 6721.27 12647.72 30.750 66.210 6763.81 12706.00 30.750 66.210 6813.90 6079.03 6150.48 6226.50 6303.48 6382.54 6464.18 6545.87 6625.20 6707.89 6789.87 6832.41 6882.50 3896.10 N 8662.45 E 6012346.64 N 537953.91E 3921.86 N 8719.42 E 6012372.62 N 538010.78 E 3947.10 N 8774.95 E 6012398.08 N 538066.22 E 3970.97 N 8827.42 E 6012422.15 N 538118:59 E 3993.45 N 8877.12 E 6012444.83 N 538168.20 E 4015.43 N 8924.39 E 6012466.99 N 538215.39 E 4037.39 N 8969.59 E 6012489.14 N 538260.50 E 4058.69 N 9013.44 E 6012510.60 N 538304.27 E 4080.47 N 9059.19 E 6012532.56 N 538349.93 E 4101.12 N 9104.07 E 6012553.39 N 538394.73 E 4111.39 N 9127.23 E 6012563.75 N 538417.85 E 4123.41N 9154.50 E 6012575.88 N 538445.07 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 69.1' MSL. Northings and EaStings are relative to 1422' FSL & 319' FWL. Magnetic Declination at Surface is 26.139° (26-May-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1422' FSL & 319' FWL and calculated along an Azimuth of 65.760° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12706.00ft., The Bottom Hole Displacement is 10040~29ft., in the Direction of 65.752° (True). Dogleg Rate (°/100ft) 3.258 3.307 1.802 2.178 2.457 1.899 0.437 0.440 0.321 0.927 0.268 0.000 North Slope, Alaska Kuparuk 3K Vertical Section Comment 9498.29 9560.82 9621.82 9679.46 9734.00 9786.13 9836.37 9885.09 9935.75 9985.16 10010.49 10040.29 Projected Survey DrillQuest 2.00.08.005 f8 July, 2001- 4:05 Page 6 of 7 Sperry-Sun Drilling Services Survey Report for 3K-20 Your Ref: AP1-500292301900 Job No. AKZZ10174, Surveyed: 10 June, 2001 Kuparuk River Unit North Slope, Alaska Kuparuk 3K Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings fit) (ft) (ft) 532.00 530.37 5.32 N 19.08 E 532.00 530.37 5.32 N 19.08 E 12706.00 6882.50 4123.41 N 9154.50 E Comment Latest C.B. Gyro Survey @ 532' MD Tie on to Gyro Projected Survey Survey tool prOgram for 3K-20 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth fit) (ft) Survey Tool Description 12706.00 6882.50 AK-6 BP_IFR-AK (3K-20) July, 200~ - 4:05 Page 7 of 7 DrillQuest 2.00.08.005 7/9/2001 Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99603-6711 ~ ATTN: Sherrie NO. 1267 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99601 Field: Kuparuk Well Job # Log Description Date BL Sepia CD Color lC-133 _~-/~. -O~ 21312 SCMT 06118/01 1J-09 ZO(" 0~/¥ 21311 SCMT 06105/01 1 1J-10 ~(.0'~! 21306 SCMT - 06/12/01 1 3H-11 / j~7.-/~.~f 21314 USIT 061t4/01 3H-11 /~7' J~.~/~ 21314 USIT 06114101 1 3K-20 ~_~,/-/¢t¢1~ 21313 SCMT 06/18/01 I ' DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) $61-8317. Thank you. RECEIVED 'JUL 1 3 2001 , Alaska Oil & Gas Cons. CmmlnJse~n Anchorage OIL GAS CONSERVA ION COH IISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 James Trantham Drilling Engineering Supervisor 'Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510 Re: Kupamk River Unit 3K-20 Phillips Alaska, Inc Permit No: 201-088 Sur Loc: 1422' FSL, 319' FWL, Sec. 35, T13N, R9E, UM Btmhole Loc: 246' FSL, 1109' FEL, Sec. 25, T13N, R9E, UM Dear Mr. Trantham: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit 3K-20. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on 3K-20 must comply with the requirements and. limitations of 20 AAC 25.080. Approval of thiS permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year.' Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this .1~ '~day of May, 2001. jjc/Enclosures. CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. t' STATE OF ALASKA I' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work:. Drill r~ Redrill E] I lb. Type of well. Exploratory D Stratigraphic Test [~] Development Oil r~ Re-entry D Deepen DI Service D Development Gas D Single Zone [] Multiple Zone D 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 34 feet 3. Address 6. Pmperbj Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25519 ALK 2555 Kuparuk River Pool 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 1422' FSL, 319' FWL, Sec. 35, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 185' FSL, 1246' FEL, Sec. 25, T13N, R9E, UM 3K-20 #59 52 180 At total depth 9. Approximate spud date Amount 246' FSL, 1109' FEL, Sec. 25, T13N, R9E, UM May 21, 2001 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1109' @ TD feetI 3K-02 12.4' @ 400' feet 2560 12660' MD /6837' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 300 MD Maximum hole angle 63.9° Maximum surface 2740 psig At total depth (TVD) 3476 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casin~l Weight Grade Couplin~l Len~h MD TVD MD TVD linclude sta~e data) 24" 16" 62.5# H-40 Weld 127' 34' 34' 161' 161' 230 sx ASI 9.875" 7.625" 29.7# L-80 BTC-Mod 7683' 34' 34' 7717' 4141' 590 sx AS3 Lite, 310 sx LiteCrete 6.75" 5.5" 15.5# L-80 BTCM 12166' 34' 34' 12200' 6444' 190 sx Class G GasBIok 6.75" 4.5" 12.6# L-80 NSCT 460' 12200' 6444' 12660' 6837' see above 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) tree vertical feet Effective Depth: measured feet Junk (measured) tree vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface RECEIVED Production MAY 1 0 2001 Perforation depth: measured Alaska Oil & Gas Cons. Commission tree vertical Anchorage 20. Attachments Filing fee ~] Property Plat [~ BOP Sketch [~] Diverter Sketch r'l Drilling program [~] Drilling fluid program r'~ Time vs depth plot [~Refraction analysis [~] Seabed report D 20 AAC 25.050 requirements r~ 21. i hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Todd Mushovic 265-697, Signed~'~~ Title:DrillingEngineeringSupervisor Date James Tranthan //'~" ~//~~,.~ ,,,~x"E Pret)ared by Sharon AI/suo-Dr~k~ ~,,,/'z.,¢,~_.~ ,~,,~~ Commission Use Onl) Perm, Number I AP, number ISee cover letter .~_.~ ~/- o ~ ~ 5o- <3 ~ ? .-- ~ .~ o/' ~ J Ifor other requirements Conditions of approval Samples required r-] Yes E~ No Mud log requi~d' [~ Yes .1~ No Hydrogen sulfide measures J~ Yes [~ No Directional survey required ,,~ Yes D No Required working pressure for BOPE r'12M; r-~ 3M; E~ 5M; r-] lOM;[~--[~_ _ _~'{~(~'~A~3D'~"~'~IJ~I'~,I'%\¢'/~5~ Other: D Taylor S~amour~f by order of _ Approved by .... Commissioner . . the commission Date Form 10-401 Rev. 12/1/85 · ORIGINAL Submit in triplicate DRAFT App~ :on for Permit to Drill, Well 3K-20 Revision No.0 Saved: 9-May-01 Remove the DRAFT stamp when the document has been approved Permit It- Kuparuk 3K-20 Applicat/on for Perm/t to Dr///Document MaxWell I~1(~ x i mi z E Well VoluE Table of Contents '1. = 1 = 1 SM 1 am Si 10. 11. 12. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25. 005 (f) ........................................................................................................ 2 Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ........................................................................................................ 2 Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25. 005(c)(3) ................................................................................................... 3 Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 Casing and Cementing Program ............................................................................. 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25. 005(c)(7) ................................................................................................... 4 Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25. 005(c)(8) ................................................................................................... 4 Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 Seismic Analysis ...................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ........................................................... , .................................... 5 Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 Evidence of Bonding ................................................................................................ 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 ORIGINAL Permit It. doc Page 1 of 7 Printed: 9-May-01 DRAFT AppJ~ ion for Permit to Drill, Well 3K-20 Revision No.O Saved: 9-May-01 Remove the DRAFT stamp when the document has been approved 13. Proposed Drilling Program ...................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 7 Attachment 1 Directional Plan ................................................................................................................ 7 Attachment 3 Drilling Hazards Summary ............................................................................................... 7 Attachment 4 Cement Loads and CemCADE Summary. ...................................................................... 7 Attachment 7 Well Schematic ................................................................................................................ 7 1 m Well Name Requirements of 20 AAC 25. 005 (f) Eac?~ well taus/be identified by a unique name desLqna~ed by the opera,or and a unique API number a~'igned by ~he c~nTmis~Jor~ under 20 AAC 25.0~0(b). For a ~e// with multiple we// bt~nche~; each branch must s~m//affy be/~ent/fied by a unique name and API nurnber by a~iing a suff~;¥ to the name designated for the well by the operator and to the nun?be' as:~igned to the well by the commination. The well for which this Application is submiEed will be designated as 3K-20. Location Summary Requirements of 20 AAC 25. 005(c)(2) An application for' a Permit to Drill must be accompanied by each of tile ~/Iowing items, except for an item a/ready on file with the con'~n?ission and identified in the application: (2) a plat' identifying the property arid the property's owners and showing (A)the coordinates' of the proposed location of the well at the surf'ace, at the top of each objectlve formation, and at' total depth, referenced to governmental se~ion #ne$. (Et) rite coordinates of the proposed Io~tion of'the we# at tl~e s'urfac~; reft, rented to the state plane coordinate system fbr this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Adminisb'ation; (C) the p~oposed depth of'the well at tile top of each objective fbrmation and at total depth; Location at Surface I 1422' FSL,. 319' FWL, NG$ Coordinates Nor~h/n.qs: 6,008.416.59 Easr/ngs: 529,306.84 Sec 35~ T13N, R9E, UM RKB E/evat/°n l Pad Elevation 103.7' AMSL 69.1' AMSL Location at Top of 185' FSL, 1246' FEL, Sec 25, T13N, R9E, UM Productive Interval (Kuparuk "A" Sand) N~S Coordinates Measured Depth~ RKB: 12,362 North/rigs: 6,012,500 East/rigs: 539,280 Total Vert/ca/Depth~ RKB: 6579 Total Vertical Depth~ SS: 6510 Location at Total Depth J 246' FSL, 1109' FEL, Sec 25, T13N, R9E, UM NGS Coordinates Measured Depth~ RKB: 12,660 Northings: 6,012,561.72 Eastings: 538,415.63 Tota/ Vertica/ Depth~ RKB: 6837 Tota/ Vertical Depthz $$: 6768 and (D) other information required by 20 AAC 2..5~ Requirements of 20 AAC 25.050(b) ]fa we//is to be intentionally deviated, ~ize application fora Permit to Dr///(Form .Z O-40Z) rnust ORIGINAL Permit It. doc Page 2 of 7 Printed: 9-May-O 1 m 1 Si DRAFT App~ ....;on for Permit to Drill, Well 3K-20 Revision No.0 Saved: 9-May-01 Remove the DRAFT stamp when the document has been approved (1) include a p/at, drawn to a suitable sca/e, showing the path of the proposed we#bore, including ail adjacent wellbore~ within 200 feet of any potion of the proposed we/I; Please see A~achment Z: D/regional Plan and (2) for all well~ within 200 feet of the proposed we//bore (A) li~t the name~ of the operator~ of tho~e we/L~ to the extent that thoze name~ are known or discoverable in public record~5 and ~how that each named opez~:tor ha~ been furnished a copy of the application by ce~ified mai~' or (B) state that the applicant i~ the only aNected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AA C 25. 005(c)(3) An application for a PernT/t to Drill must be accompanied by each of the fo#ow#?g items; except for an item a/ready on file with the cornmi~ion and identified in the application: (3) a diagram and de$cffpbon of the blowout prevent/on equipment (BOPE) as required by 20 AA£ 25.03~ 20 AAC 2~.05'b; or 20 AAC 25.037, as' app/icabl~v Refer to documents on File Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application fbr a Permit to Drill must be accompanied by each of the to/lowing items, except for an item a/ready on fife with the commission and identified in the application: (~) information on dr#ling hazar~¢, including (A) the max#num downhole pressure that may be encountered, criteria used to determine it., and n~axin?um potential surface pres'sure based on a rnethane gradient; The expected reservoir pressure in the Kuparuk sands in the 3K-20 area is expected to be 3a,00 psi, 0.52 psi/ff. This pressure was extrapolated from offset wells. The maximum potential surface pressure (MPSP) based on the expected reservoir pressure gradient, a methane gradient (0.:[1) and the vertical depth of the expected base of the Kuparuk formation is 2740 psi, calculated thusly: MPSP =(6685 ff)(0.52 - 0.11 psi/fi) =2740 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concernir~g potential causes of'hole problems such as abnom?ally geo..pt~,ssured strata, lost circulation zone~ and zones that have a pzopensity for di~brential sticking; Please see A~achment 2: Drilling Hazards Summa~, Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25. 005 (c)(5) An al~pfication for a Permit t'o Dr/II must be accompanied by each of the fo/low#Lq items, except for an item a/ready on file wit/? the cof'nmis:~on and identified in the application: (5) a desc'ription of the procedure for conduct#']g formatK)n integrity tests; as' required under 20 AAC 25",030(f); A formation integrity test will be performed in accordance with the LOT / F]:T procedure that Phillips Alaska has on file with the Commission. ORIGINAL Permit It. doc Page 3 of 7 Printed: 9-May-O 1 DRAFT App,' ';on for Permit to Drill, Well 3K-20 Revision No.0 Saved: 9-May-01 Remove the DRAFT stamp when the document has been approved 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Dr/fl must be accompanied by each of the following item~, except for an item a/ready on file with the commission and identified in the a/~lication: (d) a complete proposed casing and cement#?g program as required by 20 AAC 25.030, and a description of any 5lotted #net, pre- perforated liner, or screen to be installed; Casing and Cementing Program Hole Top Btm Csg/-I'bg Size Weight Length MD/I'VD MD/I'VD OD (in) (in) (lb/fi) Grade Connection (ft) (fi) (ft) Cement Program 16 24 62.5 H-40 Welded 160 Surface 161 / 161 Cemented from surface 7-5/8 9-7/8 29.7 L-80 BTCM 7682 Surface 7717 / 4141 See Attachment 5-1/2 x 6-3/4 15.5 & L-80 BTCM & 12,165 Surface / 12660 / 6837 See 4-1/2 12.6 NSCT & 460 12,220 Attachment See also Attachment 3: Cement Loads and CemCADE Summary. 7. Diverter System Information Requirements of 20 AAC 25. 005(c)(7) An ,Tpplication fbr a Permit to Dr/ii must be accompanied by each of the fbi/owing item~ except tbr an item a#~ady on file with the c~xnmi.~s'iofl and identified in the (7) a diagram and description of the d/verter system as required by 20 AAC.2f 035; un/ess this requ#~ment is waived by the ~fT~fTU:5:~fOR under 20.AAC 2b~ 035(/8(2); Please refer to documents on file with the Commission for Nabors Rig 8. Drilling Fluid Program Requirements of 20 AAC 25. 005(c)(8) An application fbr a Pem#t to Drill must be accompanied by eacfz of the fbi/owing item.S excerpt for an item a/ready on file w/th the conmTL~'ion and ident/fi~.d fi~ the application: (8) a df riling fluid progran; inc/ud#~g a dia,]ram and description of the dH//i~q fluid ~sten; as requ/i'ed by 20 AAC 25,033; Drilling will be done with a bentonite slur~ having the following pro ~erites over the listed inte~als: Interval Density Funnel Yield Point Plastic 10 sec Gel 10 min Gel (ppg) Viscosity (cP) Viscostiy Strength Strength (seconds) (lb/lO0 sO (lb/lO0 sf) (lb/t00 sf) Surface Hole Surface to 500' 8.5 - 9.0 150 - 200 50 -70 40 - 60 15 - 30 8 - 15 500' to Base of Permafrost 8,6 - 9.4 100 - 150 Final 9.4 - 9.6 60 - 150 25 - 50 20 - 40 15 - 40 4 - 6 Production hole Initial section 8.6 - 9.0 35 - 45 8 -12 5 - 10 3 - 6 8 - 15 Intermediate section 10.5 45 - 55 15 - 25 20 - 25 6 - 10 <5 Pay-Zone 10.5 50 - 65 15 - 25 25 - 35 4 - 7 8 - 10 (Tau O) (HTHP) Please refer to documents of file with the Commission for Nabors Rig 16E. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. ORIGINAL Permit It. doc Page 4 of 7 Printed: 9-May-O 1 DR FT App,¢" ';on for Permit to Drill, Well 3K-20 Revision No.0 Saved: 9-May-01 Remove the DRAFT stamp when the document has been approved 1 10. 11. 12. 13. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to D/#/ must be accompanied by each of the fo/lowing items, except for an item a/ready on file w/th the commission and identified in tile application: (9) for an exploratory or stratigraphic test we/I, a tabu/at/on setting out the depths of predicted abnor'n?a/ly geo-pressured strata as required by 20 AAC 25.033(0; Not applicable: Application is not for an exploratory or s/rat/graphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of'the fo/lowing items; except for an/tern all'early on file with the commission and identified in the application: (lO) for an exploratory or stratigraphic test we/I, a seismic refract/on or reflect/on analysis as required by 20 AAC 2~ OdT (a); Not applicable: Application is not for an exploratory or s/rat/graphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application fbra Pern#t to Dr/Il must be accompanied by each of the tbllowing items, except tbr an item a/ready on file w/th the commi~s'ion and/dent/fi'ed in the ap/N/cation: (11) for a we// dr#led £rom an o?fshore platform, mobile bottom..£ounded structure, jack...up rLg, or floa~.ing dr/il#Lq vessel, an analysis o? s'eabed conditions as required by 20 AAC 25.05il(b); Not applicable: Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application fbra Permit to Dr///must bE: accompar#ed by each of' the t'ollowirLq items, except for afl item a/ready on fife with the cornn#ssion and ~dent~fled in the app/ication: (:12) evidence showing that the requirements o£20 AAC 25.025 {.Bonding.)have been met; Evidence of bonding for Phillips Alaska, Tnci is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25. 005 (c)(13) An application tbra Permit to DH// must be accompanied by each of' the fo/lowing/fem.% except fbr an item <~ready on file w/th the commk¢sion and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16" conductor. Weld landing ring on conductor. 2. MTRU Nabors Rig 16E. :/ns/all diverter and function test same. 3. Spud and directionally drill 9-7/8" hole to desired targets through West Sak interval. Run MWD/LWD/PWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Circulate and condition hole to run casing. POOH. 5. Run and cement 7-5/8" 29.7# L-80 BTCM casing string to surface. Displace cement with mud and perform stage job or top job if required. 6. Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test to 5,000 psi. 7. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. UHib iivAL Permit It. doc Page 5 of 7 Printed: 9-May-01 DRRFT AppJ," '~on for Permit to Drill, Well 3K-20 Revision No.O Saved: 9-May-O1 Remove the DRAFT stamp when the document has been approved 8. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the F~ or LOT EMW). 9. Directionally drill 6-3/4" hole to top kuparuk (12165' MD) according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. Perform second LOT to evaluate long string option. :If LOT is adequate to long string, drill to well total depth (12660' ND), run 5-1/2" 15.5# by 4-1/2" 12.6 L-80 BTCM casing to surface and cement, and continue with step #15. 10. If LOT is inadequeate to Iongstring than drill 6-3/4" hole to a TD of 12,165' MD, run 5-1/2" 15.5# L-80 BTCM casing to surface and cement. 11. Nipple up BOP stack and pressure test to 5~000 psi. 12. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 13. Drill 4-3/4" hole to well total depth (+/- 12660' MD) according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH 14. Run and cement 3-1/2" 9.3# L-80 SHLT liner and Baker ZXP/Flexlock hanger/packer assembly. Set packer +/- 150' above intermediate casing shoe to provide appropriate liner lap. 15. Run and land 3-1/2" tubing with gas lift completion. 16. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Tnstall test plug. Pressure test production tree. Pull test plug. Secure well. 17. Freeze protect well. Set BPV. Release rig and turn well over to production. 18. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) A/7 app/icafio/) for a Permit to Dr/'//mu.¢tc be acco/npa/)ied by each of #)e ~//owi/tg /te/n~S except ~r an #:em a/ready on fi/e with the comm/:s.¢ion and identified fi~ the application: (Z,I) a genezal deso'ipt/on of how the operatoz' p/ans to dis79ose of dri/ling mud and czz(tings and a statement of whether ~he operator intends to 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~t~har by ¥,~,~-~:)~ ~.Dermitted ann~JlHs on 1~ by hauling the fluids to a KRU Class ]3: disposal well. All cuttings r¢~'~'¢2,~:,O gener,~ted will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary . ,,,o storage and eventual processing for injection down an approved disposal well. ~-'~ ,~ Phillips Alaska does not intend to request authorization for the use of this well for annular disposal ~,~, ~'k~./! operations. ORIGINAL Permit It. doc Page 6 of 7 Printed: 9-May-01 DRAFT ApI~' 'ion for Permit to Drill, Well 3K-20 Revision No.O Saved: 9-May-01 Remove the DRAFT stamp when the document has been approved 15. Attachments Attachment I Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary. Attachment 4 Well Schematic. ORIGINAL Permit It. doc Page 7 of 7 Printed: 9-May-01 Kuparuk River Unit North Slope, Alas ~ ~ 7 May, 2001 Surface Coordinates relative to Project H Reference: f008426.53 N, 29307.84 E (Grid) Surface Coordinates relative to Structure: 0.20 S, ~.72 E (True) Kelly Bushing: 69.10ft above Mean Sea Level A Na~libertoe Proposal Ref: pro9495 Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 0.00 0.000 0.000 -69.10 0.00 100.00 0.000 0.000 30.90 100.00 200.00 0.000 0.000 130.90 200.00 300.00 0.000 0.000 230.90 300.00 400.00 2,000 65.743 330.88 399.98 500.00 4.000 65.743 430.74 499.84 600.00 7.000 65.743 530.27 700.00 10.000 65.743 629.15 800.00 15.000 65.748 726 900.00 20.000 65.750 1000.00 25.000 g83.55 1100.00 30.000 ~~.% 1003.13 1072.23 1200.00 35.~_~.7~ '~?~' 1087.44 1156.54 130~..~_~ ~~~ 1166.75 1235.85 1500 65.755 1307.99 1377.09 1600.~ 55.000? 65.756 1368.85 1437.95 1700.~ 50.000 65.756 1422.56 1491.66 1777.99 63.900 65.756 1459.23 1528.33 1800.00 63.900 65.756 1468.91 1538.01 1900.00 63,900 65.756 1512.91 1582.01 2000.00 63.900 65.758 1556.90 1626.00 2018.40 63.900 65,756 1565.00 1634.10 2100.00 63.g00 65.756 1600.89 t669.99 2200.00 63.900 65,756 1644.89 1713.99 Sperry-Sun Drilling Services Proposal Report for 3K.20 wpOf Revised: 6 May, 200t Local Coordinates Northings Eastings (ft) (ft) 0.00 N 0.00 E Global Coordinates Northings Eastb (ft) 0.00N 0.00 N 0.00N 6.80 N N 21.76 N 34.11 N 49.82 N 68.78 N 90.84 N 115.83 N 143.58 N 173.83 N 206.40 N 241.02 N 269.28 N 277.39 N 314.27 N 351.14 N 357.93 N 388.02 N 424.89 N 0.00 E 6.36 E 15.10 E 28.57 E 48.30 E 75.71 E 110.59 E 152.68 E 201.65 E 257.14 E 318.72 E 385.93 E 458.24 E 535.12 E 597.87 E 615.89 E 697.77 E 779.65 E 794.72 E 861.54 E 943.42 E 6008417.25 N 6008419.42 N 6008423.39 N 6008429.52 N 6008438.48 N 6008450.94 N 6008466.79 N 6008485.91 N 6008508.16 N Co008533.37 N 6008561.34 N 6008591.87 N 6006824.73 N 6008659.65 N 6008688.15 N 6008696.34 N 6008733.53 N 6OO8770.73 N 6008777.56 N 6008807.93 N 6008845.12 N 529306.84 E 529306.84 E 529306.84 E 529308.43 E 529313.19 E 529321.91E 529335.36E 529355.06E 529382.42 E 529417.23 E 529459.25 E 529508.14 E 529563.53 E 529625.00 E 529692.08 E 529764.27 E 529841.01 E 529903.65 E 529921.63 E 630003.37 E 530085.11 E 530100.15 E 530166.84 E 530248.58 E 0.000 0.000 0.000 2.000 2.000 3.000 3.000 5.000 5.000 5.000 5.000 5.000 5.000 5.000 5.000 5.000 5.000 5.000 0.000 0,000 0.000 0.000 0.000 0.000 ~erticai ~tion 0.00 0.00 0.00 0.00 1,75 6.98 16.56 31.34 52.98 83.04 121.30 167.46 221.17 282.03 349.56 423.27 502.58 586.89 655.71 675.47 765.27 855.08 871.60 944.88 1034.68 North Slope, Alaska Kuparuk 3K Comment SHL: Y = 6008416.53 & X= 529306.84 (1422' FSL & 319' FW SEC. 35-T13N-R9E) Begin Dir @ 2.00°/100ft in 9-718" Hole' 300.00ft MD, 300.00ft ']'VD Increase in Dir Rate @ 3.00"1100 · 500,00ft MD, 499.84ft 'I'VD Increase in Dir Rate @ 5.00°/100 - 700.00ft MD, 698.26ft TVD End Dir, Start Sail @ 63.900° · 1777.99ft MD, 1528.33ft TVD Base Permafrost 7 May, 200f -6:36 Page 2 of 10 DrillQuest 2.00.08.006 Sperry. Sun Drilling Services Proposal Report for 3K-20 wpOf Revised: 6 May, 2001 Kuparuk River Unit Measured Depth fit) Incl. Sub-Sea Vertical Azim. Depth Depth Northings (ft) (ft) (ft) 2300.00 63.900 65.756 1688.88 2400.00 63.900 65.756 1732.88 2500.00 63.900 65.756 1776.87 2600.00 63.900 65.756 1820.87 2700.00 63.900 65.756 1864.86 2800.00 63.900 65.756 1908.85 2900.00 63.900 65.756 1952.85 3000.00 63.900 65.756 1996.84 3100.00 63.900 65.756 2040.84 3200.00 63.900 65.756 2084.83 Local Coordinates 3300,00 63,900 65.756 2128,83 2 ~0,51 N 3400,00 63.900 65.756 2172,8~ ~~ ~ 867,39 N 3500,00 63,900 65,756 221~..6.~. ~~-~' 904,26 N 3600,00 63.900 65,756 _ ~[:-~29,91 941,14 N 3700,00 63,900 ~~ ~,~ '~73,90 978,01 N 3800,00 63,900 ~ ~/~ 2417,90 1014,89 N 3900,00 63,~~,7~ ~? 2392,79 2461,89 1051,76 N ~~ ~"=~ ~-~< 2436.79 2505,89 1088,64 N 41~~§3~~ 6~ 2480.78 2549.88 1125,51 N 4200~ ;~:~ 65~756 2524,77 2593.87 1162,39 N 4300.~: 63.900~ .... 65,756 2568,77 2637,87 1199,26 N Eastings (ft) 1757,98 461,76 N 1025,30 E 600~2,32 ~ "530330,32 1801,98 498,64 N 1107,18 E ~~~.. ':-53641-.2,06 1845,97 535,51 N 1189,07 E ~,7¥~ 530493:79 1889,97 572,39 N 1270,95 E ~6008~1 ~?> 530575,53 1933,96 609,26 N 1352,83'E ~-:~'~903'~-'-~ 530657,27 1977.95 646.~~.. 1434.71 E'~ 6009068.30 N 530739.00 2021.95 ~~ '%~ 15;'i.6,60 E'" 6009105.50 N 530820.74 2065.94 ~ 71~' ~. i598.~,8 E 6009142.69 N 530902.48 2109.94 ~_ 756~:~'~ 1680.36 E 6009179.89 N 530984.21 2153.93 1762.24 E 6 217.0 N 5310 .95 Global Coordinates . Northings Easfings, (ft) . (ft)=' E E E E E E E E E E 1844.13 E 6009254.28 N 531147.69 E 1926.01 E 6009291.48 N 531229.43 E 2007.89 E 6009328.67 N 531311.16 E 2089.77 E 6009365.87 N 531392.90 E 2171.66 E 6009403.07 N 531474.64 E 2253.54 E 6009440.26 N 531556.37 2335.42 E 6009477.46 N 531638.11 2417.30 E 6009514.66 N 531719.85 2499.19 E 6009551.65 N 531801.58 2581.07 E 6009589.05 N 531883.32 4500.00 63.900 65.756 2656.76 2725.86 1273.01 N 4600.00 63.900 65.756 2700.75 2769.85 1309.89 N 4611.92 63.900 65.756 2705.99 2775.09 1314.28 N 4700.00 63.900 65.756 2744.74 2813.84 1346.76 N 4800.00 63.900 65.756 2788.74 2857.84 1383.64 N 4900.00 63.900 65.756 2832.73 2901.83 1420.51 N 5000.00 63.900 65.756 2876.73 2945.83 1457.39 N 5100.00 63.900 65.756 2920.72 2989.82 1494.26 N 2662.95 E 6009626.24 N 531965.06 E 2744.83 E 6009663.44 N 532046.80 E 2826.72 E 6009700.64 N 532128.53 E 2908.60 E 6009737.83 N 532210.27 E 2918.36 E 6009742.27 N 532220.01 E 2990.46 E 6009775.03 N 532292.01 E 3072.36 E 6009812.23 N 532373.74 E 3154.25 E 6009849.42 N 532455.48 E 3236.13 E 6009886.62 N 532537.22 E 3318.01 E 6009923.81 N 532618.96 E .OogJ: .. rtical ': i}~ate'~'~ ~tion . ..(~looft) 0.000 1124,49 0,000 1214,29 0,000 1364,09 0,000 1393.89 0,000 1483.70 0.000 1573.50 0.000 1663.30 0.000 1753.10 0.000 1842.91 0.000 1932.71 0.000 2022.51 0.000 2112.31 0.000 2202.12 0.000 2291.92 0.000 2381.72 E - 0.000 2471.52 E 0.000 2561.33 E 0.000 2651.13 E 0.000 2740.93 E 0.000 2830.73 0.000 2920.54 0.000 3010.34 0.000 3100.14 0.000 3189.95 0.000 3200.65 0.000 3279.75 0,000 3369,65 0.000 3459.35 0.000 3549.16 0.000 3638.96 North Slope, Alaska Kuparuk 3K Comment Ugnu 7 May, 2001.6:36 Page 3 of 10 DrillQuest 2.00.08.006 Sperry-Sun Drilling Services Proposal Report for 3K-20 wp01 Revised: 6 May, 2001 Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azi m. Depth Depth (ft) (ft) (ft) 5200.00 63.900 65.756 2964.72 3033.82 5300.00 63.900 65.756 3008,71 3077.81 5400.00 63.900 65.756 3052.70 3121.80 5500.00 63.900 65.756 3096.70 3165.80 5600.00 63.900 65.756 3140.69 3209.79 5700.00 63,900 65.756 3184.69 3253.79 r15.5~ 5600.00 63.900 65.756 3228.68 3297.78 17~ 5900.00 63,900 65.756 3272.68 3341.78 _~ 17~ 6000.00 63.900 65.756 3316.67 3385.77 ~ 1826~ 6100.00 63.900 65.756 3360.66 3429.76 _~ 863.~ oo.oo . 6205.31 63.900 65.756 3406,99, ~~ ~901.84 N 6300.00 63.900 65.756 34~,,~_~ ~..~_~, :J~ 1936.76 N 6500.00 63.900 65.7~ ~36.~ ~605.74 2010.51N 6700.0o 63.~%~.7~ '~"3824.63 3693.73 ~~ ~'-~'~ 3668.62 3737.72 6~~6 ~~! 6~ 3712.62 3781.72 7 00. 3 3.70 7300.00 63,900 65.756 3888.60 3957.70 7400.00 63,900 65.756 3932.59 4001.69 · . Local Coordinates Global Coordinates ." Northings Eastings Northings Ea _~gs. (n) (ft) (ft) ~..~.~...~' · 1531.13 N 3399.89 E 600~1.01 ~ ~m~9 E 1568.01 N 348t.78 E ~~~2~.43 E 1604.88 N 3563.66 E 601~.~ ~§286~17 E 1641.76 N 3645.54 E ~-~601~ 1~~? 532945.90 E 1678.63 N 3727.42'E ~"~1010~N 533027.64 E 1715.{ ~ 3~09:31'E ~ ~0146.99 N 533109.38 E ~ ~ 3891.19:E~ 6010184.19 N 533191.11E ~' ~ 3973:07 E 6010221.38 N 533272.85 E '.~- '4054.96 E 6010258.58 N 533354.59 E 4138.84 E 6010295.78 N 533436.33 E 4218.72 E 6010332.97 N 533518,06 E 4223.07 E 6010334.95 N 533522.40 E 4300.60 E 6010370.17 N 533599.80 E 4382.49 E 6010407.37 N 533681.54 E 4464.37 E 6010444.56 N 5.33763.27 E 2047.38 N 4546.25 E 6010481,76 N 533845.01 E 2084.26 N 4628.13 E 6010518,96 N 533926.75 E 2121.13 N 4710.02 E 6010556.15 N 534008.49 E 2158.01 N 4791,90 E 6010593.35 N 534090.22 E 2194.88 N 4873.78 E 6010630.54 N 534171.96 E 2231.76 N 4955.66 E 6010667.74 N 534253.70 E 2268.63 N 5037.55 E 6010704.94 N 534335.43 E 2291.59 N 5088,53 E 6010728.10 N 534386.32 E 2305.51 N 5119.43 E 6010742,13 N 534417.17 E 2342.38 N 5201.31 E 6010779.33 N 534498,91 E 7500.00 63.900 65.756 3976,58 4045.68 2379.26 N 5283.19 E 6010816.53 N 534580.64 E 7600.00 63.900 65.756 4020.58 4089.68 2416.13 N 5365.08 E 6010853.72 N 534662,38 E 7700.00 63.900 65.756 4064.57 4133.67 2453,01 N 5446.96 E 6010890.92 N 534744.12 E 7717.00 63.900 65.756 4072.05 4141.15 2459.27 N 5460.88 E 6010897.24 N 534758.01 E 7800,00 63,900 65,756 4108,57 4177.67 2489,88 N 5528.84 E 6010928.11 N 534825.86 E 0.008 3728.76 0.000 3818.56 0.080 3908.37 0.000 3998.17 0.000 4087.97 0.080 4177.77 0.000 4267.58 0.000 4357.38 0.080 4447.18 0,000 4536.98 0.000 4626.79 0,000 4631.55 0.080 4716.59 0.000 4806.39 o.000 4896.19 0.000 4986.00 0.000 5075.80 0.000 5165.60 0.000 5255.40 0.000 5345.21 0.000 5435.01 0.000 5524.81 0.000 5580.72 0.000 5614.62 0.000 5704.42 0.000 5794.22 0.000 5884,02 0.080 5973.83 0.000 5989.09 0,000 6063.63 North Slope, Alaska Kuparuk 3K Comment Top West Sak Base West Sak 7-5/8" Csg Pt ... Drill 6-3/4" Hole t, TD 7-5/8" Casing ? May, 2001 - 6:36 Page 4 of 10 DrillQuest Z00.08.006 Sperry-Sun Drilling Services Proposal Report for 3K.20 wp01 Revised: 6 May, 2001 Kuparuk River Unit Measured Depth Incl. (f~) 7900.00 63.900 6000.00 63.900 8100.00 63.900 8200.00 63.900 8300.00 63.900 ~ical Sub-Sea Vertical Local Coordinates Global Azim. Depth Depth Northings Eastings Northings EasU.'~. ~Rate''?~:~ ~tion {ft) {ft) {ft) {ft) {ft) : ~~;_;-~ ~lOOft) 65.756 4152.56 4221.66 2526.75 N 5610.72 E 601 .~0~ 5.31 ~:_ '~~-~E 0.080 6153.43 65.756 4196.55 4265.65 2563.63 N 5692.61 E 601~~~_. ~33 E 0.000 6243.23 65.756 4240.55 4309.65 2600.50 N 5774.49 E 6011'~.~. '~507~07 E 0.000 6333.04 65.756 4284.54 4353.64 2637.38 N 5856.37 E ~,_6011~_.90 ~?' 535152.80 E 0.000 6422.64 65.756 4328.54 4397.64 2674.25 N 5938.25'E ~1111~N. 535234.54 E 0.1300 6512.64 8400.00 63.900 65.756 4372.53 4441.63 2711.~=~ 602.0. i'4 E"~ 6011151.29 N 8500.00 63.900 65.756 4416.53 4485.63 2~~ '~ 6i0..2.02E ~- 6011188.49 N 8600.00 63.900 65.756 4460.52 4529.62 ..... 278~~~ ~6183:90 E 6011225.68 N 8700.00 63.900 65.756 4504.51 4573.61 ~ 2821~- 6265.78 E 6011262.88 N 8800.00 63.900 65.756 4548.51 4617.61 ~858.6~ 6347.67 E 6011300.08 N 8900.00 63.900 65.756 4592.50 ~ .50 N 642g.55 E 6011337.27 N 9000.00 63.900 65.756 4636.50~. ~~"~ "*--':~932.38 N 6511.43 E 6011374.47 N 9100.00 63.900 65.756 46 .~80.~,~., ~7~¢' 2969.25 N 6593.31 E 6011411.67 N 9200.00 63.900 65.756 ~ 93.59 3006.13 N 6675.20 E 6011448.86 N 9300,00 63,900 65,75~ ~68.~ ~837.58 3043.00 N 6757.08 E 6011486,06 N 9400.00 63.900 ~ 4~7 4881.57 3079.88 N 6838.96 E 6011523.25 N 9500.00 63.~~.~ -~-4856.47 4925.57 3116.75 N 6920.84 E 6011560.45 N ~~ ~'>~'~'~'¢ 4900.46 4969.56 3153,63 N 7002.73 E 6011597.65 N 97~~3~_~ ~ 4944.46 5013.56 3193.50 N 7084.61 E 6011634.84 N 980~ - 65:~56 4988.45 5057,56 3227.38N 7166.49E 6011672.04N 9900.~'"? 63.900~¢'' 65.756 5032.45 5101.55 3264.25N 7246,37E 6011709.24N 10000.db 63.900 65.756 5076.44 5145.54 3301.13 N 7330.26 E 6011746.43N 535316.28 E 0.000 6602.44 535398.02 E 0.000 6692.25 535479.75 E 0.000 6782.05 535551.49 E 0.000 6871.85 535643.23 E 0.000 6961.65 535724,96 E 0.000 7051.46 535806.70 E 0.000 7141.26 535888.44 E 0.000 7231.06 535970.17 E 0.000 7320.86 536051.91 E 0.000 7410.67 536133.65 E 0.000 7500.47 536215.39 E 0.000 7590.27 536297.12 E 0.000 7680.07 536378.86 E 0.000 7769.88 536460.60 E 0.000 7859.68 536542.33 E 0.000 7949.46 536624.07 E 0.000 8039.29 10100.00 63.900 65.756 5120.43 5189.53 3338.00 N 7412.14 E 6011783.63 N 536705.81 E 0.000 8129.09 10200.00 63.900 65.756 5164.43 5233.53 3374.88 N 7494.02 E 6011820.82 N 536787.54 E 0.000 8218.89 10300.00 63.900 65.756 5208.42 5277.52 3411.75 N 7575.91 E 601t858.02 N 536869.28 E 0.000 8308.69 10400.00 63.900 65.756 5252.42 5321.52 3448.63 N 7657.79 E 6011895.22 N 536951.02 E 0.000 8398.50 10500.~ 63.900 65.756 5296.41 5365.51 3485.50 N 7739.67 E 6011932.41 N 537032.76 E 0.000 8488.30 10600.00 63.900 65.756 5340.41 5409.51 3522.38 N 7821.55 E 6011969.61 N 537114.49 E 0.000 8578.10 10666.68 63.900 65.756 5369.74 5438.64 3546.96 N 7876.15 E 6011994.41 N 537168.99 E 0.000 8637.98 10700.00 63.233 65.756 5384.57 5453.67 3559.21 N 7903.36 E 6012006.77 N 537196.15 E 2.000 8667.82 North Slope, Alaska Kuparuk 3K Comment Begin Dir @ 2.00°/100ft · 10666.68ft MD, 5438.84ft TVD May, 2001 - 6:36 Page 5 of 10 DrillQuest Z00.08.006 Sperry-Sun Drilling Services Proposal Report for 3K-20 wpOl Revised: 6 May, 200f Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates ~"'~Dogi~.~ ~rtJca, Depth incl. Azim. Depth Depth Northings Eastings Northings Easting-~ '~ate~-~' ~tion {ft) (ft) (ft) (ft) (ft) (ft) .~ ..(fi)' .. ~lOOft) 11100.00 55.233 65.756 5589.02 5658.12 3700.23 N 8216.49 E ~6012i~ I~~ .... 537508.73 F 2.000 9011.24 11200.00 53.233 65.756 5647.47 5716.57 3733.55 N 8290.47. E'~ ~1218:~.._N 537562.58 E 2,000 9092.38 11300.00 51.233 65.756 5708.71 5777.81 3766. 8362'i55. E ~ ~Ti2215.36 N 537654.53 E 2.000 9171.43 11400.00 49.233 65.756 5772.67 5841.77 37~~ :~ 843'2.1~E '-~ 6012247.20N 537724.49E 2,000 9248.29 11500.00 47.233 65.756 5839.28 5908.38 ~. 38~~' ~'~8,~00:~)4 E 6012278.09 N 537792.37 E 2,000 9322.87 11600.00 45.233 65.756 5908.45 5977.55 ~5 3857.~ 8566.48 E 6012308.00 N 537858.10 E 2.000 9395.08 11610.68 45.020 65.756 5915.99 5985.09 ~~60.~ 8573.39 E 6012311.14 N 537864.99 E 2.000 9402.65 11700.00 43.233 65.756 5980.10 ~ .49 N 8630.08 E 6012336.90 N 537921.59 E 2.000 9464.84 11800.00 41.233 65.758 6054.13 ~~:~ -~-~'~3914.09 N 8691.37 E 6012364.73 N 537982.76 E 2.000 9532.05 11811.75 40.998 65.756 60~.~_~:~.~ ~.1~~? 3917.26 N 8698.41 E 6012367.94 N 537989.80 E 2.000 9539.78 11900.00 39.233 65.756 ~~99.57 3940.61 N 8750.26 E 6012391.49 N 538041.65 E 2.000 9596.64 12000.00 37.233 ~~~ 62~L02 6278.12 3966.o2 N 68O6.68 E 6012417.12 N 538O97.87 E 2,OO0 9658.52 1216~_~3:~ ~ 6~56 6342.99 6412.09 4005.38 N e. sg4.09 E 6012458.S3 N 538185.13 E 2,OOO 9764.38 12 65~,~ 6372.35 6441.45 4013,39 N 8911.87 E 5012464.90 N 538202.87 E 2.000 9773.88 1227t.~. 31.795 65.756 6432.99 6502,09 4029.26 N 8947.11 E 6012480.91 N 538238.05 E 2.000 9812.53 12300.~' 31.233 65.756 6456.93 6526.03 4035.29 N 8960.50 E 6012486.99 N 538251.41 E 2.000 9827.21 12319.91 30.835 65.756 6473.99 6643.09 4039.50 N 8989.86 E 6012491.24 N 538260.76 E 2.000 9837.47 12361.67 30.000 65,756 6510.00 6579.10 4048.18 N 8989.13 E 6012500.00 N 538280.00 E 2,000 9858.62 12393.98 30.000 65.756 6537.99 6607.09 4054.82 N 9003.87 E 6012506.69 N 538294.71 E 0.000 9874.78 North Slope, Alaska Kuparuk 3K Comment C-70 Top HRZ Base HRZ / Top Kalubik K-1 / Lower Kalubik Top Kuparuk D Top C-4 Top B End Dir, Start Sail @ 30.000°: 12361.67ft MD, 6579.10ft TVD Top A3 Target - T1 (3K-20) A3 Sand Top Geological Top A2 7 May, 2001.6:36 Page 6 of 10 DH#Quest 2.00.08.006 Sperry-Sun Drilling Services Proposal Report for 3K-20 wpOf Revised: 6 May, 200f Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates ~_~.~og""~ ~_~rtical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin!~. ~Rate~-' ~Ction _~}lOOft) (ft) (ft) (ft) (ft) (ft) (ft) ,. (it)" 12459.82 30. OO0 65.756 6595.00 6664.10 4068.33 N 9033.88 E 601 832~..67 E 12484.05 30.000 65.?56 6615.90 6685.09 4073.31 N 9044.93 E 601~.3~ ~538335.?0 E 12500.00 30.000 Co5.756 6629.80 6698.00 4076.58 N 9052.20 E~12~5 l~?' 538342.95 E 12600.00 30.000 65.756 6716.40 6?85.50 4097.12 N 9057.79~=~1254~ 538388.46 E 12659.82 30. OOO ~.756 6768.21 6S37.31 4109.40. N. ~ ~ ~2561.75 N 538415.69 E All data is in Feet (US) unless othenvJse stated. Directions and coq~ are r~letive to True North. vertical depths are relative to F~KB = 69.1' MSL. Northings ~~s~relative to 1422' FSL & 319' FVVL. Magnetic Declination at Surface is 26.167" (24-Ap~_-01~ '~ The Dogleg Sevedty is in Degrees per ~~ Vertical Section is from 1422' FSL ~; ~ a~ cal~iated along an Azimuth of 65.756° (True). Based upon Minimum Curv~~ulat~0~s, at a Measured Depth of 12059.82fL, The Co,om Ho~ eis~m~? !~9~., in the D~ec~ ~ 65.758; (True). 0. OO0 9877.78 0.OO0 9907.69 0.OO0 9919.81 0.000 9927.78 0.000 9977.78 0.0~ loo07.69 North Slope, Alaska Kuparuk 3K Comment Top A1 (Target Base) Base Kuparuk Total Depth' 12659.821t MD, 6837.31ft TVD 4-1/2" Liner 7 May, 2001.6:36 Page 7 of fO DrillQuest 2.00.08.006 Sperry-Sun Drilling Services Proposal Report for 3K-20 wp01 Revised: 6 May, 2001 Kuparuk River Unit ~,-~: Measured Station Coordinates Depth TVD Northings Eastings Comment 0.00 0.00 0.00 N 0.00 E SHL: Y = 6008416.53 & X~9306~~SL & 319' FWL, SEC. 35-T13N-R9E) 300.00 300.00 0.00 N 0.00 E Begin Dir @ 2.00°/1~~'' Hol~.00ft MD, 300.00ft TVD 500.00 499.84 2.87 N 6.36 E Increas~ !~ Dir~~o~r~: 500~ MD, 499.84ft TVO 700.00 698.25 12.88 N 28.57 E Incr.e. ase i~~~_.~/100ft: 700.00ft MD, 698.26tt TVD 1777.99 1528.33 269.27 N 597.87 E .~End Di[.';' S~~°: 1777.99ft MD, 1528.33ft TVD 7717.00 4141.15 2459.27 N 5460.88~ 7'~5/~ Csg ~bi~i'il 6-3/4" Hole to TD 10666.68 5438.84 3546.96 N 7876.~ Begin.:. Dir @ 2.00°/100ft: 10.06~.~ MD, 5438.84ff 'I'VD 12361.67 6579.10 4048.18 N .~.89~:~E ~ End Dir, Start Sail @ 30.000 : 12361.67ft MD, 6579.10ft TVD 12659.82 6837.31 4109.40 N ~~- Total Depth: 12659.82ft MD, 6837.31ft TVD Formation Tops ~ Formati on Plane ~~ ~ o f i I e P e n e t r a t i o n P o i n t (Below Well Origin). : ~a~~ Vertical Sub-Sea Sub-Sea Dip. DiP Dir.':.'~ -~epth Depth Depth Northings Eastings Formation Name Deg': · Deg, :.. ~ (fi) (fi) (ft) (ft) (fi) 156~-0.' .~ 0.225 2018.40 1634.10 1565.00 357.93 N 794.72 E Base Permafrost 270~"( ' ' 3871.~ 0.000"' 0.000 5915.99 0.000 6143.99 0.000 6224.99 0.000 6342.99 0.000 6432.99 0.000 0.225 4611.92 2775.09 2705.99 1314.28 N 2918.36 E Ugnu 0.225 6205.31 3476.09 3406.99 1901.84 N 4223.07 E Top West Sak 0225 726Z26 3941.09 3871.99 2291.59 N 5088.53 E Base West Sak 0.225 11610.68 5985.09 5915.99 3860.95 N 8573.39 E C-70 0.225 1181t.75 6132.09 6062.99 3917.26 N 8698.41 E Top HRZ 0.225 11917.41 6213.09 6143.99 3945.11 N 8760.26 E Base HRZ/Top Kalubik 0.225 12020.00 6294.09 6224.99 3970.97 N 8817.67 E K-1 / Lower Kalubik 0.225 12164.76 6412.09 6342.99 4005.38 N 8894.09 E Top Kuparuk D 0.225 12271.91 6502.09 6432.99 4029.26 N 8947.11 E Top C-4 North Slope, Alaska Kuparuk 3K 7 May, 2001.6:36 Page 8 of fO DriliOuest Z00.08.006 Sperry-Sun Drilling Services Proposal Report for 3K-20 wpOf Revised: 6 May, Kuparuk River Unit Formation Plane Profile Penetration Point (Below Well Origin) Measured Vertical Sub-Sea Su~Sea Dip Dip Dir. Depth Dep~ ~pth Nothings Ea~ings Fo~ati (~) ~g. ~;. (~) (~) (~) (ft) (~) ._ ~ ~ ~'~ ;orm,,o, ;ops (co,,,u~) ~.~ 0.~ o.~s ~236~.67 6579.~0 ~5~0.~ ~.~/'~ ~.~3 E ~Y~p A3 6594.~ 0.~ 0.2~ 12~.82 ~.10 6595.~ 3~~ .~ ~ ~.~ E Top A1 (Tarot ~15.~ 0.~ 0.~5 12~.05 6~5.~ ~15.~:.~~? ~.93 E ~ Ku~ Measured Ve~ica~ Measured.~:~.~~~ ~pth Depth Dep '~:~"Casing ~tail <S~a~> ~u~~~'~16~~ 4141.14 7~/8" Ca~ <Su~a~> ~B~ ~9.~ ~37.31 ~1~" Liner North Slope, Alaska Kuparuk 3K 7 May, 2001.6:36 Page 9 of fO DrillQuest 2.00.08.006 Sperry-Sun Drilling Services Proposal Report for 3K.20 wp01 Revised: 6 May, 2001 Kuparuk River Unit Targets associated with this wellpath Target Name T1 (3K-20) A3 Sand Top Geographical Coordinates #1 ' Target E n t.~,o ~?~'t e s TVD;~ ~o~i~~ Eastings ,;~79-10 ~: ~J~ ~48,18 N 8989.13 E M~n S~ Leve~o~i C~i~t~: ~~.~ '?~, ~12~.~ N 5382~.~ E G~mph]~l C~~.~ -¢~}:. 7~' 42.424W N 149' 41' 15.~91 'W T~ ~ ..; "'~:';~ ~-~~' 6579.10 4208.51 N 89~.76 E ' ' ' ~ ~3 ~79.10 ~76.~ N 8819.25 E 6579.10 ~1.87 N ~68.~ E 6510.00 6012487.00 N 538435.00 E 6510.00 6012660.00 N 538195.00 E 6510.00 6012528.00 N 538110.00 E 6510.00 6012354.00 N 538360.00 E 70° 26' 42.2883" N 70° 26' 44.0020" N 70° 26' 42.7079" N 70° 26' 40.9839" N 149° 41' 11.4097" W 149° 41' 18.4308" W 149° 41' 20.9466" W 149° 41' 13.6321" W North Slope, Alaska Kuparuk 3K Target Target Shape Type Polygon Geological 7 May, 2001.6:36 Page I0 of 10 DrillQuest 2.00.08.006 Sperry-Sun Drilling Services Proposal Data - 3K-20.3k-20 wp01 / .- .... (f=) ;1.' .~_../ ..... . · (") .:'1 (ft) '"'~'~-" t · .'.: ": 'I" (.ft) i:"/l~)Oft'l 'suii~.i o/i..oo=tt.... ' ' 'i." :(~t) ~--.~.-~ ......... ~l.~.~--:,g-~..~...-~ ..... :2_~:.~ ........ !: {~ ~-..i-...~-~ ...... l ..... :---~ _ "..'~.~,..~._-i .... ~.___~_,_, - ........ I ' · ' · ~ . · ' ' ~ - · , '~ I 0,00 . .. O.O00i 0.0.00, 0.00, ., 0.00' 0.00~ · ~. · : .J ~ . J. '.O~O01 ~'~ ~~------~ --~ -'~ .... '-4 ...... ~ ~'-~-'~-:~-- '.. --~: ..... ~-'~ ..... ~ :' ' ~:" ~ ~ ......... ~' ':::'-~::~'. ~ ?--~~"--'~d ....... ~ ......... ~__.~__.:~ .... m ........... :~ .... ~__.~.._____~ ............... ~..~~m --m. ~--: ..... ~ ? · 3 '].' SO0;O~ 200,00, 4.000' 65.743, 499;.84i.: 199 '84, .... 2,8.7.N~ .6.3'6~ 2.000 . 2~000,. · O,O0,O]. '-65;743~ .. 6~98, I '~; ! . '~oo'..o~ :~oo?~o ~%'t-5'~-"~YT~'~-~' ~T~-~21'"~ %%~: :~'~ .... -~-%~5 ~T~b~l ?~:'.oo~. · o. ooo~ '..~ .~I ~ .. ' ~.:.. .: :_ -...~ · .~ . ; ~ ... ' '[ · · '.t .~ . ". ~ ' ': ' ~ ' [ · ' · · · '"" · I · .' t . '._ , '~ ' '~7:~8.~0"~0.~8~.00' 63'.'900 . 6S.756 1~2'8,3~.... ~3:0'.0'8. :.26~2e 'N" 59~.8~ 'E 5.000 ' 5'.000 .' 0..00~' , 0,'015 ' 6.~S:.'71.~ · . . .. .:' ....~...: . . .'.'.. '... -... . .'..' ... ...t .'.." ..'..... · ..., . ........... .'.. . . .. ....... ..:. . ~ . .. ..... ... .... · .... . . ... . ., · . . · · . .... . . . .. , ?~ ~2~z.~.t.'z~'~.~..:ss so.ooo ~s.~'~s:~.zo Zz~o:2~o~.z~ u~.~ ~ ~.ooo .... ~..o~o..... ~.ooo. =:~6".0"0o..~:.~:~ ~i'J~s~'i'~o] "~:~A'!.~o:~eOl. 6s.?s~]6e6~.oo;-':';.'%A:~Oi~oes...~- ~I~o~ ' '-' ' ' ':" "';'"" ~ :...: .... ,~ ..... ~.,= .... ,~ ....... ~ ..... ~ .................. ;-.~-~ ...... ~..~_::,.,.,~..~ o. ooo~. .0...o.oo, ,. o,.~oo~...., o.ooe/:.~ ~,o~:.~i ORIGINAL 24 April, 2001.20:26 .1. DrillQuest Sperry-Sun Drilling Services Proposal Data. 3K-20.3k-20 wp01 24 April, 2001. 20:27 -1- DrillQuest 15~ 45! 60~ North S~ope, Alaska Kuparuk River Unit 3K Pad 3K-2@ (wp01 } Start Sai~ (~ 63900°: 1777 90f~ MD, 1528 33fi TVD t 500 3000 4500 6000 7500 9000 10500 Scale: lirlch = 1500it Sectio-~ P.~imuth: ,¢'~5 756° (7;ue North} 4800 Phillips Alaska, lnc, North S~ope, Alaska Kuparuk River Unit 3K Pad 3K~2@ {wp@l} 1200 2400 3600 4800 I · I · %5!8" Dsg Pt 6000 7200 8400 9600 I J- J Total Depth: ~2659 62fi MO, 6637 3tf~ T~D (246' FSL& tt69* FEL, End Dil, Sta¢[ Sail ~ 3000(}°: 12361 671l MD, ? Dgr Start Sail ~ 63900': 1777 99fi MD, I528 33ft TVD ~ 500'/tOOfft : 700 00~ MD, 698 26ft TVD Dir Rate @ 3 00o/t00ft : 500 00ft MD, 499 84ft ~VD Dir @ 2 00"/100ft in 9-7/8" He}e: 300 00ft MD, 300 00it TVD SHL: Y = 600841653 & X= 5293O684 (t422' FSL & 319' PC/L, SE(; 35,,513N*R9E) -T T T I F I F I T 1200 2400 3600 4800 Scale: I inch = 1200fl Eastings 6000 7200 8400 9600 Kuparuk River Unit 3K-20 (wp03) Measured SSTVD TVD Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northin;s Eastin;s Northin_~s Eastirms (fi) (D ,eg) (Deg) (ft) (fi) (fi) (fi) (ft) (fi) Dogleg Vertical Rate Section comment (°/t00ft) (ft) 0.00 0.00 0.00 -69,10 0.00 0.00 N 0.00 E 6008416.53 N 529306.84 E 0.00 0.00 300.00 0.00 0.00 230.90 300.00 O.00 N 0.00 E 6008416.53 N 529306.84 E 0.00 0.00 500,00 4.00 65.74 430.74 499.84 2.87 N 6.36 E 6008419.42 N 529313.19 E 2.00 6.98 700.00 10.00 65,74 629.15 69825 12.88 N 28.57 E 6008429.52 N 529335.36 E 3.00 31.34 1777.99 63.90 65.76 1459.23 1528.33 269,28 N 597.87 E 6008688.15 N 529903.65 E 5.00 655.71 2018.40 63.90 65.76 1565.00 1634.10 357.93 N 794,72 E 6008777.58 N 530100.t5 E 0.00 871.60 4611.92 63.90 65.76 2705.99 2775.09 1314.28 N 2918.36 E 6009742.27 N 532220.01 E 0.00 3200.65 6205.31 63.90 65.76 3406,99 3476,09 1901.84 N 4223,07 E 6010334,95 N 533522.40 E 0.00 4631.55 7262.26 63.90 65.76 3871.99 3941.O9 2291.59 N 5088.53 E 60t0728.10 N 534386.32 E 0.00 5580.72 7717.00 63.90 65.76 4072.05 4141.15 2459.27 N 5460.88 E 6010897.24 N 534758.01 E 0.00 5989.09 10666.68 63,90 65,76 5369.74 5438.84 3546,96 N 7876,15 E 6011994,41 N 537168.99 E 0,00 8637.98 11610.68 45.02 65.76 5915.99 5985°09 3860,95 N 8573.39 E 6012311.14 N 537864.99 E 2.00 9402.65 11811.75 41.00 65.76 6062.99 6132.09 3917.26 N 8698.41 E 6012367.94 N 537989,80 E 2.00 9539.78 SHL Begin Dir Increase DLS Increase DLS End Dh' Base Permafrost Ugnu Top West Sak Base West Sak 7-5/8" Csg Pt. Begin Dir C-70 Top HRZ I1917.41 38.89 65.76 6143.99 6213.09 3945.11 N 8760.26 E 6012396.03 N 538051.53 E 2.00 9607.60 Base HP, Z / Top Kalubik 12020.00 36.83 65.76 6224.99 6294.09 3970.97 N 8817.67 E 6012422.1t N 538108.84 E 2.00 9670.57 12164.76 33.94 65.76 6342.99 6417_09 4005.38 N 8894.09 E 6012456.83 N 538185.13 E 2.00 9754.38 12271.91 31.80 65.76 6432.99 6502.09 4029.26 N 8947.1t E 6012480.91 N 538238.05 E 2.00 9812.53 12319.91 30.84 65.76 6473.99 6543.09 4039.50 N 8969.86 E 6012491.24 N 538260.76 E 2.00 9837.47 12361.67 30.00 65.76 6510.00 6579.10 4048.18 N 8989.13 E 6012500.00 N 538280.00 E 2.00 9858.62 12393.98 30.00 65.76 6537.99 6607.09 4054.82 N 9003.87 E 6012506.69 N 538294.71 E 0.00 9874.78 12459.82 30.00 65.76 6595.00 6664.I0 4068.33 N 9033.88 E 6012520.33 N 538324.67 E 0.00 9907.69 12484.05 30.00 65.76 6615.99 6685.09 4073.31 N 9044.93 E 6012525.35 N 538335.70 E 0.00 9919.81 12659,82 30.00 65,76 6768.21 6837.31 4109.40 N 9125.06 E 6012561,75 N 538415,69 E 0.00 10007,69 K-1 / Lower Kalubik Top Kuparuk D Top C4 Top B Top A3 / Target Top A2 Top A1 Base Kuparuk Total Depth Sperry-Sun Anticollision Report GLOBAL SCAN APPLIED: All wellpaths within 200% 100/1000 of reference Interpolation Method: MD Interval: 100.00 [t Depth Range: 69.10 to 12660.58 ft Ma~imam Radius: 1459.15 ft Reference: Error Model: Senn Method: Error Surface: Plan: 3K-20 wp01 & NOT PLANNED PRONG ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Casing Points 7717.00 4140.89 7.625 9.875 7-5/8" 12660.50 6837.14 4.500 6.750 4~1/2" Plan: 3K-20 wp01 Date Composed: 5/3/2001 Version: 1 Principal: Yes Tied-to: From Well Re(. Point Summary <. Offset Wellpath ,> Reference Offset Ctr-Ctr No-Go Allo~able Site Well Wellpath MD MD Distance ~ea Deviation ft ft ft 'ft ft Warning Kuparuk 3K Pad 3K-01 3K-01 V0 500.18 500.00 14.19 6.85 7.34 Kuparuk 3K Pad 3K-02 3K-02 V0 399.81 400.00 12.40 5.32 7.08 Kuparuk 3K Pad 3K-03 3K-03 V0 399.42 400.00 37~05 5.18 31.89 Kuparuk 3K Pad 3K-04 3K-04 V0 399.04 400.00 60.32 5.50 54.83 Kuparuk 3K Pad 3K-05 3K-05 V0 300.00 300.00 88.50 3.99 84,51 Kuparuk 3K Pad 3K-06 3K-06 V0 496,59 500.00 113.50 6.47 107.05 Kuparuk 3K Pad 3K-07 3K-07 V0 398.13 400.00 137.17 5.06 132.11 Kuparuk 3K Pad 3K-08 3K.08 V0 397,60 400.00 163.50 5.40 158.11 Kuparuk 3K Pad 3K-09 3K-09 V0 397.35 400.00 187.93 5.38 182.55 Kuparuk 3K Pad 3K-09A 3K-09A V0 494.49 500.00 187.17 6.62 180.56 Kuparuk 3K Pad 3K-22 3K-22 V2 793,05 800,00 30,95 12.79 19.45 Kuparuk 3K Pad 3K.22A 3K-22A Vt 793,05 800,00 30.95 12,79 19,45 Kuparuk 3K Pad 3K-23 3K-23 V2 497,99 500.00 74.44 7.01 67.44 Kuparuk 3K Pad 3K-24 3K-24 V7 1282,05 1300.00 55.87 34.70 29.06 Kupamk 3K Pad 3K-25 3K.25 V1 495.82 500.00 127.84 6.89 t20.95 Kuparuk 3K Pad 3K-26 3K.26 V1 495.45 500.00 150.40 7.14 143.26 Kuparuk 3K Pad 3K-27 3K-27 V2 299.98 300.00 174.84 4.16 170.68 Kupamk 3K Pad 3K-30 3K-30 V1 586.89 600.00 277.76 8.72 269.06 Kuparuk 3K Pad Plan: 3K.19 Plan: 3K-19 V2 Plan: 500.68 500.00 26.73 7.34 19.39 Pass: Pass: Pass: Pass: Pass: Pass: Pass: Pass: Pass: Pass: Pass: Pass: Pass: Pass: Pass: Pass: Pass: Pass: Pass: Major Risk Major Risk Major Risk Major Risk Major Risk Major Risk Major Risk Major Risk Major Risk Major Risk Major Risk Major Risk Major Risk Major Risk Major Risk Major Risk Major Risk Major Risk Major Risk Site: Kuparuk 3K Pad Well: 3K-01 Rule Assigned: Major Risk Wellpath: 3K-01 V0 Inter-Site Error: 0,00 Reference Offset MD ' TVD MD TVD ft' ft ff ft semi-Major Axis' · . Ctr-Ctr No-Go Allowable Ref Offset TFO+AZI TFO-HS Casing . Distance Area Deviation ft ft dog deg · in ' 'ft · ft ft warning 69.10 69.10 69. t0 69.10 100.00 100.00 100,00 100.00 200.00 200.00 200.00 200.00 300.00 300.00 300.00 300.00 400,18 400.16 400.00 399.99 500.18 500.02 500.00 499.95 599.62 598.98 600.00 599.69 697.86 696.15 700.00 698.93 793.30 789.37 800.00 797.34 884.66 876.75 900.00 894.62 970.58 956.73 1000,00 990.42 1050.69 1029.01 1100.00 1084.51 1125.40 1094.08 1200.00 1176.86 1200,00 1156.54 1300.00 1267.32 1258.96 1203.94 1400.00 1355.71 1318.21 1249.71 1500.00 1441.88 1372.83 1290.12 1600.00 1525.66 0.00 0;00 357.13 357.13 12.23 0.73 11.50 0.02 0.02 357.41 357.41 12,26 1,13 11.13 0.13 0.11 359.19 359.19 12.58 2.67 9.91 0.24 0,16 1.40 1.40 12.91 4.06 8.84 0,33 0.20 357.20 291.46 12,78 5.41 7.37 0.41 0.30 339.70 273.96 14.19 6.85 7.34 0.54 0.42 319.99 254.25 21.41 8.46 12.96 0.73 0.60 309.06 243.32 35.86 10.29 25.60 1.00 0.83 302.93 237,19 58,04 12.39 45,72 1,37 1.12 298.41 232.67 89.46 14.75 74.87 1.81 1.46 295.37 229,63 t30.29 17.31 113,28 2.32 1.84 293.60 227.86 178.93 20.03 159.38 2,85 2,24 292,64 226.90 233.38 22.86 211.21 3.45 2.66 292.17 226.43 292.94 25.80 267.99 3,99 3.11 292.01 226.27 357.04 28.66 329.49 4.56 3.56 292.09 226.35 425.16 31.64 394.91 5.13 4.02 292.35 226.61 496.79 34.46 463.85 Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass RAM ORIGINAL ~367 %. --350 - % --250 100 -"50 --0 2' ANTI-COLlISION SEIWINC,-S Depth Range~ From: 69. t0 To: 12660.58 Maximum Ran~: 1459.15 R~ference: Plan: 3 K-20 wp0 1 From Colour To MD 69 500 5OO 1000 1000 1500 1500 2000 2000 =~ 3000 3000 ~ 4000 6OOO 7OOO 7000 8000 8OOO 9OOO lO000 11000 t1000 ~ 12000 SURVEY PROCrI~M Dep~Fm DegthTo Sm'~5.'txlm 69.1012¢~:0.58 Pl~amed: ~-20 wp01 Vt MWD WELL DET^IL8 ~ tNt-~~F~-WNo~hing F.~.ng 3K-~O -IZ21 0.61 6~8416-~3 529306.g4 Plan: 3K-19 (Plan: 3K-19) 0 3K~I(3K~I) ~0 From Colour To MD 69 ' 500 500 1000 1000 ....... 1500 1500 2000 2000 .......... 3000 3000 ~ 4000 4000 5000 5000 6000 6000 7000 7000 8000 8000 ' ' ' 9000 9000 10000 10000 ! ! 000 I 1000 12000 13000 21 ;0 180 3K-27 0K-2''/) 3K-30 K-OI), Major Risk . ' -K.4ll).~jorRisk 4c.06), Major Risk /vlajor Risk Risk -K-23), Major Ri~k P~n: 3K-20 wp01 (3~.20/Plan 3K-20) Cmsau~d By: Davo Eg~dabt Da~-: Chcckcd: Al~ro~d: V :. -'%;' Travelling Cylinder Afirm~th (TFO+AZI) [deg] vs Centre to Cenlre Separation [150flYin] Travelling Cylinder Azimm. h (TFO+AZI) [deg] vs Centxe to Centre Separation [2Oft/in] 69.100.000.00 69.10 0.00 0.00 3~0.00 0.0~0.00 3~0.000.~0 0.O0 500.00 4.0{) 65.74499.842.g7 6.36 700.{;0 I0.00 65.7469fl.2~ 12.88 2~.57 177g.05 63.90 6~.761528.%1.69.2~ 597.92 1066/.42:63.99 65.76543g."~ 3547.31 7 ~'/6.93 1 z362.54 30.0D 65.766579.10 4O4838 t 2~0.58 30.00 65.766~37.21 4109.~/ 9125.90 SECTION DETAILS Sc~ MD I'rg~ TVD ~ N/-S I Et-W DLe8T F~ eVSoc 0.000~0 0.00 o~o o~oo o.oo ~ 65.'/4 6.9~ 3.000.00 31.34 5.000.00 655.76 0.000.00 2.00 I~0.00 9'&S9.59 TI (3K-20) 0.00 0.O) 0,00 0.00 10t)~.6! , , , TARGET DETAILS Name TVD +N/-S +E/-W Shape TI (3K-20) Caz 6579.10 4048.58 8990.03 Rectangle (150x300) T1 (3K-20) 6579.10 4048,58 8990.03 Rectangle (150×300) "llll ti I iT. i I I ~ . , I ! Il 11 i il i i ' Ill .... I SURVEY PROGRAM /~M Azimuths ~ True No!th Magae~eNorth:26.1s° Date: 5/3/200l Yalidated: No ¥¢rsion: ? Magnetl~ Field 81~ngth: 57431nT Depth Fm Depth To Survey/Plan Tool .~ Dip Angle: 80,75' Dala: 5/'a/2001 Model: BGGM2000 69. ! 0 t2660,58 Planned: 3K-20 wp0! Vi ~+IFR-AK-CAZ-SC i~i i , .......... L.., , , ' ': :::::::::::::::::::::::::: ...... ~ ................ : -M':' :' :: :~' ~-'" ,",,-:"~:--:, :::: ::.- '::::.:-: t~:.,'~"U? ',"-",:'" ~" ': ~::~::9:'.:A::'"' : ::::h2~ L' :': '~',_,,~,?"~Z~:~_" _'~'~" ~ietd: K. uparuk River Ual' Site: Kuparuk 3K ?ad wen: 3~-~0 Outer 90% target (thc bigger target) is bas~ on MWD4-IIFR4CAZ while using SCC ~llpath: Plan 3K-20 The inner (smaller) target is ONLY MWD+IIFR (with SCC) , , .,. ~ , , ; ~ ,, ............... ~ ........... ~ ............ ~: i ............ ~ .............. ! ........... ~~,__! .......... ~ .............................. ~ .,iX ............ i ....................... ~ ............ ! ............. , ............. ............ ~ ......... ~ .............. ! ........ i .............. ....... ....... ": ............ I ............. 4 ............. t ............... i ............. I' ........... I, .............. i"-'/ ................. :i .......................... :~ ............. ~ .............. 1 ........................ ~ ............. ! .............. ~ ............... k..: .............. : ........... i .............. i ........... ' ............. ; ............... i ............. ! ............. ~ .......................... !, ............ ~ .......... ~ ............ i .......... ....... i 4.--~-...~ .......... ._z~___z,_..~_4__~_!_.! i -..X.-~-4._.~._,_~_.;_.2__4...-'~ .... i--~-Z--i- ..... .. i : ... ~..L..... ..', ........ t ............ ~ , . .... i ......... 1 ...... . ix,.,', i ~ i { i . .............. , ~ /~ ........ !: ......... .................. .......... ~ .................................................... ,I ............. .............. ~ ................................................................................ ..... :I~-X" ' ..... ..................................... J: .................................. ~ i ' i ' ........................... ~ .~ ~ , ~c~'f2"~... ~ rI · ......................... ~ , . ............. ................ ........................... ~ , , ,, ~. , t , 'i ' ' ; : ' ' · ' I ' ' ~ ..... ~' ' ~ ''~" ~ ~' :i,i,' 'ii"~~' ¢ :!,..,>~-.,..i ':~ i i ' '~ .... ~ ............................ I ............. :~ ............. ! ............ 4~! ....... X ......................... i-..-,~ ..... ~--,~.,..,.,,t.,~~: ............. ~~-! ............... i ........... i ...................... i ..... ~ ......... ~, .................. , ........... ? ........ 1 .......................... ~ ................ ,' ...................................................................................... ~ ................. : .............. ( ............ '. ............. ~ ............. ~ ................ ~ ............................ :~ ~ ,,,~ .,,~...,:~ ~ ~; ...... ,,~ ............. ............. ,, ............. ..... ............... , ............................... , ........ ~ .... ~ ,' '~,~~ .............. ',,~,~i~~' x::',~:,':.:,~ !:.:!':;i~:::.:~~ , . ., ,, :.~ ,, ~X: , : ...... ...............~ ". ............................................................. ........... ! ........... ; ............................................... i! ........... ~ .............................. ~ ............ i .................................. i ! ............. ............. ~.~ .................. m~X ................... iX,,..,! ,:. ,, ~ .... i./- ? i ......... ~ ......... ~ ........... X.,,.i ......... I !~'-! " : ~ ~ :~ i ~i: \7:'i:-N.I ,'7:,~7-~i .................. : ........... ........... ~' .......... ': ............... i ......... ~' .... 7XL'"""~ ....................... ! ...... ............ , ......................... _ . _ . .................................. ~ ~ ' :~ :~ ' ': ..... ~i'" .................... ; ............. ! ;' : .......... .......... ........... ~~ : ........... ........................ !:' .... ~ , '~ .................... ~ ................................................... i ........................ ................. , ....... ~", ~'-~'.'.\ ................. ! ~ .......... ,, ........................................ ; ........ i ........................ i...--..~. ........... i .............. i ............ ;~ ............... i ............ ~ ................. ' I ~ ~ ,~ i : / ~. , . , ...... ~.~ ............ ':.......X. Tt. I ,~ ,~" ! ! '' ." t ; ~ ~"'i-: ; '!",'-',-~': I 8850 8900 8950 9000 9050 ~ Plan 3K-20 UHIUI II/-IL TARGET DETAil S Name TVD +N/-S +E/-W Shape Ti (3K-20) Caz6579.104048.588990.03Rectangle ( [ 50x300} Ti (3K-20l 6579,104048.588990.03Rectangle (I50x300) T Field: Kuparuk River Uni Site: Kuparak 3KPad ~ Well: 3K-20 :llpa~h: Plan 3K-20 Depth Fm Depth To Smwey/Plan 69.10 12660.58 Planned: 3K-20 wp0t Vi SURVEY PROGRAM Date: 5/3/20(1l Validated: No Version: 7 Tool MWD ~iFR-AK-CAZ-SC LEGEND 3K~01 (3K-01)~ Major Risk 3K-02 (3K-02L Major Risk 3K~03 (3K-03L Major Risk 3K-04 ~3K~04L M~tor Risk 3K~..05 f3K-05L M~ior Risk 3K-()6 (3K-06k Major Risk 3K~07 (3K-07L Vf~ior Risk 3K-08 {3K-08t. Vlfkior Risk 3K~09 (3K~09), Major Risk 3K~09A f3K~09AL Major Risk '~K-22 (3K-22L Major Risk 3K.-23 ~3K-23t. V/~'or Risk 3K~24 (3K~24,. Major Risk 3K-25 (3K-25L Major Risk 3K-26 (3K-26)~ Major R~sk Plan 3K-20 Red line is ~iheoreticM Magnetic interfera~ce distance 500 1000 1500 2000 2500 3000 3500 Measm'ed Depth [500f~'in] 3K-20 Drillin Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 9-7/8" Hole / 7-5/8" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Careful well planning and surveying, adherence to anti-collision policy Gravel and sand Low Elevated mud viscosity from spud; Hi dens sloughing sweeps; contingent 13-3/8" casing string. Shaker/Trough Ball Mill Low Controlled ROP Overflow Shoe Fracture/Lost Moderate Reduced pump rates, and lightweight tail Returns during cement cement job 6-3/4" Hole / 5-1/2 & 4-1/2" Casinq Interval Event I Risk Level Mitigation Strategy Shale stability in HRZ Moderate Control with higher MW and proper drilling practices. Hole cleaning in long, Moderate Good drilling practices. high angle tangent High ECD and High Pumping and rotating out on all trips to swabbing if higher MW reduce swab and barite sag potential. is required Shale stability across K- High Control with higher MW and proper drilling 1 interval practices. 3K-20 Drilling Hazards Summary. doc prepared by Todd Mushovic 5/9/01 ORIGINAL Page I of I Schlumberger Rig: Nabors 16E Location: Kuparuk (EBA) Client: Phillips Alaska, Inc. Revision Date: 5/8/01 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@slb.com < TOCat Surface Previous Osg. < 16", 62.6# casing at 120' < Base of Permafrost at 2,018' IVD(1,634' TVD) < Top of Tail at 5,405' IVD < Top of West Sak at 6,205' IVD < 7 5/8", 29.7# casing in 9 7/8" OH 'rDat 7,717' IVD (4,141' TVD) Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems (Volumes are based on 250% excess in the permafrost and 45% excess below the permafrost. Top of tail slurry is designed to be 800' above West Sak formation. Lead Slurry (Minimum thickening time: 250 min.) ASLite @ 10.7 PP~I, Class G + 50%D124, 9%D44, 0.4%D46, 30%D53, 1.5%S1, 1.5%D79 - 4.44 ft°/sk 0.9513 ft3/ft x (120') x 1.00 (no excess) = 0.2148 ft3/ft x (2018'- 120') x 3.50 (250% excess) = 0.2148 ft3/ft x (5405' - 2018') x 1.45 (45% excess) = 114.2 ft3 + 1426.9 ftc+ 1054.9 ft~ = 2596 fts/4.44 ft3/sk - Round up to 590 sks 114.2 ft3 1426.9 ft3 1054.9 fta 2596 ft3 584.7 sks Have 170 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry (Minimum thickening, time: 180 min.) LiteCRETE @ 12.0 ppg - 2.40 ft°/sk 0.2148 ft3/ft x (7717'- 5405') x 1.45 (45% excess) = 0.2578 ft3/ft x 80' (Shoe Joint) = 720.1 ft3 + 20.6 ft~ = 740.7 ft3/2.40 ft3/sk = Round up to 310 sks 720.1 ft3 20.6 fta 740.7 ft3 308.6 sks BHST = 92°F, Estimated BHCT = 86°F. (BHST calculated using a gradient of 2.4°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate Volume Stage Stage Time Cumulative Time (bpm) (bbl!. . (min) (minI. . CW100 6 40 6.7 6.7 Drop Bottom Plug 3.0 9.7 MudPUSH XL 6 50 8.3 18.0 Lead Slurry 6 467 77.8 95.8 Tail Slurry 6 133 22.2 118.0 Drop Top Plug 3.0 121.0 Displacement 6 331 55.2 176.2 Bump Plug 3 20 6.7 182.9 MUD REMOVAL Recommended Mud Properties: 9.8 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* XL, Pv = 17-20, Ty = 20-25 Centralizers: Recommend 1 per joint from 5205' MD to TD for proper cement placement. 'Mark of SchIumberEer Uii'iUit'V'AL Schlumberger Rig: Nabors 16E Location: Kuparuk (EBA) Client: Phillips Alaska, Inc. Revision Date: 5/8/01 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@slb.com < Base of Permafrost at 2,m~' k4..) (1,634.' IVL)) Previous Csg. < 7 5/8", 29.7# casing at 7,717' < 5 1/2", 15.5# casing in 6 3/4" C)H < TOC at 11,365' rVD < Top of Kuparuk D at 12,165' IVE) < X-over at 12,200' < Top of A3/Target at 12,362' IVD < 4 1/2", 12.6# casing in 6 3/4" OH TD at 12,660' rvD (6,837' TVD) Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems (Volumes are based on 75% excess. Top of tail slurry is designed to be 800' above the top of Kuparuk D formation. Tail Slurry (minimum thickening time 150 min.) GasBLOK w/Class G + 3% D53, 2 gps D600, 0.15 gps D135, 0.12% D800, 0.2% D047, 0.6% D065, per lab testing @ 15.8 ppg, 1.2 ft3/sk 0.0835 ft3/ft x 835' x 1.75 (75% excess) = 0.1817 ft3/ft x (12660'- 12200') x 1.75 (75% excess) = 0.0854 ft3/ft x 80' (Shoe Joint) = 73.1 ft3 + 146.3 ft3 + 6.8 ft3 = 226.2 ft3/1.2 ft3/sk: Round up to 190 sks 73.1 ft3 146.3 ft3 6.8 ft3 226.2 ft3 188.5 sks BHST = 157°F, Estimated BHCT = 133°F. (BHST calculated using a gradient of 2.4°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate Stage Cumulative Volume Stage Time Time (bpm) (bbl), (min) (min), CWl00 6 40 6.7 6.7 Drop Bottom Plu[ 3.0 9.7 MudPUSH XL 6 50 8.3 18.0 Tail Slurry 6 41 6.8 24.8 Drop Top Plug 3.0 27.8 Displacement 6 276 46.0 73.8 Bump Plug 3 20 6.7 80.5 MUD REMOVAL Recommended Mud Properties: 10.4 ppg, Pv < 15, my < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* XL, Pv = 19-22, Ty = 22-29 Centralizers: Recommend 1 per joint from 11165' MD to TD for proper cement placement. 'Mark of Schtumber§er ORIGINAL 3K-20 Producer ( Proposed Completion Schematic Slimhole Base Case - 3-1/2" Completion String PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 16" 62.6# @ +/- 160' MD Depths are based on Nabors 16E RKB Surface csg. 7-5/8" 29.7# L-80 BTCM 7717' MD / 4141' TVD Intermediate csg. 5-1/2" 15.5# L-80 BTCM 12,200' MD / 6444' TVD Future Perforations Production csg 4-1/2" 12.6# L-80 IBT 12,660' MD / 6837' TVD 3-1/2" FMC Gen 5 Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Camco 'DS' nipple w/2.875" No-Go Profile. 3-1/2" x 6' L-80 handling pups installed above and below, EUE8RD set at +/- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple 3-1/2" x 1" Camco 'KBG-2-9' Mandrels w/DV's and RK latch's (Max. OD 4.725", ID 2.90"), IBT box x box, 3-1/2" x 6'L-80 EUE8RD box x IBT pin handling pup installed above, 3-1/2" x 6' L-80 IBT pin x EUE8RD pin handling pup installed below. Spaced out w/3-1/2" 9.3# L-80 EUE8RD tubing as follows: GLM # TVD-RKB MD-RKB GLM Numbers and Spacing To Be Determined 3-1/2" x 1" Camco 'KBG-2-9' mandrel w/DCK-3 shear valve and latch (Max. OD 4.725", ID 2.90"), IBT box x box, pinned for 3000 psi shear (casing to tubing differential), 3-1/2" x 6' L-80 EUE8RD box x IBT pin handling pup installed above, 3-1/2" x 6' L-80 IBT pin x EUESRD pin handling pup installed below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Camco 'D' nipple w/2.75" No-Go profile. 3-1/2" x 12' L-80 EUE8RD spaceout pup installed above, 3-1/2" x 6' L-80 EUE8RD handling pup installed below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 80-40 GBH-22 casing seal assembly w/15' stroke, 3-1/2" L-80 EUESRD box up, 3-1/2" x 6' L-80 EUE8RD handling pup installed on top Baker Casing Seal Receptacle, 80-40, 5-1/2"BTCM x 4-1/2" Buttress Baker 5" OD x 4" ID 17' Seal Bore Extension CSR set at +/- 100' above top perforation ORIGINAL TJM, 5/9/01 PHILLIP Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 May 9, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: KRU 3K-20 Surface Location: Target Location: Bottom Hole Location: 1422' FSL, 319' FWL, Sec. 35, T13N, R9E 185' FSL, 1246' FEL, Sec. 25, T13N, R9E 246' FSL, 1109' FEL, Sec. 25, T13N, R9E Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 3K-20. The well will be drilled and completed using Nabors 16E. Please utilize documents on file for this rig. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 3K, or hauled to an approved Prudhoe or GKA Class II disposal well. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report Sharon AIIsup-Drake, Drilling Technologist (20 AAC 25.070) 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Mark Longden, Geologist 263-4506 If you have any questions or require further information, please contact Todd Mushovic at (907) 265-6974 or James Trantham at (907) 265-6434. Sincerely, James Trantham Drilling Engineering Supervisor RECEIVED rvlAY 1.0 Z001 Alaska Oil & Gas Cons. Commission Anchorage ORIOlN AL Annular log AAI IKRU 12N-329 ISUN 198-067 15/6/98 i5/14/98 i !Y iY IN i 7/27/991 1091from AAI report submitted 2/26/99 AAI IKRU 12N-331 iSUN 198-117 9/11/98 19/25/98 i , IY JN JN I contingent on 10-403, inwellfile PAl IKRU 12N-332 ISUN i200-079 7/17/00 17/21/00 ] I I i I ! I 10-407(#300-187)submtted7/17/2000w/LOT&cmt~g_~n_fo ....... AAI IKRU 12N-335 ISUN !98-204 110/19/98 111/25/98 ! I IY iN i I 10/5/99 254951fromPPCO10/13/2000quartedyreport AAI IKRU 12N-337A ]SUN i98-122 16119/98 {7/17/98 ! I IY IY !Y i 306391fromAAIreportsubmitted 2/26/99 ISUN i98-100 !5/30/98 I I[ IY iN IN i i ]contingent on 10-403, not in well file as of 9/20/00 ........ AAI IKRU 2N-339 AAI iKRU 2N-341liSUN ~98-103 17/6/98 17/17/98 ! IY I ! i I 34150Jfm: PPCO 10/13/2000 quarterly report, ddlling notes indicate 2N-341 in commun~ca~io-n wit~ 2-NL3~ KRU i I I i , Y I I i ! ]letter approval into 2N-328, 2N-329, 2N-343, Injected volume w/compl, rpt AAI 2N-343 iSUN i98-092 !5/18/98 15/14/98 i ! iY IY I 7/27/99! 3180810sg crnt. AAI [KRU 2N-345 ISUN 198-113 17/18/98 18123/98 I I IY N iN i I Icontingent on10-403, inwellfile, broachedcenductorwhileddllin~2N-343 _. -" iCRU~ 2N-347 ~!SUN!200-063 I 6/16/00 7/21/00 il~1 I Ii' !'~ I] 31640 50 nd bbls cate cmt 2N-341 to surface, n cemmun no broaching; cation withV°lume 2N-347 from PPCO 10113/2000 quarterly r~port~ ~dll~g note~s PAl PAl KRU 2N-349 SUN !200-111 I srr I i I I ! i lw/request annularat laterdate, srr as 349A, no 10~-0~-w~ll f~le'a~ of 9/20/~0 PAl CRU i2N-349A SUN i200-139I I I i I i i I I LOT @ shoe to 11.86, 2nd LOT for annular to 10.72, Sundry_ap~oroval-~3~0---2~8 ...... _~_ ~ -- ~_ _ PAl I KRU 2P-417 SUN 201-069 I I ! I I I I i I Iw/request approval after well ddlled. PAl 'KRU 2P-438 SUN 201-082 I i i t I ! i I I !w/request approval after well ddlled. -' AAI KRU 2T-21 PTD 195-013 16/4/95 IN/A I I iN iY i i 5/1/951 913691 from AAi report submitted 2/26/99 AAI KRU 2T-32 PTD 195-049 110/20/95 N/A i i I N [Y i 8/1/95 111000Jfrom AAI report submitted 2/26/99 AAI IKRU 2T-36 PTD 195-102 !10/20/95 N/A I i iN !N , i 01Neverutilized AAI tKRU 2T-37 PTD 195-101 9/26/95 ]N/A i I IN IN J i I 01 Never utilized i95-112 9/27/95 I I iN iN ] ] I 0iNever utilized AAI t KRU 2T-38 t PTD NIA AAI iKRU 2V-17 IPTD i97-008 i N/A i { ~ IN IN I 1/17/96 01 c°ntingent °n data submissi°n; cancelled permit AAI IKRU 2X-17 iPTD 195-171 14/16/96 N/A I J iY IN ! 495]from AAI report submitted 2/26/99 AAI IKRU 2X-18 IPTD 195-160 15/9/96 IN/A I I tN IY IN i 1/17/961 25079]fromAAIreport submitted2/26/99 AAI KRU t2X-19 IPTD 195-175 13/22/96 N/A i I IN iN i i { 0UeverutJlized AAI IKRU 12Z-22 IPTD 194-147 14/3/95 N/A ! [ ~.iY. J I 2/1/951 10807,from AAI report submitted 2/26/99 AAI iKRU 13A-17 ISUN 196-132 110/29/96 8/30/96 I I iY ]y i 12/16/96i 133201contingent on 10-403, data in ~11 file; fromAAI report submitted 2/26/99 AAI IKRU 13A-18 PTD 196-133 '10/31/96 N/A i I IY IN iN i 0iconUngentonl0-403, top job to 550' - AAi IKRU 13F-19 SUN f96-102 8/7/96 16/25/96 I I IY !Y !Y { 10/29/96J 15394icontingenton10-403, datainv, ell file; from AAI report submilted 2/26/99 AAI iKRU 13F-20 SUN i 199-079I f i I I i { i I PAl IKRU 13F-21 SUN ]200-203 i t I ] I ! i i I Iwill request at completion of ddlling operations ....... AAI JKRU 3G-03 ~SUN J96-122 J8/29/96 j815196 i J IY JY iY j 11/8/98J 6473jcontingent on 10-403, data in ~ell file; from MI report submitted-2/-2~)/9~ ....... jAAI JKRU 3G-25 PTD J96-118 J8/8/98 N/A ! J IN N I i I 0Jcontingent on l0-403 w/CQL or LOT; took kick, sus_pendedwell. ~ - - !AAI IKRU 3G-26 {SUN ]99-075 I 8/19/99 , i I N ' ; i I I iY !Y i 10/28/96 i 27117 !fi'orn AAI report sabmitted 2/26/99; also 30201 bbls into 2M-33 & 15428 bbls into 3M-27 IA-Al KRU 3H-24 PTD 196-015 5/9/96 IN/A IAAI KRU 3H-28 PTD i96-018 2/15/96 N/A ] IN iN i i ] 0!p&a & s/t as 3H-28A iAAI KRU 3H-28A PTD ] 96-03715/8/96 N/A ] ] IN iN ] ! ] 0iNever uUlized ..... ~A/~I KRU 3J-17 PTD 196-146112/21/96 iN/A I ] yY iN ! I I 0 !contingent on 10-403, did remedial cmt job, 43/4" wastes to 1C-11 KRU 3J-18 ]PTD !96-147 }12/14/98 IN/A I J IN i i I 0!contingentonl0-403w/CQLorLOT KRU 3J-19 ISUN [96-148 i 11/2/96 110/3/96 I ] [Y iY iY [ 1/14/971 21235 i from AAI report submitted 2/26/99 -- AAIPAI KRUKRu ~'~ IPTDISUN i97-0971201-0887/15/97 IN/Al I] J] IYI IN1 iN! ]i II 01 Never utilizedlplan to eventually request approval for annular disposal - info not submitted w/j3td__apj~licafi0n- .- AAI IKRU ISUN 198-24911/30/99 I ! ! i i I ! Iiic°ntingent°n AAI IKRU SUN 198-081 15/25/98 i I I IN iN iN I 10-403, not in well file AAI KRU ~ PTD i97-077 17/22/97 !N/A j J JY IY !Y i 4/9/99J 34070Jfrom AAI report submitted 2/26/99, 4/9/99 '- ' AAI KRU ~ PTD j97-046 J5/8/97 ! N/A J J J Y J Y i Y J 7/18/97 J 37273 J contJngent on data submittal, contacted AOGCC w' exceeded; from repor~ submitted 2/26199 AAI JKRU I~ JSUN !97-113 j7/27/97 I J J IY JN jN i J 0JNeverutilized -- AAI KRU ~ ISUN 198-082 i6/8/98 I I J IY IN IN ~ I jcontingenton 10-403, not in well file AAI IKRU ~ jPTD j97-076 15/29197 JN/A ! j !Y JY jY ! 8/7/97! 334801confingent on data submittal - in v, ell file; from MI repod submitted 2/26/99 ...... AAI IKru~ iSUN 198-077 16/17/98 i l i IY IN IN i I i contingent on data submittal - in well flle ..... _ _ AAI IKRU ~ JPTD J97-109 J7/21/97 IN/A ! J IY jN IN i J 0jNeverutilized AAI IKRU 3M-27 JPTD j95-214 J5/12/96 IN/A i J IN iY IY i 10/29/98j 154281from AAl report submitted 2/26/99 AAI KRU 3M-29 IPTD i96-005 15/3/96 IN/A i ! !N iN i i i 0INeverutilized --- - AAI IKRU 30-20 JPTD j 97-045 j4/12/97 IN/A I J iY JY iY i 6/23/971 11905Jconfingent on data submittal - in well file; from AAI report submi.ed 2/26)99-- AAi IKRU 3Q-22 JPTD 195-186 J 2/8/96 JN/A j j IN IY !N i 1/23/97 j 6345ifromAAIrepodssubmitted2126199,419199 ' - AAI jKRU 3R-26 IPTD !95-187 J 2/4/96 IN/A i J Ju iN I i j 0iNever utilized PAl JEXPL Atlas #1 ISUN !201-004 J J i J J J j i t j requested w/ptd BPX IPBU B-33 jPTD 193-018 J11/5/93 IN/A J j JN IY J I 12/14/98j 3974jFrom BPXAAnnular Injection Data Entry Screen; from B-36 BPX PBU lB-36 IPTD !96-065 J6/4/96 iN/A i j jN jN i i I 0]Neverutilized AAI EXPL Bufflehead 1 IPTD 195-063 j12/16/95 J12/12/95 j J jN !Y !Y i 9/5/96! 11148jAnnularinjection summerof 1996, Approval by BEW ' AAI CRU CD1-01 JSUN !99-046 j6/28199 j3/12/99 i j iN iN iN iY i 5221ifrom AA110/13/2000 report; auth. expired _ - - ' AAI JCRU JCD1-02 ISUN i200-172 J J i J J i i i J J AAI JCRU lCD1-03 JSUN j199-120 j J1/13/00 i J J JY i ! 4/24/011 339901from PPCO 4/24/2001 quarterly report, source wells: CD1-43,~cD1_~1,~CD1-30_. . PAl ICRU JCD1-04 JSUN i200-117 J j J J i i j I I Page 3 American Express® Cash Adv~nce Draft 132 ' ISSued by Intqr~ed P~yment System, In~ En~lewood, Color~lo ~,~ '~ ~0~,~ B~ ~ G~.~ J,~on - Do~w,. ~ G~d Jun~n, ~o ~:. ~O ~.&OO~OO~: 5 5 WELL PERMIT CHECKLIST FIELD & POOL COMPANY .... 'NiT L SS' ADMINISTRATION ,~R DATE ~ .~/f?/~! WELL NAME .,?,~'-'.Z. 43 PROGRAM: exp ENGINEERING 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in ddlling unit ............ 8. If deviated, is wellbore plat included ............. ... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit canbe issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... /'-',~,;/ GEOL AREA N 14. Conductor string provided ................... 15. Surface casing protects all known USDWs. ' ,, dev v~ redrll serv wellbore seg ann. disposal para req UNIT# /'2/_~",,O ON/OFF SHORE GEOLOGY 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to.tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons ..... ' ..... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ....... ~ ..... 23. If diverter required, does it meet regulations ........... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ....... _...~.... ~ . . 26. BOPE press rating appropriate; test to ~.~ Dsig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for diSposal; Y'. N (D) Will not damage producing formation or impair recovery from a Y N pool; and 30. Permit can be issued wlo hydrogen sulfide measures ...... Y N ,,/ 31. Data presented on potential overpressure zones ....... Y 32. Seismic analysis of shallow gas zones... .......... Y//N ~'(-../~/'~. 33. Seabed condition survey (if off-shore) ............. /'Y N ' ' ' 34. Contact name/phone for weekly progress reports [exploratory one] Y N (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N , ,, 'GEOLOGY: ENGINEERING: UlClAnnular COMMISSION: Comments/Instructions: O Z O c:Vnsoffice\wordian~diana\checklist (rev. 11101//00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this. . nature is accumulated at the end of the file under APPE .N. DIXi .. No 'special'effort has been made to chronologically organize this category of information. · .. · ., Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Dec 20 lC):~6:43 2001 Reel Header Service name ............. LISTPE Date ..................... 01/12/20 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Colmments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/12/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL, NAME: API NUMBER: OPERATOR: :LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-10173 P. SMITH R. ROSS 3K-20 500292301900 PHILLIPS Alaska, Inc. Sperry Sun 19-DEC-01 MWD RUN 2 MWD RUN 3 AK-MM-10173 AK-MM-10173 T. MCGUIRE T. MCGUIRE M. THORTON M.THORTON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FY' FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LE'VEL: WELL CASING RECORD MWD RUN 99 AK-MM- 10173 35 13N 9E 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1422 3].9 .00 68.60 34.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 16.000 120.0 6.750 7.625 7706.0 RECE 'VED 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. MWD RUNS 1-3 ARE DIRECTIONAL, WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. MWD DATA ARE CONSIDERED PDC PER THE E-MAIL MESSAGE FROM D. SCHWARTZ OF PHILLIPS ALASKA, INC. TO R KALISH OF SPERRY-SUN DRILLING SERVICES DATED 10/29/01. PDC AUTHORIZED BY: M. LONGDEN OF PAI TIE-IN LOG AND WELL NAME: N/A 4. VERTICAL RESISTIVITY INVERSION (VRI) DATA IS PRESENTED AS A DEEP PHASE ENHANCED {RDVR) CURVE IN MWD MERGED DATA, AND AS 4 ENHANCED CURVES AND 4 MODELED CURVES IN THE FINAL RAW MWD FILE (MWD 099). .5. MWD RUNS 1-3 REPRESENT WELL 3N-20 WITH API#: 50-029-23019-00. THIS WELL REACHED A TOTAL, DEPTH (TO) OF 12706'MD, 6882'TVD. SROP = SGRC = SEXP = SMOOTHED tLRTE Of;' PENETRATION WHII..,E DRILLING. SMOOTHED GAMMA ]RAY COMBINED. SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVE[I RESISTIVIT (SHALLOW S PACING ) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SEDP = SFXE = RDVR = MEXP = SPACING). SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY DEEP SPACING). SMOOTHED FORMATION EXPOSURE TIME. INVERSION-DERIVED DEEP PHASE RESISTIVITY ( ENHANCED). FORWARD-MODELED EXTRA SHALLOW PHASE RESISTIVITY. MESP = FORWARD-MODELED SHALLOW PHASE RESISTIVITY. MEMP = FORWARD-MODELED MEDIUM PHASE RESISTIVITY. MEDP = FORWARD-MODELED DEEP PHASE RESISTIVITY. VEXP = INVERSION-DERIVED EXTRA SHALLOW PHASE RESISTIVITY (ENHANCED). VESP = INVERSION-DERIVED SHALLOW PHASE RESISTIVITY (ENHANCED). VEMP = INVERSION-DERIVED MEDIUM PHASE RESISTIVITY (ENHANCED). VEDP = INVERSION-DERIVED DEEP PHASE RESISTIVITY (ENHANCED). $ File Header Service name ............. STSLIB.001 Service Sub Level,. Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FiLE HEADER FILE NUMBER: 1 EDITED MERGED PFWD Depth shifted and clipped curves; all. bit runs merged. DEPTH INCREMENT: .5000 FI LE SUMMARY PBU TOOL CODE START DEPTH FET 539.0 RPD 539.0 RPM 539.0 RPS 539.0 RPX 539.0 GR 547.0 ROP 583.5 RDVR 6098.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE, PBU TOOI.., CODE MWD MWD MWD MWD $ REMARKS: STOP DEPTH 12670 0 12670 0 12670 0 12670 0 12670 0 12663 0 12706.0 7302.0 EQUIVALENT UNSHIPPED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 539.0 5979.0 2 5979.0 7717.0 3 7717.0 12706.0 99 6098.0 7302.0 MERGED PLAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Legging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 . liN Max frames per record ............. [,Jnde'fined Absent value ...................... -999 Depth Units ....................... Datum Specificat. ion Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AP1 4 i 68 RPX HWD OHMH 4 1 68 RPS MWD OHMM 4 I 68 RPM MWD OHMM 4 i 68 RPD MWD OHP~ 4 1 68 RDVR MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 Name Service Unit Min Max DEPT FT 539 12706 ROP MWD FT/H -1.54 549.58 GR MWD AP1 12.55 529.1.6 RPX MWD OHMH 0.53 372.12 RPS MWD OHMH 0.74 2000 RPM MWD OHN~4 0.61 2000 RPD MWD OHMM 0.55 2000 RDVR MWD OHMM 0.707 70.655 PET MWD }{()UR 0. 1314 92. 8338 First Mean Nsam Reading 6622.5 24335 539 158.357 24246 583.5 89.3486 24233 547 15.3871 24218 539 24.5848 24218 539 36.927 24218 539 47.486 24218 539 7.98415 2409 6098 0.74675 24218 539 Last Reading 12706 12706 12663 12670 12670 12670 12670 7302 12670 First Reading For Entire File .......... 539 Last Reading For Entire File ........... 12706 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.O02 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 539.0 5935.0 RPS 539.0 5935.0 RPM 539.0 5935.0 RPD 539.0 5935.0 FET 539.0 5935.0 GR 547.0 5943.0 ROP 583.5 5978.5 $ LOG HEADER DATA DATE LOGGED: 31-MAY-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE 'VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 5979.7 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 8.0 MAXIMUM ANGLE: 66.4 TOOL STRING (TOP TO BOTT(~) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01912HWRG6 EWR4 ELECTROMAG. RESIS. 4 PB01912HWRG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 120.0 BOREHOLE CONDITIONS MUD TYPE: Spud Mud MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S): 78.0 MUD PH: 9.0 MUD CHLORIDES (PPM): ,450 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE {DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT PIT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Tpe .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT FT 4 1 68 ROP MWD010 FT/H 4 1 68 GR MWD010 API 4 1 68 RPX MWDOiO OH'MM 4 1 68 RpS MWD010 OHMM 4 1 68 RPM MWD010 OHMM 4 i 68 RPD MWD010 OHMM 4 1 68 FET MWD010 HOUR 4 1 68 6.2 5.000) 3.548 10.000 4.000 Units Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 ].6 5 20 6 24 7 28 8 68.0 98.6 68.0 68.0 Name Service Unit Min Max DEPT FT 539 5978.5 ROP MWD010 FT/H -1.54 549.58 GR MWD010 API 1.2.[55 117.65 RPX MWD010 OHMM 0.93 372.12 RPS MWD010 OHMM 1.22 2000 RPM MWD010 OHMM 1.69 2000 RPD MWD010 OHMM 1,.16 2000 FET MWD010 HOUR 0.1314 6. 6865 First Last Mean Nsam Reading Reading 3258.75 10880 539 5978.5 176.102 10"791 583.5 5978.5 64.2981 10793 547 5943 29.0632 ].0793 539 5935 48.6286 10793 539 5935 73.8'762 10'793 539 5935 98.0132 1.0793 539 5935 0.466732 10793 539 5935 First Reading For Entire File .......... 539 Last Reading For Entire File ........... 59'78.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/20 Maximum Physical Record..65535 File Tpe ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE RPS FET RPD RPX RPM GR ROP $ 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: START DEPTH STOP DEPTH 5936.5 7673.0 5936.5 7673.0 5936.5 7673.0 5936.5 7673.0 5936.5 7673.0 5944.5 7680.5 5980.0 771.7.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE ,AND CASING DATA OPEN HOLE BIT' SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOl, MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Reco~d Data Record Type .................. 0 Data Specification Block Type ..... 0 02-JUN-01 Insite 66.16 Memory 7717.3 62.9 64.9 TOOL NUMBER PB01912HWRG6 PB01912HWRG6 9.875 Spud Mud 9.50 82.0 9.0 5O0 5.4 3.200 70.0 2.323 99.0 6.000 70.0 3.400 70.0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Ma.'..~ frames per record ............. Unde[ined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HOUR 4 1 68 Units Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 Name Service Unit Min Max DEPT FT 5936.5 7'717 ROP MWD020 FT/H 1.1 316.56 GR MWD020 AP1 28.49 125.72 R?X MWD020 OHMM 1.88 43.62 RPS MWD020 OHP~H 1.97 42.84 RPM MWD020 OHMM 2.12 38.83 RPD MWD020 ONMM 2.57 35.83 FET MWD020 HOUR 0.1895 16.3211 Eirst Reading For Entire File .......... 5936.5 Last Reading For Entire File ........... 771.7 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number. .......... 1.0.0 Date of Generation ....... 01/12/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Mean 6826.75 174.42 87.7475 6.4088 6.59286 6.77185 6.90889 0.833387 Nsam 3562 3475 3473 34'74 3474 34'74 3474 3474 First Reading 5936.5 5980 5944.5 5936.5 5936.5 5936.5 5936.5 5936.5 Last Reading 7717 7717 7680.5 7673 7673 7673 7673 7673 Physical. EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.O03 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL, CODE START DEPTH GR '7681.0 FET 7696.0 RPX 7696.0 RPS 7696.0 RPD 7696.0 RPM 7696.0 STOP DEPTH 12663.0 12670.0 12670.0 12670.0 12670.0 12670.0 ROP LOG HEADER DATA 7717.5 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: 12706.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL, CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT': NEUTRON TOOL, HATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL, STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 09-JUN-C)i Insite 66.16 Memory 12706.0 30.8 67.2 TOOL NUMBER 1993HAGR4 1993HAGR4 6.750 '7706.0 Water Based 10.50 48.0 9.5 60O 9.4 2.300 68.0 1.104 149.0 2.000 68.0 2.400 68.0 Name Service Order Units Size Nsam Rep DEPT FT 4 i 68 ROP HWD030 FT/H 4 1 68 GR MWD030 AP1 4 1, 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHHM 4 i 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 Name Service Unit Min Max DE PT FT 7681 12706 ROE.' MWD030 FT/H 1.1 282.53 GR MWD030 API 25.09 529.16 RPX MWD030 OHMM 0.53 268.31 RPS MWD030 OHMM 0.74 2000 RPM MWD030 OHMM 0.61 2000 R?D MWD030 OHMM 0.55 2000 FET MWD030 HOUR 0.1569 92.8338 First Reading For Entire File .......... 7681 Last Reading For Entire File ........... 12706 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 First Mean Nsam Reading 10193.5 10051 7681 133.575 9978 7717.5 117.05 9965 7681 3.68711 9949 7696 4.78677 9949 7696 7.37819 9949 7696 6.84867 9949 7696 1.01874 9949 7696 Last Reading 12706 12706 12663 12670 12670 12670 12670 12670 Physical EOF Fi].e Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record F1 LE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 99 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL, CODE START DEPTH STOP DEPTH MEMP 6098 0 7302.0 MESP 6098 0 7302.0 MEXP 6098 0 7302.0 VEDP 6098 0 7302.0 VEMP 6098 0 7302.0 VESP 6098 0 7302.0 VEXP 6098 0 '-1302.0 MEDP 6098 0 7302.0 $ LOG HEADER DATA DATE LOGGED: 02-JUN-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: VRI DATA TYPE (MEMORY OR REAL-TIME): Processed TD DRILLER (FT): TOP LOG INTERVAI, (FT): BOTTOM LOG INTERVAL, (~-'T): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 62.9 MAXIMUM ANGLE: 64 . 9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOl_, CODE, TOOL 'rYPE TOOL NUMBER $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CANE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION {IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARI<S: $ Data Formatz Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optics'al log depth units ........... Feet Data Reference ?oint .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Unde~"'ined Absent value ...................... -999 Dep't h Units ....................... Datum Specification Block sub-'type...0 Name Service Order Units Size Nsam Rep Code Offset Chan~el DEPT FT 4 1 68 0 1 VEXP MWD099 OHMM 4 1 68 4 2 VESP MWD099 OHMM 4 1 68 8 3 VEMP MWD099 OHR~ 4 1 68 12 4 VEDP MWD099 OHMM 4 1 68 ]..6 5 MEXP M~D099 OHMM 4 1 68 20 6 MESP MWD099 OHMM 4 i 68 24 7 MEMP MWD099 OHMM 4 1 68 28 8 MEDP MWD099 OHMM 4 i 68 32 9 Name Service Unit Min Max DEPT FT 6098 7302 VEXP MWD099 OHMM 1.078 74.163 VESP MWD099 OHMM 0.882 82.614 VEMP MWD099 OHMM 0.575 75.542 VEDP MWD099 OHMM 0.707 70.655 MEXP MWD099 OHMM 1..4'75 45.678 MESP MWD099 OHMM 1.43 44.704 MEMP MWD099 OHMM 1.283 39.675 MEDP MWD099 OHMM 2.052 35.682 First Reading For Entire File .......... 6098 Last Reading For Entire File ........... 7302 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Mean 67C)0 7.31602 7.57226 7.79173 7.98415 7.05428 7.24866 '7.46098 7.6079 N s am 2409 2409 2409 2409 2409 2409 2409 2409 2409 First Reading 6098 6098 6098 6098 6098 6098 6098 6098 6098 Last Reading 7302 '7302 '7302 7302 7302 '7302 7302 7302 7302 Date of Generation ....... 01/12/20 Ma×imum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/12/20 Origln ................... STS Tape Name ................ UNknOWN Continuation Number ...... 0i Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/12/20 Origin ................... STS Reel Name ................ UNKNOWN Continuation Numbe£ ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File