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208-084
WELL LOG TRANSMITTAL #906120614 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Records: 1D -04A Run Date: 11/22/2019 and 11/23/2019 � e r 3 194 5 January 16, 2020 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1D -04A Digital Data in LAS format, Digital Log Image file I1V 1 CD Rom 50-029-20416-01 �L. Y JAM 2 2 2020 AOC. CC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Date: 2" z Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION���A^ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Plug Perforations L1 Fracture Stimulate Pull Tubing ope&iWifiutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate � , ❑ Alter Casing ❑ ❑ Plug for Redrill ❑ Perforate New Pool //GG��hhaa�I�p��l1ye//pp,�����D�fpye//�ry,�pp�rogram ❑ Repair Well ❑� Re-enter Susp Well ❑ i'1r,i KU7ei Cng Patch❑ 2. Operator ConocoPhillips Alaska, Inc 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Exploratory ❑ 208-084 3. Address: P.O. Box 100360, Anchorage, Alaska 99510 Stratigraphic ❑ Service ❑ 6. API Number: 50-029204160100 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025650 KRU 1D -04A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ku aruk River Field/Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8560 feet Plugs measured None feet true vertical 6462 feet Junk measured None feet Effective Depth measured 6655 feet Packer measured 5657 feet true vertical 6012 feet true vertical 6014 feet Casing Length Size MD TVD Burst Collapse Conductor 51 16 80 80 Surface 2861 10.75 2890 2690 Production 7013 7 7042 6399 Perforation depth Measured depth 7726-8560 feet True Vertical depth 6524-6462 feet Tubing (size, grade, measured and true vertical depth) 3.5 L-80 6684 MD 6041 TVD Packers and SSSV (type, measured and true vertical depth) Packer- Baker SAB -3 Permanent packer 6657 MD 6014 TVD Nipple- Carrico DS nipple with No Go Profile 558 MD 558 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A N/A N/A Suhsequent to operation: N/A N/A IN/A N/A N/a 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.289) 15. Weil Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 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: Dusty Freeborn Contact Name: Dusty Freeborn/Jan Byrne Authorized Title: Well Integrity & Compliance Specialist Contact Email: N16172cop.conn Authorized Signature: Date: ,/ / Contact Phone: 907-659-7224 VTL Form 10-404 Revised 412017 BBDMS4c.,, DEC9 61 Submit Original Only Date Event Summary 09/12/19 TIFL failed due to pressure increase and fluid inflow 101031191 Pulled existing tubing patch from 4973'- 5006' 10/05/19 Set PX plug and passed CMIT-TAA to 2500 psi 10/10/19 LDL identified leaks at 5037', 4990', 11/22/19 11/23/1 Set lower packer of 1 st patch at 5720'. Passed CMIT-TxIA to 2500 psi. Set upper packer/assembly of 1st patch at 5698'. Miss set 9lPull upper packer/assembly of 1st patch. Re -set upper packer/assembly at 5698'. Passed CMIT-TxIA to 2500 psi. Set lower packer of 2nd patch at 5068'. Passed CMIT-TxIA. 11/24/19 11/25/19 11/27/1 Set 1st spacer pipe with anchor latch at 5037'. Passed CMIT-TxIA to 2500 psi. Set 2nd spacer pipe with anchor latch at 5037'. Passed CMIT-TxIA to 2500 psi. Set 3rd spacer pipe with anchor latch at 5037'. Passed CMIT-TxIA to 2500 psi. Set upper packer/assembly of 2nd patch at 4946'. Passed MIT -T to 2500 psi and CMIT- TxIA to 2500 psi. 9 Pull dummy valves and set GLV and OV into station #1 & #2 (2657' and 4036'). Passed MIT -T to 2500 psi. ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 29, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for two retrievable tubing patches set across a known tubing leaks in producer KRU 1D -04A (PTD 208-084). Please contact Jan Byrne or me at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax Delivered to: . 29 -Oct -19 AOGCC 29Oct19-SP0 ATTN: Natural Resources Technician II4� 't... Alaska Oil & Gas Conservation Commision + 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 WELL NAME 1F-14 API # 50-029-21022-00 ORDERSERVICE # DWUJ-11034 FIELD NAME DESCRIPTION KUPARUK RIVER WL DELIVERABLE DESCRIPTION PPROF DATA TYPE FINALFIELD Color DATELOGGED Prints I -Oct-19 1 3Q-04 50.029-22219-00 DWUJ-00133 KUPARUK RIVER WL SCMT FINAL FIELD 11 -Oct -19 1 1B-03 50-029.20588-00 DWUJ-00136 KUPARUK RIVER WL PPROF FINAL FIELD 13 -Oct -19 1 1D -04A 50.029-20416.01 DWUJ-00132 KUPARUK RIVER WL LDL FINAL FIELD 11 -Oct -19 1 31.08 50-029-21550.00 DWUJ-00137 KUPARUK RIVER WL LDL FINAL FIELD 14 -Oct -19 1 1D -04A 50.029.20416-01 EDWI.00025 KUPARUK RIVER WL CALIPER FINAL FIELD 17 -Oct -19 1 2N-329 50-103-20257-00 DWUJ-00143 KUPARUK RIVER WL CALIPER FINAL FIELD 21 -Oct -19 1 TXCUBVED ULI e 7 A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package X ( have been verified to match the media noted above. The specific P 'it Name Signature Date content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. Please return via courier or sign/scan and email a copy to Schlu erger and CPAL AlaskaRTSPrintCenter@slb.com Tom.Osterkam conoco hill s.com SLBAuditor- Schlumberger-Private Originated: API # 50-029-21022-00 Delivered to: DATE 29 -Oct -19 Schlumberger!1 WL I 9O 2ct19SP02 DATA FINAL FIELD DATELOGGED Prints 12.Oct-19 AOGC C PTS - PRINT CENTER „ ATTN: Natural Resources Technician 11 6411 A Street�.J WL Alaska Oil & Gas Conservation Commision Anchorage, AK 99518 '� 333 W. 7th Ave, Suite 100 (907) 273-1700 main (907)273-4760 fax -of#j Anchorage, AK 99501 NAME 1F-14 API # 50-029-21022-00 ORDER H 5WUJ-11034 FIELDWELL NAME DESCRIPTION KUPARUK RIVER WL I DELIVERABLE DESCRIPTION PPROF DATA FINAL FIELD DATELOGGED Prints 12.Oct-19 CD's 1 3Q-04 50-029-22219.00 DWUJ-00133 KUPARUK RIVER WL SCMT FINAL FIELD 11 -Oct -19 1 1B-03 50.029-20588.00 DWUJ-00136 KUPARUK RIVER WL PPROF FINAL FIELD 13 -Oct -19 1 1D -04A 50.029-20416-01 DWUJ-00132 KUPARUK RIVER WL LDL FINAL FIELD 11 -Oct -19 1 31.08 50-029-21550-00 DWUJ-00137 KUPARUK RIVER WL LDL FINAL FIELD 14 -Oct -19 1 1D -04A 50-029-20416-01 EDWI-00025 KUPARUK RIVER WL CALIPER FINAL FIELD 17-Oct49 1 2N-329 50-103-20257-00 DWUJ-00143 KUPARUK RIVER WL CALIPER FINAL FIELD 21 -Oct -19 1 jr 7 courier or sign/scan and email a copy to A Transmittal Receipt signature confirms that a package (box Z ley and CPAI. SLB Auditor - Sch lu m Berger -Private envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific Date content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. • 110Zoe^��� Vt WELL LOG TRANSMITTAL#902783200 DATA LOGGED tt/3/2015 M. K.BENDER To: Alaska Oil and Gas Conservation Comm. October 30, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED NOV 03z 5 RE: Multi Finger Caliper(MFC) and Leak Detect Log: 1D-04A AOGCC Run Date: 9/25/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1D-04A Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20416-01 Leak Detect Log 1 Color Log 50-029-20416-01 SCANNED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 1) ,(4.247.4kii.) • • Nvv- ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 RECEIVED NOV 032015 October 31, 2015 AOGCC Ms. Cathy Foerster �Q� Alaska Oil& Gas Commission saute Nov 1 `� 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 1D-04A(PTD 208-084) for a retrievable tubing patch which was pulled and reset in the tubing above the packer. Please call Brent Rogers or myself at 659-7224 or Dusty Freeborn/Jan Byrne at 659-7126 if you have any questions. Sincerely, 7ZZ1 Kelly Lyons Problem Wells Supervisor Attachments STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool rRepair Well Re-enter Susp Well r Other:tbg patch 17 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: _ ConocoPhillips Alaska, Inc. Development az,— Exploratory r 208-084 3.Address: 6.API Number: Stratigraphic r Service r 50-029-20416-01 P.0. Box 100360,Anchorage,Alaska 99510 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25650 1 D-04A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8560 feet Plugs(measured) None true vertical 6462 feet Junk(measured) None Effective Depth measured N/A feet Packer(measured) 6657 true vertical N/A feet (true vertical) 6014 Casing Length Size MD TVD Burst Collapse CONDUCTOR 51 16 80 80 SURFACE 2861 10.75 2890 2690 PRODUCTION 7013 7 7042 6399 RECEIVED Perforation depth: Measured depth: 7726-8560' NOV 0 3 2015 True Vertical Depth: 6524'-6462' C AOGC Tubing(size,grade,MD,and TVD) 3.5, L-80,6684 MD,6041 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER SAB-3 PERMANENT PACKER @ 6657 MD and 6014 TVD NIPPLE-CAMCO DS NIPPLE w/NO GO PROFILE @ 558 MD and 558 TVD 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 r Exploratory r Development F7 Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil p Gas r VVDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 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 Contact Kelly Lyons/Brent Rogers Email n1617( cop.com Printed Name -II ons _agiTitle Problem Wells Supervisor Signature l Phone:659-7224 - Date 10-31-15 RBDMS NV n 5 2015 S Submit Original Only 10-404 Revised 5/2015g • 1D-04A • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/07/15 (WC); MIT OA TO 1800 PSI. (PASSED), TIFL (FAILED) DUE TO IA PRESSURE INCREASE AND INFLOW DURING MONITOR. Initial T/I/O/00= 170/1261/1145/0 IA FL @ 4771' 172' (above station#3 OV), OA FL @ SF Pressured OA to 1800 psi. w/20 gal. diesel. T/I/O/O0= 180/1261/1800/0 15 min. T/I/O/00= 180/1261/1775/0 (-25) 30 min. T/I/O/OO= 180/1261/1770/0 (-5) PASS Bled OA to 750 psi. in 4 min. T/I/O/OO= 180/1261/750/0 Shut in well and stacked tubing and IA T/I/O/O0= 1250/1250/700/0 IA FL @ 4147' (624' of inflow) Bled IA to 620 psi. in 30 min. T/I/O/00= 1200/620/650/0 T FL @ 2532' (decimeter @ 600 fps), IA FL @ 3496' (651' of inflow). Bled AL line to 0 psi. 15 min. T/I/O/OO= 1200/660/650/0 (+60) T FL @ 2746' (214'of outflow), IA FL @ 3253' (243' of inflow). 30 min. T/I/O/OO= 1200/700/650/0 (+40) T FL @ 2802' (56' of outflow), IA FL @ 3055' ( 198' of inflow). IA inflowed a total of 1716'. Final T/I/O/OO= 1200/700/650/0 09/21/15 PULLED UPPER ER PATCH ASSEMBLY @ 4953' RKB; MAKE SEVERAL ATTEMPTS& UNABLE TO RECOVER ELEMENT; SET 3 1/2 ER TEST TOOL IN LOWER ER PACKER @ 4987' RKB. LRS ON LOCATION DOING CIRC OUT CMIT. IN PROGRESS. PUMPED 200 BBLS OF DIESEL DOWN THE TUBING TAKING RETURNS UP THE IA. COMBO MIT FAILED. JOB COMPLETE. 09/22/15 ATTEMPT CMIT TXIA(FAILED W/ 1BPM LR); W/HOLEFINDER ON TOP OF TEST TOOL OBTAIN THE SAME LR; PULLED ER TEST TOOL&LOWER WFT ER PACKER @ 4987' RKB; SET 2.81"XX PLUG W/GAUGES (112"OAL) @ 6635' RKB. CMIT TXIA(PASS). JOB SUSPENDED FOR PLAN FORWARD LRS PERFORM COMBO MIT, 1.9 BBLS TO PRESSURE UP : PRE CMIT T= 850 IA=950 OA = 500 STARTING T=2525 IA=2525 OA=520 15 MIN T=2490 IA= 2490 OA= 520 30 MIN T = 2490 IA=2490 OA= 520 09/25/15 RUN LEAK DETECTION LOG LOOKING FOR SUSPECTED LEAK BELOW PULLED PATCH. FOUND KNOWN LEAK AT 4969'AND NEW LEAK AT 4992'WITH LRS PUMPING DOWN TUBING AT 0.5 BPM AND 1000 PSI. RETURNS UP IA TO FLOWLINE. FP FL WITH 6 BBLS METH. JOB COMPLETE. . • ID-04A • DESCRIPTION OF WORK COMPLETED SUMMARY 10/30/15 SET 2.72" SOS PARAGON II PACKER (ser#cpp35045)W/SHEAR OUT DISC @ 5006' RKB.LRS PERFORMED CMIT TO 2500 PSI,PASSED. SET 2.70" MIDDLE STARDDLE PATCH EXTENSION ASSEMBLY(oal-28.84') @ 4978' RKB. SET 2.72" SOS UPPER PARAGON II PACKER (ser#cpp35032) STARDDLE PATCH ASSEMBLY(oal-21.55') @ 4958.7' RKB. BLOW OUT SHEAR DISC,SHEARED @ 3700 PSI. PERFORMED DRAW DOWN TEST ON IA.SAW NO PRESSURE INCREASE. GAS LINE LINE READY TO BE TIED IN TO BOL.... CMIT,PASSED. PRE MIT T/I/0=1450/1420/480 INITIAL T/I/0=2500/2450/480 15 MINS T/I/0=2450/2420/480 30 MINS T/I/0=2450/2420/480 MIT-T TO 2500 PSI. PASSED. PRE MIT T/I/0=1175/1150/470 INITIAL T/I/0=2500/1200/470 15 MINS T/I/0=2400/1200/470 30 MINS T/I/0=2375/1200/470 LEAVE 2500 PSI ON TBG. RIG OFF TBG & R/U ON IA. PRESSURE UP IA TO 2500 PSI. RIG BACK UP 0 TBG, PRESSURED UP TO 3700 PSI TO BLOW DISC. IA UNLOADED TO TBG PRESURE. PERFORMED DRAW DOWN TEST ON IA. BLED DOWN FROM 1050 PSI TO 400 PSI. MONITOR FOR 5 MINUTES. NO PRESSURE CHANGE. Executive Summary Pulled existing Weatherford retrievable tubing patch. Replaced it with a longer, 47' Statewide Oilfield Services retrievable tubing patch to cover an additional leak that had developed. KUP PROD • 1D-04A ConocoPhillips a Well Attributes Max Angle&MD TD Alaska,inc. Wellbore API/UWI Field Name Wellbore Status rax (°) MD(ftKB) Act Btm(ftKB) mnoovlyupc 500292041601 KUPARUK RIVER UNIT PROD 105.46 7,460.33 8,560.0 4Y Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 10-046,10/25/2015 145.57 PM SSSV:NIPPLE 10 11/10/2014 Last WO: 5/31/2000 38.99 1/28/1980 vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:Mandrel Orientation pproven 10/25/2015 I ' Casing Strings HANGER;27.0 �it ` Casing Description OD(in) 113(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 29.0 80.0 80.0 65.00 H-40 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.794 28.8 2,890.0 2,690.3 45.50 K-55 ,,,,-„a, ,,r,,, ,,,°„a,,,„„a„",,,,,,, ,,, ',,,, nut Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 29.8 7,042.3 6,398.8 26.00 K-55 -MA CON ou CTOR:2s.o-fio.oNI Casing DescriptionOD(in) ID(in) lop(ftKB) Bet Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread LINER 1D-04 Post 5 4.151 6,746.0 7,099.0 6,455.5 14.87 K-55 S/T NIPPLE;557.6 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread WINDOW AL1-02 5 4.000 7,090.0 7,098.0 6,454.5 15.00 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread LINER A 23/8 1.992 7,730.2 8,560.0 6,462.0 4.40 L-80 STL GAS LIFT;2,857.4 - Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inct(°) Item Des Com (in) 7,730.2 6,523.0 98.89 ANCHOR ANCHOR 1.992 SURFACE;28.8-2,890D ..` 8,526.8 6,467.4 98.44 0-RING BTT 0-RING 1.992 GAS LIFT;4,035.9 _ Tubing Strings Tubing Description (String 1a. ID(in) (Top(HKB) (Set Depth(H..f Sef Depth(TVD)(...I WI(Ib/fl) IGratle (Top Connection TUBING 31/2 2.992 27.0 6,604.41 6,041.4 9.30 L-80 EUEBrd ill Completion Details Nominal ID GAS LIFT;4,949.4 •, Top(ftKB) Top(ND)(ftKB) Top Inel(°) Item Des Corn (in) is 27.0 27.0 0.00 HANGER CAMERON GEN 4 TUBING HANGER 3.540 -'Qi-r PACKER;4,953.9 557.6 557.6 0.21 NIPPLE CAMCO'DS'NIPPLE w/NO GO PROFILE 2.875 aQ4a 6,635.3 5,992.3 3.83 NIPPLE HES'X'NIPPLE w/2.81"PROFILE 2.750 PATCH;4,958• Iiii6,642.7 5,999.7 3.80 PBR BAKER'80-40'PBR w/10'STROKE 2.992 ,`n I 6,656.1 6,013.1 3.74 SEAL ASSY BAKER KBH-22 ANCHOR SEAL ASSEMBLY 3.000 PACKER;4,987.1 6,657.0 6,014.0 3.73 PACKER BAKER SAB-3 PERMANENT PACKER 3.250 111 6,673.0 6,030.0 3.67 NIPPLE CAMCO'D'NIPPLE 9CR w/NO GO PROFILE***NIPPLE 2.750 NOT ACCESSIBLE DUE TO BEING COVERED BY 1D- 04L1-02 D- 04L1-02 LINER TOP"" GAS LIFT;5,820.5 6,683.9 6,040.9. 3.62 WLEG WIRELINE ENTRY GUIDE. 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;6,135.6 Top(ND) Top Ieel Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) ' 4,953.9 4,389.6 30.31 PACKER WEATHERFORD WIDEPAK LE PACKER 9/6/2013 1.810 4,958.0 4,393.1 30.21 PATCH SPACER PIPE&RS ANCHOR 9/6/2013 1.750 GAS LIFT;6,558.2 4,987.1 4,418.4 29.46 PACKER WEATHERFORD ER PACKER 4/29/2012 1.750 7,092.0 6,448.5 1.54 WHIPSTOCK BAKER MONOBORE WHIPSTOCK CEMENTED IN 5/29/2008 0.000 PLACE NIPPLE;6,635.3 Perforations&Slots Shot Dens Top(ND) Bim(TVD) (shots/f P60;8,642.7 Top(ftKB) Btm(ftKB) (HKB) (ftKB) Zone Date t) Type Com 7,726.0 8,560.0 6,523.7 6,462.0 C-3,C-2,10- 6/13/2008 32.0 SLOTS Alternating solid/slotted SEAL ASSY;6,656.1 - 04A pipe-0.125"x2.5"@4 circumferential adjacent + r rows,3"centers PACKER;6,657.0 staggered 18 deg,3'non -slotted ends Mandrel Inserts •Lli. St aH Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(In) Sery Type Type (in) (psi) Run Date Com 1� 2,657.4 2,492.2 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,193.0 1/18/2015 12:00 NIPPLE;6,673.0 '..° 2 4,035.9 3,640.1 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,242.0 1/18/2015 10:00 t 3 4,949.4 4,385.7 CAMCO KBUG 1 GAS LIFT OV INT 0.188 0.0 9/14/2015 2:00 4 5,620.5 4,996.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/31/2000 2:00 WLEG;6,683.9 'i; 5 6,135.8 5,495.7 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/31/2000 9:30 6- 6,558.2 5,915.4 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/4/2000 7:30 Notes:General&Safety End Date Annotation PRODUCTION;29.8-7,042.3 12/25/2002 NOTE:WAIVERED WELL:IA X OA COMMUNICATION 6/21/2008 NOTE:Sidetrack KOP is 1 D-04AL1-02,A&all other laterals off this wellbore I 4/28/2009 NOTE:View Schematic w/Alaska Schemalic9.0 9/27/2015 NOTE:Mandrel Orientation on 27 Sept 2015 WHIPSTOCK;7,092.0- WINDOW AL1-02;7,090.0- 7,096.0 LINERID-04 Post S/T; 8,746.0-7,099.0 LINER AL1-02;8,680.7-9,852.0 SLOTS;7,726.0-8,560.0 LINER A;7,730.2-8560.0 • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q $ - Q ~ ~- Well History File Identifier Organizing (done) RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: ~..o.~a iiiuimiuiuim DIGITAL DATA iskettes, No. ^ Other, No/Type: o a„~~~~~ iiiiuiiiiiimiii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: Maria Date: /s~ ~ Project Proofing III IIIIII IIII) II III BY: Maria Date: ~s~ Scanning Preparation _~ x 30 = ~ + ~ y =TOTAL PAGES_~ (Count does not include cover sheet) BY: Maria Date: ~' 4/~Q ~s~ Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ q / I V ~s~ t Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned III IIIIIIIIIII IIIII BY: Maria Date: ~s~ Comments about this file: Quality Checked III II II II III II') III -~ 10/6!2005 Well History File Cover Page.doc STATE OF ALASKA KA OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS t.Operations Performed: Abandon r Repair w ell PT. Rug Perforations r F4 rforate r • uirmeR„ i bi* atch Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat.Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r _ 208-084 " 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r` 50-029-20416-01 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 025650 • 1D-04A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): None Kuparuk River Field/Kuparuk River Oil Pool • 11.Present Well Condition Summary: Total Depth measured 8560 feet Plugs(measured) None true vertical 6462 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 558,4963,4965,4987,6657 true vertical 0 feet (true vertical) 558,4397,4399,4418,6014 Casing Length Size MD TVD Burst Collapse CONDUCTOR 52 16 80 80 SURFACE 2861 10.75 2890 2690 PRODUCTION 7013 7 7042 6401 n Perforation depth: Measured depth: 7726'-8560'Slotted Liner /•SCANNED NO v 1 4 2O' S True Vertical Depth: 6534'-6462' CAN Tubing(size,grade,MD,and TVD) 3.5, L-80,6684 MD, 6041 TVD Packers&SSSV(type,MD,and TVD) NIPPLE-CAMCO'DS' NIPPLE W/NO GO PROFILE @ 558 MD and 558 TVD PACKER-WEATHERFORD WIDEPAK LE PACKER @ 4953.9 MD and 4389.6 TVD PATCH-SPACER PIPE&RS ANCHOR @ 4958 MD and 4393 TVD PACKER-WEATHERFORD ER PACKER @ 4987 MD and 4418 TVD ' PACKER-BAKER SAB-3 PERMANENT PACKER @ 6657 MD and 6014 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 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 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r • Service r Stratigraphic r X 16.Well Status after work: Oil r • Gas r WDSPL r Daily Report of Well Operations GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 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 Contact Jolin Oksness/Brent Rogers/Kelly Lyons Email n1617 aa•cop.com Printed Name Jolin Oksness Title Problem Wells Supervisor Signature Phone:659-7224 Date 09/24/2013 Form 10-404 Revised 10/2012 VIZ-P 101)5/J 3 /0/O '% Submit Original Only RBDMS OCT 11 2 13 r 1D-04A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/06/13 36.09' tubing patch from the lower WFD ER Packer set @ 4990' RKB into the upper packer at 4953.9' RKB. The patch has a setting depth of 4958'. RAN 2.5" HES DPU TO SET WFT WIDEPAK LE PKR SPACER PIPE SNAP LATCH ASSY (OAL=36.09'), SET @ 4957' SLM/4987' RKB. STUNG INTO LOWER ER PKR @ 4990' RKB. MITT 2500#WITH TEST TOOL IN PATCH DRAWDOWN IA. TURN OVER TO DHD. **MITT pass: preTIO=1000/1400/360, initial=2560/1398/360, 15min=2550/1398/360, 30 m i n=2 550/1398/360** I 1D-04A DESCRIPTION OF WORK COMPLETED SUMMARY • Dan Seamount Page 1 of 1 09/27/13 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 September 24, 2013 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. wells 1D-04A(PTD 208-084). The report records the completion of the tubing patch installation and integrity test. Please call myself, Brent Rogers or Kelly Lyons at 659-7224 or MJ Loveland or Martin Walters at 659-7043 if you have any questions. Sincerely, Jolin Oksness Well Integrity Engineer on behalf of Problem Well Supervisor Attachments 10-404 Report of Sundry Well Operations 1D-04A 1D-04A Description of Work Completed 0 • IIIV • • ConocoPhillips Alaska P.O. BOX 100360 RECEIVED ANCHORAGE, ALASKA 99510 -0360 MAY 2 9 2012 AOGCC May 26, 2012 Mr. Dan Seamount , . Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 JUI. ?' 3 `z012 Dear Mr. Seamount: Enclosed please find 10 -404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. wells 1D -04A (PTD 208 -084). The report records the reinstallation of a tubing patch and follow -up integrity test after the original patch lost integrity. Please call Kelly Lyons / Brent Rogers at 659 -7224 or MJ Loveland / Martin Walters at 659 -7043 if you have any questions. Sincerel , ,,,,,'-' /7 L___ Kelly Lyons Problem Wells Supervisor Attachments • STATE OF ALASKA • A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Tubing Patch Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator ConocoPhillips Alaska, Inc 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ 208 -084 - 3. Address: P.O. Box 100360 Anchorage AK 99510 Stratigraphic El Service ❑ 6. API Number: _ 50- 029 - 20416 -01 ^-r 0 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 025650 - 1D-04A 9. Logs (List Togs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8560 feet Plugs measured feet true vertical 6462 feet Junk measured feet Effective Depth measured feet Packer measured 6657 feet true vertical feet true vertical 6014 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 52 16 80 80 Surface 2861 10.75 2890 2690 RECEIVED Intermediate Production 7012 7 7042 6401 Liner MAY 2 9 2012 Perforation depth Measured depth 7726' -8560' Slotted liner feet AOGCC True Vertical depth 6534' -6462' feet Tubing (size, grade, measured and true vertical depth) 3.5 L -80 6684' MD 6041' TVD Packers and SSSV (type, measured and true vertical depth) SSSV =nip 558' MD 558' TVD Packer Baker SAB -3 6657' MD 6014' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory El Development El - Service ❑ Stratigraphic ❑ Daily Report of Well Operations x 16. Well Status after work: Oil - U Gas ❑ WDSPL U GSTOR ❑ WINJ ❑ WAG ❑ 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 Contact Kelly Lyons / Brent Rogers Printed Name O Kelly Lyons - d'`� / Title Problem Wells Supervisor Vim - ma y '- _ Signature f `'�'`��) " ' Phone 659 -7224 Date 5/26/2012 ,k r ,/'' „ 7RB MS MAY 2 9 2012. `"J7' G,, i. / I Z A t �l Form 10-404 Revised 11/2011 71 6. ./ 2 . Submit Original Only • • Date Event Summary 03/22/12 SET TEST TOOL IN ER PKR @ 4966' RKB. TBG TEST FAILED. RAN HOLEFINDER TO 4922' SLM; MIT TBG 2500 PSI, PASSED. RESET ER TEST TOOL @ 4966' SLM. MIT TBG, PASSED. RDMO FOR NORDIC 3. RIH w/ QC, 3 "GR, 3 1/2 ER PACKER TEST TOOL TO 4939' SLM / 4966' RKB, SET, INIT. PSI T /I /0= 2050/2165/400 START PSI T /I /0= 2500/2165/400 15 MIN T /I /0= 2425/2170/400 AFTER 30 MIN T /I /0= 2375/2180/400 15 MORE MINS T /I /0= 2350/2190/400. RIH w/ QC, 2.5 "RB, 3 1/2 D &D HOLEFINDER TO 4922' SLM, SET, PRESSURE TBG TO 2500 PSI, PASSED MITT, POOH, CONFER w/ CWG. RIH w/ QC, 3 "GR, 3 1/2 ER TEST TOOL ( NEW ) TO 4939' SLM / 4966' RKB, SET, PRESSURE UP ON TBG TO 2500 PSI, HAD TO BUMP UP 1 TIME, FAILED FIRST TIME, TBG DROPPED TO 2350 PSI T /I /0= 2500/1985/380 AFTER 15 MIN. T /I /0= 2400/1995/380 AFTER 30 MIN. T /I /0= 2375/2000/380 03/23/12 WEATHER DELAYED START. PULLED 3 -1/2" WEATHERFORD (21.99' C)AI ) I IPPFR PATCH ASS'Y @ 4966' RKB. PULLED LOWER ER PKR a 4985' RKB. SET 2.813 XX PLUG WITH FILL EXTENSION (52 "OAL) (a) 6635' RKB. BLED TBG & IA TO PRODUCTION LINE. COMPLETE 03/25/12 T POT- passed; T PPPOT- passed; Initial T /I /O /OOA= si/490/390/0; Stung into T PO test void with 300psi. Bled to Opsi. gas. 15min. reading 275psi. Torqued LDS to 450ft. #'s Bled T PO to Opsi. 15min. reading 0 +psi. Pressured up T PO test void with hydr fluid 4800psi. 15min. reading 4800psi. 30min. reading 4800psi. Final T /I /0 /OOA= si/490/390/0 04/21/12 PULLED 2.81 XX PLUG a 6635' RKB. BRUSHED & FLUSHED TBG FROM 4900' TO 5100' SLM. READY FOR E/L. 04/24/12 SET WEATHERFORQ ER PACKER (2.74" OD) AT 499O' RKR RFAF)Y FOR SI ICKI I1sJE. 04/26/12 SET 26' WEATHERFORD UPPER PATCH ASS'Y ON HES' DPU @ 4963' RKB. SET TEST IDOL, TBG TEST FAILED. SET HOLEFINDER ABOVE PKR, GOOD TBG TEST. REPEATED TEST TOOL IN UPPER PKR @ 4963' RKB. TEST PRESSURE FALLING OFF SLOWLY; SLOW INCREASE IN PRESSURE ON IA. IN PROGRESS. 04/27/12 PULLED 26' UPPER PATCH ASS'Y FROM 4963' RKB. MEASURED BHP @ 6651' RKB. BRUSH & FLUSH TO LOWER ER PACKER. SET TEST TOOL IN LOWER ER PACKER @ 4990' RKB. PULLED DV FROM 4949' RKB. IN PROGRESS. 04/28/12 LOADED WELL WITH DSL. CMIT 2000 PSI, PASSED. SET DV @ 4949' RKB. PULLED ER TEST TOOL FROM 4990' RKB. IN PROGRESS. ** *CMIT pass preTIO= 1000/1000/350.. initialT10= 2000/1960/355, 15minTIO= 1975/1940/355 30minTI1= • • I " ** 04/29/12 SET 26' UPPER PATCH ASS'Y ON HES DPU (ca 4963' RKB. MITT 2000 PSI, PASSED. GOOD DRAWDOWN TEST ON IA. COMPLETE. ** *MITT preTIO= 850/840/356, initialT10= 2050/860/356, 15minTIO= 1950/870/356, 30minTIO= 1900/870/358 * * ** • 05/02/12 TIFL (PASSED) Arrived on location Gas lift was shut in. IA -FL © 240'. T /I /O= 200/0 vac /620. Shut in wing stacked tubing out with gas. Stacked T /I /O = 1350/0 vac /480. Shot second IA -FL @ same location. 60 min monitor T /I /O= 1350/0 vac /380 shot third IA -FL © same location. Summary Set Weatherford ER patch assembly from 4963' to 4990'. TIFL passed following patch set I ' i KUP 1D-04A ConocoPhillips 8 Well Attributes Max Angle & MD TD Wellborn APIIUWI Field Name Well Status Inc( (°) MD (ftKB) Act Btm (ftKB) Combo"P fillips 500292041601 KUPARUK RIVER UNIT PROD 105.46 7,460.33 8,560.0 "' Comment H2S (pprn) Date Annotation End Date KB-l3rd (ft) Rig Release Date Well coot,¢ - ID 47302012 9.2136 AM SSSV: NIPPLE 75 9/26/2011 Last WO: 5/31/2000 38.99 6/21/2008 Schematic - Actual Annotation Depth (ft18) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: SET PATCH ASSY, GLV C/O ninam 4/30/2012 Casing Strings Casing Description String 0... String ID ... Top (MB) Set Depth (1... Set Depth )TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 28.0 80.0 80.0 65.00 1-1 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thad HANGER, 27 I 1 SURFACE 103/4 9.794 28.8 2,890.0 2,690.3 45.50 K - 55 Casing Description String 0... String ID ... Top (ft69) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd PRODUCTION 7 6.276 29.8 7,042.3 6,400.5 26.00 K - 55 Casing Description String 0... String ID ... Top (ft1(9) Set Depth (f.. Set Depth (TVD) .. String Wt.. String .. String Top Thrd LINER 1D 5 4.151 6,345.0 7,099.0 6,455.3 14.87 K - 55 CONDUCTOR, Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 28. WINDOW AL1 - 02 5 4.000 7,090.0 7,098.0 6,454.3 15.00 Casing Description String 0... String ID ... Top (88(9) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd NIPPLE, 558 fr LINER AL1 -02 TOP 23/8 1.992 6,650.7 7,726.0 6,523.8 4.50 L -80 STL Liner Details Top Depth (TVD) Top Intl Nomi... GAS LIFT, Top (RKB) (MB) ( °) Item Description Comment ID (in) 2'6557 6,650.7 6,007.7 3.82 DEPLOY DEPLOYMENT SLEEVE 2.600 SURFACE, Casing Description String 0... String ID _. 'Top (WEI) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 29 -2,890 LINER A 12 3/8 I 1.992 7,730.2 I 8,560.0 I 6,462.0 I 4 I L -80 I STL Liner Details GAS LIFT, If Top Depth 46 (TVD) Top Intl Nomi... S Top (f(103) (ftKB) (1 Item Description Comment ID (in) 7,730.2 6,523.1 98.96 ANCHOR ANCHOR 1.992 GAS LIFT, 4649 8,526.8 6,467.4 98.44 0-RING BTT O -RING 1.992 1 J�� Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd PACKER,4.963 .i \ TUBING TUBING 31/2 2.992 27.0 6,684.4 6,041.4 9.30 L -80 EUE8rd PATCH,4.965 - ' , Completion Details Top Depth PACKER, 4,967 )TVD) Top Intl Nomi... 4 Top (ftKB) (RKB) 1 °) Item Description Comment ID (in) GAS LIFT, 27.0 27.0 - 0.06 HANGER CAMERON GEN 4 TUBING HANGER 3.540 5,620 G Fill AS LIFT, 557.6 557.6 0.21 NIPPLE CAMCO 'DS' NIPPLE w /NO GO PROFILE 2.875 6,136 GAS LIFT 6,635.3 5,992.3 3.91 NIPPLE HES 'X' NIPPLE w/2.81" PROFILE 2.750 6,558 . NIPPLE, 6,635 6,642.7 5,999.7 3.87 PBR BAKER '80 PBR w /10' STROKE 2.992 PBR, 6,643 SEAL ASSY, 6,656.1 6,013.1 3.79 SEAL ASSY BAKER KBH ANCHOR SEAL ASSEMBLY 3.000 6,656 4 PACKER, 6657 6,657.0 6,014.0 3.79 PACKER BAKER SAB - 3 PERMANENT PACKER 3.250 NIPPLE, 6,673 WLEG, 6,684 6,673.0 6,030.0 3.70 NIPPLE CAMCO '13' NIPPLE 9CR w /NO GO PROFILE ***NIPPLE NOT 2.750 PRODUCTION, 3 - ACCESSIBLE DUE TO BEING COVERED BY 1D - 02 LINER 0.0 WHIPSTOCK, � TOP*** 7,092 WINDOW 6,683.9 6,040.9 3.64 WLEG WIRELINE ENTRY GUIDE. 2.992 ALt-02, - 7,090 -7698 LINER 1004, _ I111 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) 8.345 -7099 Top Depth LINER ALI -02 (TVD) Top Intl TOP, - 8,651 -7,726 : Top (ftKg) (ftKB) rl Description Comment Run Date ID (In) SLOTS, - 4,963 4,397.6 30.08 PACKER WEATHERFORD ER PACKER 4/29/2012 1.810 7,726 -8,560 LINER -60 - - 4,965 4,399.3 30.03 PATCH SPACER PIPE &SNAP LATCH ASSEMBLY 4/29/2012 1.750 7,7 0 TO (10 4,987 4,418.4 29.46 PACKER WEATHERFORD ER PACKER 4/29/2012 1.750 8,560 LINERAL1 - 02 7,092 6,448.5 0.02 WHIPSTOCK BAKER MONOBORE WHIPSTOCK CEMENTED IN PLACE 5/29 /2008 0.000 TOP, - 6,650A,970 & & LINER AL1 -02, Perforations Slots 6,651 -9,852 Shot Top (TVD) etm (TVD) Dens • . Top (661(9) BbS (ftKB) (BNB) (MB) Zone Date (eh... Type Comment 7,726 8,560 6,523.8 6,462.0 C-3, C-2, 1D-04A 6/13/2008 32.0 SLOTS Slotted Liner • s•■ N otes: General & Safety - End Date Annotation • a' W. `e 12/25/2002 NOTE: WAIVERED WELL: IA X OA COMMUNICATION J ∎m. 6/21/2008 NOTE: Sidetrack KOP is 1D-04AL1-02, A & a9 other laterals off this weibore Tilt: 4/28/2009 NOTE: View Schematic w/ Alaska Schematic9.0 III . Mandrel Details Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run Stn Top (ftKB) (RKB) (') Make Model (In) Sery Type Type (In) (psi) Run Date Com... l 1 2,657.4 2,492.2 31.41 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,266.0 7/12/2010 2 4,035.9 3,640.3 36.57 CAMCO KBUG 1 GAS LIFT OV BK 0.188 0.0 7/12/2010 3 4,949.4 4,386.0 30.43 CAMCO KBUG 1 GAS LIFT DMY INT 0.000 0.0 4/28/2012 4 5,620.5 4,997.3 19.48 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/31/2000 5 6,135.6 5,495.8 9.63 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/31/2000 _ 6 6,558.2 5,915.4 4.16 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/4/2000 ri Zoe - 2■552, WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 4, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 1D -04A Run Date: 4/25/2012 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 1D -04A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 20416 -01 JUL 12 `t012' 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: Vv-1/1 Signed: %�, • • Igek ��- Regg, James B (DOA) pi-6 Z06- From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, March 20, 2012 2:32 PM lZ- To: Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 1 D -04A (PTD 208 -084) Report of IA SCP Attachments: 1D-04A schematic.pdf i Jim, Guy Kuparuk producer 1 D -04A (PTD 208-684) was identified with IA SCP due to annuluspressure trends and bleeds. The SCP is suspected to be from TxIA communication. The well is currently SI due to rig activity on 1D pad. Slickline is tentatively scheduled to start working on the well on 03/21/12 -TFy will attem t re air the leak or secure the well. The secure will be done if Slickline needs to move off the well due to rig activity and will return at a ater date for further attempts to repair. Attached is a 90 day TIO plot and schematic. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 _ Pager (907) 659 -7000 pgr. 909 5 GP MAR 1 1 , :? ZUIL cf 2/t00r5` Ar 446 1 I KRU 1D -04A PTD 2080840 3/20/2012 TIO Pressures Plot TRN_ANNL ANNULUS PRESSURE TRENDS 500_ anbC 3000 WELL NAM WLKRU1D-04 — 200. ' 3000 3000. 2700 3000. • 3000. 2400 3000., 2100 1800 __- 1500 -- 1200 __J\ • t i 600 < - 300 El 0 , --_-- ow , PLOT START TIME MINOR TIME PLOT DURATION PLOT END TIME • 21— DEC -11 13:10 MAJOR TIMEWEEK IIIIIIIIIIII HRS 7D Farm 6M ®®ia R PICK TINE: SC TAG NAME DESCRIPTION P -VALUE LATEST Pil WL1D -04 —CHORE FLOW TUBING CHORE 7777777 DRILLSITE WELL NI .., SCRATCH 95 FLOW TUBING PRESSURE 7777777 ® PREY WELL a ia , , -. ® SCRATCH_95 FLOW TUBING TEMP ? ? ?? ? ?? ■ NEXT WELL PI- 1D5231 -04 GL CASING PRESSURE ? ? ? ? ? ?? - TM ? ?? ENTRY TYPE OPERATOR . 777777? I OPERATOR VERIFIED NI SCRATCH_95 INNER ANNULUS PRES 7777777 SYSTEM AUTO ENTRY SCRATCH_95 OUTER ANNULUS PRES 777777? I BOTH N.-- KUP • 1 D -04A COnocoPhlIlips Well Attributes Max Angle & MD TD A aSk , Inc, Wellbors API /UWI Field Name Well Status Inc! (.) MD (RKB) Act Btm (MKS) Taps 500292041601 KUPARUK RIVER UNIT PROD 105.46 7,460.33 8,560.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date Well conng: - 1D - O4A, 8/18/2010 SSSV: Nipple 50 8/7/2009 Last WO: 5/31/2000 38.99 6/21/2008 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag Rev Reason: SET PATCH, GLV C /O, Pull Plug /Catcher Imosbor 8/18/2010 Gasin! Strin.s Casing Description Stri g 0.. String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 28.0 80.0 80.0 65.00 H 40 ■ r Casing Description String O., String ID .., Top (RKB) Set Depth (f... Set Depth (TVO) ... String Wt... String ... String Top Thrd HANGER, 27 SURFACE 103/4 9.794 28.8 2,890.0 2,690.3 45.50 K - 55 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f. Set Depth (TVD) ... String Wt... String ... String Top Thrd p ,(Q �. PRODUCTION 7 6.151 29.8 7,042.3 6,400.5 26.00 K - 55 j 44g0f5 " ` Casing Description Strng 0... Stdng ID ... Top (I8(B) Set Depth (f... Set Depth (TVD) ... String W.. String ... String Top Thrd " �" � '� LINER 1 5 4.151 6 7 6,455.3 14 L K -55 CONOUC70R, Casing Description String 0... String ID ... Top (11K13) Set Depth (1... Set Depth (TVD) ... String Wt... String Top Thrd 2e eO WINDOW AL1 - 02 5 4.000 7,090.0 7,098.0 6,454.3 15.00 Casing Description String 0... String ID ... Top (MKS) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd NIPPLE.558 LINER AL1 -02 TOP 2 3/8 1.992 6,650.7 7,726.0 6,523.8 4.50 L -80 STL Liner Details Top Depth (TVD) Top Intl Noml... GAS Z T, TO•(RKB) (R(B) ( °) Item Description Comment ID(in) 6,650.7 6,007.7 3.82 DEPLOY DEPLOYMENT SLEEVE 2.600 ■ SURFACE. Casing Description String 0... String ID ... Top (MB) Set Depth (L. Set Depth (TVD) ... String Wt... String ... String Top Thrd 29 - 2.890 LINER A 23/8 1.992 7,730.2 8,560.0 6,462.0 4.40 L -80 STL Liner Details GAS LIFT, r Top Depth 4.036 (TVD) Top Inc' 50181 . Top MKS) (RKB) ( °) Item Description Comment ID (in) 7 ,730.2 6,523.1 98.96 ANCHOR ANCHOR 1.992 GAS LIFT, 4,940 8,526.8 6,467.4 98.440 -RING BTT0 -RING 1.992 Tubin. Strin.s Tubing Description String 0... String ID ...Tap (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PACKER.4.966 TUBING 31/2 I 2.992 27.0 6,684.4 6,041.4 I 9.30 L -80 EUE8rd it PATCH, 4,968 Completion Details Top Depth (TVD) Top Intl Noml... PACKER, 4.985 _ Top (B) (MB) ( °) Item Description Comment ID (In) let GAS LIFT. 27.0 27.0 -0.06 HANGER CAMERON GEN 4 TUBING HANGER 3.540 GASLIIFT. BM 557.6 557.6 0.21 NIPPLE CAMCO 'DS' NIPPLE w /NO GO PROFILE 2.875 6.136 GAS LIFT. 6,635.3 5,992.3 3.91 NIPPLE HES 'X' NIPPLE w/2.81" PROFILE 2.750 NIPPLE, 6,635 6,642.7 5,999.7 3.87 PBR BAKER '80 -40' PBR w /10' STROKE 2.992 PBR, 6,643 SEAL ASSY, 6,656.1 6,013.1 3.79 SEAL ASSY BAKER KBH -22 ANCHOR SEAL ASSEMBLY 3.000 PACKER. 6,657 6,657.0 6,014.0 3.79 PACKER BAKER SAB-3 PERMANENT PACKER 3.250 NIPPLE, 6,873 WLEO. 6.664 6,673.0 6,030.0 3.70 NIPPLE CAMCO 'D' NIPPLE 9CR w /NO GO PROFILE ***NIPPLE NOT 2.750 PRODUCTION, ACCESSIBLE DUE TO BEING COVERED BY 1D- 04L1 -02 UNER 30 -7,042 TOP*** Whipstock, 7,092 WINDOW - °' 6,683.9 6,040.9 3.64 WLEG WIRELINE ENTRY GUIDE. 2.992 AL1 -g2, 709 104. 11: Other In Hole Wireli retrievable plugs, valves, pumps, fish, etc.) Top Depth LINER -� - i l l l fiht p g p p 8 , ER ALI-02 - (TVD) Top Mel TOP, Top (ftKB) (ftKB) 8651 -7726 ) (1 Description Comment Run Date ID (In) slots 4.966 4,400.2 30.00 - ACKER UPPER WEATHERFORD ER PACKER 7/12/2010 1.750 7,726.8,560 LINER A. 4,969 4,402.7 29.93 - ATCH PATCH ASSY- SPACER PIPE & SNAP LATCH SEAL 7/12/2010 1.750 7,730 - 8.560 - ASSY OAL =20.7' TD (1004A), LINERALI - 02 4,985 4,416.7 29.51 - ACKER LOWER WEATHERFORD ER PACKER 7/5/2010 1.750 TOP, I 6,650.8,970 , 7,092 6,448.5 0.02 hipstock BAKER MONOBORE WHIPSTOCK CEMENTED IN PLACE 5/29/2008 0.000 LINER 911 -02, , - 6,651 -9,852 , 3 fl )'•T 3 " z r Perforations & Slots yi ,, ,I ' o. / L shot lki! Top (TVD) Btm (TVD) i i i ' Tap (ftKB) Btm (ftKB) (RKB Den. ) (RKB) Zone Date (s11... Type Comment ■ 7,726 8,560 6,523.8 6,462.0 6/13/2008 32.0 Slots Slotted Liner it, Notes: General & Safe �� ®' - Annotation 12/25/2002 NOTE: WAIVERED WELL: IA X OA COMMUNICATION ,11 6/21/2008 NOTE: Sidetrack KOP is 1 D- 04AL1 -02, A & all other laterals off this wellbore 1 i 1 4/28/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 NI i 111 _ IIj I t _ Mandrel Details Top Depth Top Port (TVD) Incl Valve Latch Size TRO Run Top (MB) (RKB) (1 Make Model Sere Type Type (in) (pal) Run Date 2,657.4 2,492.2 31.41 CAMCO KBUG GAS LIFT GLV BK 0.156 1,266.0 7/12/2010 4,035.9 3,640.3 36.57 CAMCO KBUG GAS LIFT OV BK 0.188 0.0 7/12/2010 _ © 4,949.4 4,386.0 30.43 CAMCO KBUG 111.1 GAS LIFT DMY : 0.000 0.0 6/17/2010 - -g.. 4,997.3 iii6ICAMCO KBUG 11111 GAS LIFT DMY 0.000 0.0 5/31/2000 - © 6,135.6 5,495.8 ilia CAMCO KBUG MI GAS LIFT DMY laill 0.000 0.0 5/31/2000 _ 6 6,558.2 5,915.4 4.16 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/4/2000 il 'ft • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 • August 9, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7`" Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: ~~ica ~[[~a~ ~C~, CL~-~~~~~~~t~~x 7'Sa~~i3°-~~s~.~t~i Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. wells 1D-04A (PTD 208-084). The report records the completion of the tubing patch installation and integrity test. Please call myself or Martin Walters at 659-7224 or MJ Loveland or Perry Klein at 659- 7043 if you have any questions. Sincerely, Brent Rogers Problem Well Supervisor Attachments ~A" c~ STATE OF ALASKA A KA OIL AND GAS CONSERVATION CO~ISSION REPORT OF SUNDRY WELL OPERATIONS t. Operations Performed: Abandon j"' Repair well ~ Plug Perforations ~ Stimulate (- Other ~ Tubing patch After Casing r Pull Tubing ~ Ft'rforate New Fbol r Waiver ~ Time Extension (- Change Approved Program ~""` Operat. Shutdow n r Perforate r Re-enter Suspended Well r 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory ~ 208-084 3. Address: Stratigraphic r Service (~ .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20416-01 7. Property Designation 8. Well Name and Nu~ber: ADL 025650 1 D-04A 9. Field/Pool(s): ,,~ Kuparuk River Field /Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 8560 feet Plugs (measured) None true vertical 6462 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 558, 6657 true vertical 0 feet (true verucal) 558, 6014 Casing Length Size MD TVD Burst Collapse CONDUCTOR 52 16 80 80' SURFACE 2861 10.75 2890 2690' PRODUCTION 7012 7 7042 6401' nn ~~~~~i.~ ,~~~;i=; ~ ~ ?01~; Perforation depth: Measured depth: 7726' - 8560' Slotted liner ~~BS~'3 ~t ~is~ ~ ~t1t1~N111SSI0Ci True Vertical Depth: 6534' - 6462' ~ ' `!~+ s,_sr :4~ Tubing (size, grade, MD, and TVD) 3.5, L-80, 6684 MD, 6041 TVD 22' Weatherford patch assembly from 4966' to 4988' Packers & SSSV (type, MD, and TVD) NIPPLE - CAMCO 'DS' NIPPLE W/NO GO PROFILE @ 558 MD and 558 TVD PACKER -BAKER SAB-3 PERMANENT PACKER @ 6657 MD and 6014 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 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 N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N!A N/A N/A 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory ~ Develop ent r Service r X 15. Well Status after work: ~ Gas ~ WDSPL r Daily Report of Well Operations GSTOR (! WAG ~ GASINJ ~ WINJ r SPLUG r 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: NIA contact Brent Rogers/Martin Walters Printed Name Brent Rogers Title Problem Well Supervisor Signature Phone: 659-7224 Date 08/09/10 RSDIIAS AUG 12 Form 10-404 Revised 7/2009 ~ g- IZ -~v Subrr~it~~gi ~OOnly i 1 D-04A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/04/10 07/12/10 07/31/10 Summary SET WEATHERFORD 3.5" BOTTOM PATCH PACKER AT 4988' CORRELATED TO LEAK DETECT LOG DATED 19 JUN 2010. CCL TO MID-ELEMENT OFFSET 14.7', CCL STOP DEPTH 4973.3'. SET (UPPER) 3 1/2 ER PACKER, SPACER PIPE AND SNAP LATCH ASSEMBLY (21.99' OAL) @ 4966' RKB. SET 3 1/2 ER TEST TOOL @ 4966' RKB. P.T. IA AND TBG. PULLED DV'S @ 2657' AND 4036' RKB. SET GLV @ 2657' AND OV @ 4036' RKB. PULL ER TEST TOOL @ 4966' RKB. COMPLETE TIFL POST PATCH (passed ), T/I/0= 219/1020/975. SI well and double blocked the lift gas, shot initial IA-FL @ 4036' station # 2 OV. Stacked T, T/I/0= 1000/1000/930. Bled IA, T/I/0= 1050/400/930. Shot second IA-FL @ same location. 30 min post bleed and final T/I/0= 1050/400/930. Set 22' Weatherford ER patch assembly from 4966' to 4988'. TIFL passed following patch set. • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 1D-04A Run Date: 7/4/2010 July 16, 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 1D-04A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20416-O1 ~~. ~ ~.w '~ i r' ~ 7 ,~} 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 rafael.barreto 1 ' o om ~, Date: iI1~~. ~ ~ %Q~G / ~=3 ~d3 Signed: ~ figs. firat~t~i~icx~ ~~cPu~:sP°A ~aa PROACTIVE DIAGNOSTIC SERVICES INC. • ^a~~ 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 following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report 2) 26-Jun-10 1 D-04A ~b~ ~~`~~ 1 Report / EDE ~ ~~~:~ 50-029-20416-01 .~ ~ ~ -, Signed Print Name: Date ~f }L ~ ~" ~~'' { g has . C~~r~aiit~n Arachr~r~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-awa : pdsarac9a~raae(c'Dmemor I~og.c®rat WEesn'E : w.onemorvlog.corn C:\Documents and Settings\Diane Williams\Desktop\Transmit_Cotroco.docx • • Memory Mult~Fnger Caliper LOg Results Summary Company: CanocoPhillips Alaska, Inc. Well: 1Q-04A Log Date: June 26, 2010 Field: Kuparuk Log No.: 7419 State: Alaska Run No.: 2 API No.: 50-029-20416-01 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8RD Top Log Intvl1.: Surface '~ Pipet Use: Tubing Bot. Log tntvl1.: 6,649 Ft. (MD} Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the X Nipple @ 6,635' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. An LDL (June 19, 2010) indicated a tubing leak at 4,982'. The caliper recordings across this interval indicate the tubing appears to be in good condition with respect to internal corrosive and mechanical damage. A 3-D log plot of the caliper recordings in the vicinity of the leak point is included in this report. The caliper recordings indicate the 3.5" tubing togged appears to be in good to fair condition with respect to internal corrosive and mechanical damage, with a maximum wall penetration of 27% recorded in joints 67 (2,056') and 124 (3,811'). Recorded damage appears as isolated pitting and general corrosion. No significant areas ofcross-sectional wall loss or I.D. restrictions are recorded throughout the tubing fogged. This is the second time a PDS caliper has been run in this well and the 3.5" tubing has been logged. A comparison of the current and previous log (April 16, 2008) indicates an increase in corrosive damage during the time between logs. A comparison plot depicting the differences in maximum recorded penetrations on a join#-by joint basis between the current and previous log is included in this report. MAXIMUM RECORDED WALL PENETRATIONS Corrosion (27%) Jt. 67 @ 2,056 Ft. (MD) Corrosion (27%) Jt. 124 ~ 3,811 Ft. (MD) Isolated Pitting (24%) Jt. 14 @ 436 Ft. (MD) Corrosion { 27%) Jt. 131 ~ 3,993 Ft. (MD) Corrosion (27°~,) Jt. 51 ~ 1,586 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross~ectional wall loss (> 10%) are recorded throughout the tubing logged. MAXIMUM RECQRDED ID RESTRICTIONS No significant i. D. restrictions are recorded throughout the tubing logged. L Field Engineer: Wm. McCrossan Analyst: M. Lawrence Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. j P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888} 565-9085 Fax; (281) 565-1369 E-mail: PDS umemoryiog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~o~s--fl~~ 19`~5~ • • PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1 D-04A Date : June 26, 2010 Description : Detail of Caliper Recordings Across Area Where LDL Indicated Leak at 4,982' Maximum Recorded Penetration ~'°'~ ~" Comparison To Previous Well: 1 D-04A Survey Date: )une 26, 2G ! U Field: Kuparuk Prev. Date: Apri116, 2008 ~ Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 24 Iv v. Z11 Country: USA Tubing: 3.5" 9.3 Ib L-80 EUE&~! Overlay Max. Rec. Pen. (mils) 0 50 100 150 200 250 0.1 10 19 29 39 49 59 ! 69 79 86.3 - 96 ~ 106 o Z 116 e ~ 126 133 - 143 153 160.3 170 180 187 197 204 211 ^June 26, 2010 ^April 16, 2008 Difference Diff. in Max. Pen. (mils) -100 -50 0 50 100 '- - - 4: t :;~ - 10 i9 29 39 49 59 69 79 86.3 9b ~ 106 0 Z 116 e 126 133 143 153 160.3 170 180 187 197 204 1211 -46 -23 0 23 46 Approz. Corrosion Rate (rnpy) • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (3.3' - 6643.1') Well: 1 D-04A Field: Kuparuk Company: ConocoPhiliips ,Alaska, Inc. Country: USA Survey Date: June 26, 2010 ® A pprox. Tool De viation ^ A pprox. Borehol e Profil e 7 755 152 9 2263 GLM 1 D 3063 ~ N + + 3812 v GLM 2 ~ 4593 GLM 3 5393 GLM 4 GLM 5 62 09 GLM 6 212.3 6643 0 5 0 1 00 Da mage Pr ofile (% tivall) / Tool D eviatio n (degr ees) Bottom of Survey = 212.3 1 25 50 ' 75 100 Z = 125 o 150 175 i 200 ~=:, ' • • PDS Report Overview ~~._ 5... Body Region Analysis Well: 1 D-04A Survey Date: June 26, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size; 1.69 Country; USA No. of Fingers: 24 Anal st: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 EUEBrd 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body metal loss body 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Nurnber of ~oints anal sed total = 226 pene. 0 100 115 11 0 0 loss 62 164 0 0 0 0 Damage Configuration (body ) 50 40 30 20 1O 0 isolated ;Pneral line ring hole/poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 78 33 45 0 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 n GLM 1 GLM 2 GLM 3 GLM 4 GLM 5 GLM 6 Bottom of Survev = 212.3 Analysis Overview page 2 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE8rd Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 1 D-04A Kuparuk ConocoPhillips Alaska, Inc. USA June 26, 2010 Joint No. Jt. Depth (Ft.) i'e~n. Ul~sr~t (Ins.) Pen. Body (Ins.) Pen. % Mrt,rl Loss "~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 3 U 0.02 ~t -t 2.88 PUP 1 7 0 0.01 4 3 2.93 - 2 40 U Q02 9 ? 2.91 3 71 ~? 0.02 ~> 1 2.90 4 103 O 0.02 Fi I 2.90 5 133 O 0.01 t! 2.91 6 161 O 0.01 I 2.92 - 7 193 U 0.02 F; ? 2.91 8 225 U 0.02 Lt 1 2.92 9 256 i) 0.02 9 1 2.91 10 288 wt 0.03 10 1 2.92 11 318 0 0.02 ~a _' 2.92 12 349 U 0.01 ~ 1 2.92 13 380 U 0.02 ~~ ,' 2.91 14 411 t) 0.06 2-1 i 2.90 Isolated ittin . 15 443 l) 0.01 ~ I 2.91 16 474 U 0.03 3 I 1 2.91 Shallow ittin . 17 505 U 0.01 ~~ 1 2.91 17.1 537 U 0 t? i) 2.88 Carnco'DS' Ni le w No Go Profile 18 538 t1 0.01 4 1 2.91 19 570 tt 0.01 6 1 2.91 20 601 U 0.03 11 2 2.91 21 632 t) 0.03 13 1 2.92 Shallow ittin . 22 663 O 0.04 1 5 ~' 2.91 Shallow ittin . 23 695 i r 0.03 1 _' 1 2.92 24 726 O 0.02 ~:~ I 2.88 25 755 U 0.03 11 1 2.91 26 786 O 0.03 11 2.92 27 815 U 0.03 1t) ~t 2.91 28 846 i) 0.02 2.92 29 878 U 0.03 12 2.91 30 909 t) O.D1 ~ ~' 2.92 31 941 t) 0.02 ;; I 2.91 32 972 O 0.02 i 1 2.91 33 1004 O 0.03 la U 2.91 Shallow ittin . 34 1035 (. 0.02 9 2 2.92 35 1067 l1 0.02 7 I 2.91 36 1098 (~ 0.02 ~; 2.91 37 1129 U 0.02 ~~ r 2.91 38 1161 U 0.02 ~, I 2.91 39 1192 U 0.02 t3 if 2.93 40 1222 t) 0.02 ~~ I 2.92 41 1252 U 0.03 13 1 2.91 Shallow ittin . 42 1284 i) 0.03 13 ~' 2.91 Shallow corrosion. 43 1315 l) O.D3 1I U 2.91 44 1345 U 0.03 11 2 2.92 45 1377 t? 0.02 `) ! 2.90 46 1408 i! 0.04 14 _' .91 Shallow ittin . 47 1440 t) 0.04 17 (~ 2.90 Shallow corr Sion. 48 1469 ~; 0.03 I1 2.90 _ Penetration Body Metal Loss Body Page "I PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE8rd Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: ELATION SHEET 1 D-04A Kuparuk Conoco Phillips Alaska, Inc USA June 26, 2010 Joint No. Jt. Depth (Ft.) Pen. I llriet (Ins.) Pen. Body (Ins.) Pen. ~;% Metal I osti °~, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 49 1499 tt 0.04 15 4 2.91 Shallow corrosion. 50 1529 tt 0.05 18 4 2.91 Shallow corrosion. Lt. De osits. 51 1557 i t 0.06 22 2.91 Corrosio_ n. Lt. De osits. 52 1587 U 0.04 1.5 2.91 Shallo ittin . 53 1616 a 0.04 14 _' 2.93 Shallow ittin . 54 1645 U 0.05 20 ') 2.92 Shallow corrosion. 55 1675 (t 0.05 1 ~) 7 2.92 Shallow corrosion. 56 1706 t? Q05 1 fi -3 2.92 Shallow corrosion. 57 1734 a 0.04 1 i ~t 2.92 Shallow ittin Lt De osits. 58 1763 U 0.04 I Ei 5 2.92 Shallow corrosion. Lt. De osits. 59 1793 (t 0.03 1 "3 5 2.93 Shallow ittin . Lt. De sits. 60 1823 (t 0.04 ? ' ~~ 2.91 Shallow corrosion. 61 1853 tt 0.04 I i +, 2.93 Shallow ittin . 62 1882 t) 0.05 2~J is 2.92 Corrosion. 63 1911 t) 0.04 14 -1 2.92 Shallow corrosion. 64 1940 tt 0.03 13 ~ 2.93 Shallow ittin - 65 1969 (t 0.04 17 5 2.90 Shallow corrosion. Lt. De osits. - 66 1998 (t 0.04 1 5 4 2.90 Shallow corrosion. - 67 2028 it 0.07 27 E~ 2.91 Corrosion. 68 2057 i) 0.03 13 ~ 2.93 Shallow ittin . 69 2086 (1 0.04 16 i~ 2.93 Shallow c rrosion. 70 21 16 i t 0.05 2i) ~ 2.92 Corrosion. 71 2145 !~ 0.03 17 2.94 72 176 !? 0.02 ~' 2.93 73 2205 t t 0.03 i I 2.92 74 2234 i) 0.06 2Z a 2.92 Corrosion. 75 2263 a 0.02 7 I 2.92 76 2294 tJ 0.05 18 G 2.93 Shallow corrosion. 77 2324 U 0.04 15 4 2.94 Shallow ittin . de osits. 78 2354 U 0.02 ts ~ 2.94 79 2385 a 0.03 11 2.91 80 2418 ct 0.02 '% 2.92 81 2449 t! 0.02 I .92 82 2481 t t 0.01 ] 2.92 83 2513 t r 0.02 ~ i 2.91 84 2 543 t ? 0.02 t3 1 2.94 85 2574 tt 0.03 10 1 2.91 86 2606 U 0.02 ~l ? 2.92 86.1 2638 t) 0.02 f~ 1 2.95 PUP ~ 86.2 2643 (1 0 i) t) N A GLM 1 Latch @ 11:00 86.3 2650 t? 0.03 1:3 ~' 2.89 PUP Shallow ittin . 87 656 ~~ 0.02 ~) _' 2.91 88 2688 tt 0.02 7 2.93 89 2718 U 0.03 13 1 2.90 Shallow corrosion. 90 2751 tt 0.02 8 1 2.91 91 2783 I~ 0.03 tt) 2.91 92 2814 t ~ 0.02 1 2.92 93 2846 U 0.01 ~~ 1 2.94 94 2877 ? 0.03 11 2 2.91 95 2909 tt 0.03 I1 L 2.92 _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 EUE8rd Well: Body Wall: 0.254 in Field: Upset Wall; 0.254 in Company: ~ti'ominal I.D.: 2.992 in Country: Survey Date: ELATION SHEET 1 D-04A Kuparuk Conoc-oPhillips Alaska, Inc. USA June 26, 2010 Joint No. Jt. Depth (Ft) Ne~n. lJl:u~? (Iii,.) Pen. Body (Ins.) Pen. `~~ Metal loss `;_~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 96 2940 O 0.03 I < ,' 2.91 97 2971 U 0.02 ~? 4 2.95 98 3001 U 0.03 I ~' ~ 2.92 99 3033 !' 0.03 I ~' 2.91 100 3063 t1 0.02 ~~ 2.92 101 3095 t) 0.03 1 i) 2.90 102 3124 U 0.02 t 2.95 103 3155 U 0.03 I1 a 2.93 104 3186 ti 0.03 I ~' 1 2.94 105 3216 l) 0.02 7 1 2.93 106 3247 i) 0.03 1 Z _' 2.90 107 3279 t? 0.03 i? 2.91 108 3310 U 0.04 15 I 2.93 Shallow ittin . 109 3341 t? 0.06 ?_' ~:~ 2.92 Corrosion. 110 3369 U 0.04 14 _1 2.92 Shallow ittin =~ 111 3398 U 0.05 it) (~ 2.91 Isolated ittin 112 3429 U 0.04 1 ~ - 2.92 Shallow ittin - 113 3459 t? 0.05 11 2.91 Corrosion. - 114 3488 U 0.04 1 7 t, 2.93 Shallow corrosion. 115 3518 U 0.03 13 '> 2.91 Shallow corrosion. Lt De osits. 116 3547 t) 0.05 2t) 4 2.92 Corrosion. ~~ 117 3576 (1 0.04 14 9 2.93 Shallow ittin . de osits. 118 3605 i) 0.05 2i) - 2.92 Shallow corrosion. 119 3635 !? 0.04 14 6 2.93 Shallow ittin Lt. De osits. 120 3664 t? 0.05 21 (, 2.94 Corrosion. 121 3694 ii 0.05 1'I '~ 2.93 Shallow corrosion. - 122 3722 U 0.06 ?' 2.91 Corrosion. Lt. De wits. 123 3752 I? 0,05 ?i) ( 2.92 Corrosion. Lt. De_osits. 124 3782 U 0.07 Z? t3 2.93 Corrosion. Lt De osits. 125 3812 t~ Q04 13 b 2.93 Shallow corrosion. 126 3842 f) 0.05 ~U 1l? .94 Shallow corrosion. 127 3873 t) 0.04 14 ~ 2.92 Shallow ittin . 128 3904 t? 0.03 11 2.94 129 3933 !> 0.04 13 is 2.92 Shallow corrosion. 130 3963 U 0.04 1 i; t> 2.92 Shallow corrosion. ; 131 3991 U 0.06 ~? 2.91 Corrosion. 131.1 4021 rt 0.02 is 2.93 PUN 131.2 4026 l) 0 i 1 ! ? N A GLM 2 Latch @ 10:00 131.3 4 33 (? 0.01 (: 2.95 PUP 132 4039 ~? 0.04 I -~ -; 2.93 Shallow corrosion. 133 4068 U 0.05 Zt) i 2.90 Corrosion. 134 4098 U 0.04 14 ~? 2.93 Shallow ittin _ 135 4128 t? 0.03 11 2.96 136 4158 t) 0.06 22 8 2.91 Corrosion. Lt. e osits. 137 4188 a 0.05 20 F3 2.92 Corrosion. 138 4218 t', 0.04 1 ? 2.9~ Shallow corrosion. 139 4247 ~ ~ 0.04 1 ? 2.90 Shallow corrosion. 140 4279 !? 0.03 1(? I 2.91 141 4311 t? 0.02 9 Z 2.95 ' 142 4342 i? 0.03 11 2.92 ~~ Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINTTABI. Pipe: 3.5 in 9.3 ppf L-80 EUE8rd Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal LD.: 2.992 in Country: Survey Date: • -LATION SHEET 1D-04A Kuparuk ConocoPhillips Alaska, Inc USA June 26, 2010 Joint No. Jt. Depth (Ft.) I'en. UI ~;c~i (ln~.) Pen. Body (Ins.) t'en. °lo ME~tal I oss `;~, Min. LD• (Ins.) Cornments Damage Profile (% wall) 0 50 100 143 4374 O 0.02 ~) 2 2.92 144 4405 t? 0.03 11 5 2.93 145 4436 (~ 0.02 7 1 2.93 46 4466 a 0.03 11 ? 2.93 147 4498 ~ ~ 0.03 I ? 1 2.93 148 452 9 U 0.02 f ~ 2.91 149 4561 U 0.02 cl 2.93 150 4593 U 0.01 G i 2.91 151 4624 U 0.02 9 I 2.93 152 4656 t) 0.03 11 I 2.91 153 4687 O 0.03 12 1 2.93 154 471 U 0.03 I [) I 2.92 155 4750 t) 0.01 b ti 2.93 156 4781 U 0.03 11 I 2.93 Lt. De osits. 157 4813 U 0.03 I i 2.93 158 4844 ~~ 0.02 ~~ 2.92 159 4876 ;t 0.03 1~' I 2.91 160 4907 U 0.03 12 3 2.93 160.1 4938 t} 0.02 7 2 2.93 PUP 160.2 4945 i~ 0 t; i~ N A GLM 3 Latc 02:30 160.3 4951 !? 0.01 c; -1 2.94 PUP 161 4957 U 0.02 £~ 2.93 162 4989 t~ 0.04 1-1 2.92 Shallow corrosion. 163 5020 (1 0.03 1 ~ 2.91 Shallow ittin t De osits. 164 5050 (~ 0.01 ( 2.93 165 5081 (~ 0.05 12i 2.92 Shallow corrosion. Lt. De osits. 166 5112 t I 0.02 ~s ~ 2.92 167 5144 ti 0,02 2.93 Lt De osits. ~ 168 5175 !? 0.03 I t ~ 2.92 Lt. De osits. _ 169 5207 t? 0.03 1I 2.9L 170 5238 tt 0.03 1? l .91 171 5269 U 0.02 tr ~ 2.92 172 5300 ! ? 0.02 ~ _' 2.90 173 5331 l1 0.02 t~ I 2.90 174 5362 c 1 0.03 1 ? I 2.90 175 5393 t? 0.03 11 4 2.94 176 5424 U 0.03 12 1 2.91 177 5456 U 0.02 7 1 2.93 178 5487 t~ 0.03 I ; I 2.92 Shallow ittin . 179 5519 ! } 0.02 7 I 2.92 180 5551 t) 0.03 Lt I 2.91 Shallow ittin 181 5580 0 0.02 I 2.93 181.1 5612 l) 0.02 t3 2.94 PUP 181.2 5617 tt 0 U tl N A GLM 4 Latch ~ 12:30 181.3 5624 ti 0.02 6 ~' 2.91 PUP 182 5630 U 0.03 13 ? 2.89 Shallow ittin . 183 5662 tt 0.03 1 3 2.88 Shallow ~ittin . 184 5693 ! I 0.02 ~) _' 2.90 185 5725 !' 0.02 `+ ~? 2.95 186 5756 0.02 ~~ +~ 2.90 _;y Penetration Body Metal Loss Body Page 4 i PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE8rd Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal LU.: 2.992 in Country: Survey Date: • iLATION SHEET 1D-04A Kuparuk ConocoPhillips Alaska, Inc, USA June 26, 2010 Joint No. Jt. Depth (Ft.) f'en. 11tri~~t (Inti.) Pen. Body (Ins.) Nc n. °,6 ~1et,il Loss `;~ Min. LD• (Ins.} Damage Profile Comments (%wall) 0 50 100 187 5788 rt 0.03 1 Z ? 2.91 188 5818 t) 0.02 - 2 2.91 189 5849 a 0.04 I ~~ 2.91 Shallow ittin . 190 5880 c? 0.02 ~> 2.90 191 5912 t? 0. 3 1 I 2.92 192 5943 Ci 0.03 1 _~ f 2.92 Shallow ittin . 193 5974 Li 0.03 1I .91 194 6005 l) 0.03 1,' 2.89 195 6035 ~) 0.02 ~_) 2.92 196 6065 O 0.03 12 2.90 197 6096 t t 0.03 1 1 ~' 2.93 197.1 6128 !! O.U2 tt ~ 2.95 PUP 197.2 6134 t) 0 U !) N A GLM 5 Latch ~ 8:00 197.3 6141 tt 0.02 6 2.90 PUP 198 6147 ;) 0.02 i Z 2.89 199 6177 t) 0.04 14 ? 2.92 Shallow ittin . 200 6209 t) 0.02 ~> 2.91 201 6239 t) 0.03 12 _' 2.93 202 6270 t) 0.03 1) 2.89 203 6302 ~) 0.03 11 3 2.92 204 6333 (t 0.03 1 3 2.90 Shallow ittin . 205 6364 U 0.02 7 2.9 206 6396 i t 0.04 1 5 .92 Shallow corrosion. 207 6427 O 0.03 i Z 2.92 208 6459 i) 0.02 _' 2.93 209 6489 {) 0.02 2.90 210 6520 t? 0.03 i i? ~+ 2.91 210.1 6552 t) 0.02 tS ~ 2.93 PUP ~ 10.2 6558 t? 0 (~ u N A GLM 6 No Deviation 210.3 6566 t) 0.02 ti 2.90 PUP 211 6572 tt 0.03 11 _' 2.89 212 6604 t t 0.01 ~ 2.91 212.1 6635 O 0 U l) 2.81 X Ni le w 2.81" Profile 212.2 6637 U 0.03 12 _' 2.94 PUP 212.3 6643 U {) a Z99 PBR _ Penetration Body Metal Loss Body Page 5 • • PDS Report Cross Sections •-_,5... Well: 1 D-04A Survey Date: June 26, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, fnc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 EUESrd Anal st: M. Lawrence Cross Section for Joint 124 at depth 3810.55 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Rernaining wall area = 95 °~° Tool deviation = 38 ° Finger 6 Penetration = 0.068 ins Corrosion 0.07 ins = 27% Wall Penetration HIGH SIDE = UP Cross Sections page 1 ~ PDS Report Cross Sections ~~ Well; 1 D-04A Survey Date: June 26, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 211387 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 93 f L-80 EUE8rd Anal st: M. Lawrence Cross Section for Joint 67 at depth 2055.77 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 94 °,~o Tool deviation = 32 " Finger 11 Penetration = 0.068 ins Corrosion 0.07 ins = 27% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ConocoPhillips aln ~., Irv. HANGER.! CONDUCTJR, 29-00 NIPPlE, 558 GAS LIFT 2,65] SURFACE, 252,890 GAS LIFT, 4 036 CAS LIFT, 4 949 GAS LIFT 5,620 GAS LIFT 6,136 \\\ GAS LIFT, 8,558 PLUG, 6,635 NIPPLE, 6635 PBR, 6,643 SEPL ASSV LINER AL 1-02 TOP, 6,851-112'0 slay. T,1zeaSeo LINER A, 7130 8 560 TD t1o-o»A), 6,560 LINER ALi-02 1 OP, S E50-8 910 LINER ALi-01, 6,651-9.852 1D-04 STL DUE TO (~1... LINER I I I !?"~! I ~^~ I I I oo I I valve I wmn I size Imortlnl I I WELL LOG TRAN5NTITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 1 D-04A Run Date: 6/19/2010 July 3, 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 1D-04A Digital Data in LAS format, Digital Log Image file 50-029-20416-01 1 CD Rom 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 Bivd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barre t, 31 3~ J ay .~i~ 4~" Date: ~a^ ~b~ -v `~5~'/ j9 LS~~ Signed: _ Regg, James B (DOA) Page 1 of 1 z~ - ~a- From: NSK Problem Well Supv [n1617@conocophillips.com] ~-~ ~~7fi~lo \ , ~~ Sent: ~ ' - ( Friday, June 04, 2010 1:54 PM To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 1 D-04A (PTD 208-084) Report of failed TIFL Follow Up Flag : Follow up Flag Status: Blue Attachments: 1 D-04A schematic.pdf Guy, Tom, Jim Kuparuk gas lifted producer 1 D-04A (PTD 208-084) failed a diagnostic TIFL on 06/03/10. The TIO prior to the test was 2 50/980/875. A leaking GLV is suspecfe Slickline will troubleshoot the leak and repair if possible. ~i- Attached is a schematic and 90 day TIO plot. ~ Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~ :~?.,}~,~~.: ~+1i, % ') Vii?! 8/20/2010 KRU 1D-04A PTD 2080840 June 4, 2010 TIn Pressure Plot CHOKE FTP - FTT IAP oaP T11/O Plot -1 D-04 200 1500 .................................................................................................................................................... ~ ~ 150 ~_-,.,------- ------- . - ---- ~---- ------ -~ -__ it - ; ~ a 1000 ......i,_..............IL...~~:....._ ..~...~~...........,, .... ............... ......................................... ........ a ~~ ' ~ I 100 + ~ ~ ~ I'~~ Y c i I aA ~ ~ s v 500 I 50 ~ ~ ~ :~ - o a 01-Apr-10 01-May-10 01-Jun-10 Date __ _ ,1---., ~ KUP ~ 1D-04A ~~ ,. .. ~OtIOCOPf1l~II~35 ~ ~ I - -- _ Max Angle & MD Well Attnbute s TD ~ _ _ _ W Ilb API/UWI F IdN n Well Status mall/ I.D(:°/.LL/ Aci Blm (ftK8) _ ~' ~ ~ 500292041601 KUPARUK RIVER UNIT PROD 105.46 7,460.33 8,560.0 -, C t H23 (ppm) Date Annotation End Date KBGrd (ft) Rig Release Date SSSV:Nlpple 75 827/2008 LastWO: 5/312000 38.99 6/21/2008 e'eiic_~eg 1DOtA,-~mrzgc~alasygr,~ sc - gctuei Annotation Depth (ftKB) End Date Annotation Last Motl By End Date _ _ _ _ _ Last Tag. Rev Reason: FORMAT UPDATE Imosbor - 7202009 _ Casing Strings -- - - Casing Descnpbon at wy v... String ID ... Top (kKB) Set Depth (f... Set Depth (ND) ... String Wt... Str ng ... String Top Thrd CONDUCTOR 16 15.062 28.0 80.0 80.0 65.00 H-40 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... S et Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 103/4 9.794 28.8 2,890.0 2,690.3 45.50 K-55 HANGER, 27 Casing Description String 0... String ID ... lop (ftKB) Set Depth (f... S et Depth (ND) ... String Wt... String ... String lop Thrd PRODUCTION 7 6.151 29.8 7,042.3 6,400.5 26.00 K-55 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... S et Depth (ND) ... String Wt... String ... String Top Thrtl _ _ ~ LINER 1D-04 5 4.151 6,345.0 7,099.0 6,455.3 14.87 K-55 ~,. '' Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... S et Depth (ND) ... String Wt... String ... Skiing Top Thrtl coNDUCroR. -. ~ WINDOW AL1-02 5 4 000 7,090.0 7,098.0 6 454.3 15.00 28-80 Casing Description Strrng 0... String ID ... Top (ftKB) Set Depth (f... S at Depth (ND) ... String Wt... String ... String Top Thrd ._ _! LINER ALI-02 TOP 23/8 1992 6,6507 7,726.0 6.523.8 4.50 L-80 STL NIPPLE, 558 ~ y ~ Llner D@ta11S _ Top Depth (TVD) Top Incl Top (ftKB) (ftKB) (°) It em Description Comment ID (in) GAS LIFT, ~ T r-~ 6,650.7 6,007.7 3.82 D EPLOY DEPLOYMENT SLEEVE 2.600 2,657 :,.~ _-..~ Casing Descripton String 0... String ID ... Top (ftKB) Sat Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd _ I WFR A 23/8 1.992 7.730.2 8,560.0 6.462.0 4,40 L-80 STL 6URFACE, 29-2 880 ~:. i {..Iner Detaii$ _ . F 7 M Top Depm ~~...~ (ND) lop Incl GAS LIFT, _~ r Top (ftKB) (ftKB) (°) It em Description Comment ID (in) °'0~ 7,730.2 6,523.1 98.96 A NCHOR ANCHOR 1.992 8,526.8 6,467,4 98.44 0-RING BTT 0-RING 1.992 ~ GAB LIFT, J _~ Tubin ' g Stnngs _ _ 4'~9 r ,,. ' _ _ Tubing Desc pt ~, St g O ~~.5[ring ID Top (kK8) Set D ptl (f.. Set D pth (NDI Striny Wt St -ng , String Top Thrd TUBING 3 1 2 ~._ 2.992 ~ 27 0 6 684 4 ~ 6,04L4 9.3~ L 80 I EUE8rd Gnsul'r ~• -~~- Com IetionD etails -- -- ~ --- , 5,620 a~ _ Top Depth ~ --- GA6LIFT, _ (ND) Top lncl GASL IFT To ftKB) (ftKB) (°) It em Deseri lion Comment ID (in) , sssa 6 635 NIPPLE _ 27.0 27.0 -0.06 H ANGER CAMERON GEN4 TUBING HANGER 3.540 , . PBR, 6,643 SEAL A ~ 557.6 557.6 0.21 N IPPLE CAMCO'DS' NIPPLE w/NO GO PROFILE 2.875 6.65fi 657 PACKER 6 ' 6,635.3 5,992.3 3.91 N IPPLE HES'X'NPPLE w2.81"PROFILE 2.750 , , NIPPLE, 6,673 6 fiB4 WLEG '. 6,642.7 5,999.7 3.87 P BR BAKER'80-40' PBR w/10' STROKE 2.992 , . PRODUCTION. 042 30-7 ~ ~ 6,656.1 6,013.1 3.79 S EAL ASSY BAKER KBH-22 ANCHOR SEAL ASSEMBLY 3.000 , Whipstock, 7 osz 6,657.0 6,014.0 3.79 P ACKER BAKER SAB-3 PERMANENT PACKER 3.250 , WINDOW 6,673.0 6,030.0 3.70 N IPPLE CAMCO'D' NIPPLE 9CR w/NO GO PROFILE "`NIPPLE NOT 2.750 Au-oz. ACCESSIBLE DUE TO BEING COVERED BY 1D-04L7-02 LINER 7,asoa,osa LINER 1 D-04, , TOP" 6,345-7,099 LINER ALI-02 TOP _ ~ 6,683.9 6,040.9 3.64 W LEG WIRELINE ENTRY GUIDE. - 2.992 , 6,651-7,726 stets, ' ~ -... _. - Other In Hole (Wireline - - _ ___ retrievable plugs, valves, pumps; fish, etc.) - - -- . 7,726-8.560 ~ Top Depth ~, 7,730-8,560 1 I (TVD) ' pl I'~ (hKB) To kK8 Top I I (I Description Com t Run Date ID (in D 04A, TD (1 8,550 092 6 448.5 7 0 02 W hipstock BAKER MONOBORE WHIPSTOCK CEMI '. I-D IN PLACE 5292008 0.000 LINERALi-02 ^9 - .., , , _._-. 1. __.__..__ _- .___-.._ _ - ....i TOP, ' 6.650b,970 Perforations $r Slots _ - - LINER AL7-02, -_._. _ _ __ _.. Shot 6.651-9,852 Top (ND) Btm (TVD) Dena Top (ftKB) Btm (ftK8) (ftK8) (ftKB) Zone Date (ski... Type Commerrt 7,726 8,560 6,523.8 6,462.0 6/13/2008 32.0 Slots Slotted Liner Notes: Gen eral & Safety ___ __ _ End Date __-_ _ Annotation 1225/2002 NOTE: WAIVERED WELL: IA X OA COMMUNICATION _ 6/212008 NOTE: Sidetrack KOP is 1D-04AL1-02, A & all other laterals off this wellbore 4/282009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 1• `I Mandrel Details Top Depth _ Top ___ _ PoA (ND) Incl OD Valve Lateh Size TRO Run Stn Top (ftKB) (ftK8) (°) Make Motlel tin) Serv Type Type tin) (psi) Run Date Com... 1 2,657.4 2,492.2 31.41 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,266.0 6242008 2 4,035.9 3,640.3 36.57 CAMCO KBUG 1 GAS LIFT OV BK 0.188 0.0 6/24/2008 3 4,949.4 4,386.0 30.43 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 526/2008 4 5,620.5 4,997.3 19.48 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/31/2000 ~', 5 6,135.6 5,495.8 9.63 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/312000 6 6,558.2 5,915.4 4.16 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/42000 y , DATA SUBMITTAL COMPLIANCE REPORT 2/8/2010 Permit to Drill 2080840 Well Name/No. KUPARUK RIV UNIT 1D-04A Operator CONOCOPHILLIPS ALASKA INC MD 8560 TVD 6462 Completion Date 6/21/2008 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-20416-01-00 UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surve Yes DATAINFORMATgN Types Electric or Other Logs Run: MWD DIR, GR, RES Well Log Information: Log/ Electr Data Digital Dataset (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / gyp rviea~rrma i~uniue~ name ~~a~e mcu~a rvv arar~ atop a.n rtecervra a.vnnnrnw D D Asc Directional Survey 0 8560 Open 8/12/2008 PBU 1 D-04AL1, PBU 1 D- 1 04AL1-01, i;<PBU 1D- ~ 04AL1-02 also on Disk D ~ C Lis 19033 I~ nduction/Resistivity 6959 8560 Open MPR logs plus PFD graphics og Induction/Resistivity 25 Col 7100 8560 Open 12/3/2009 MD MPR, GR Induction/Resistivity 5 Col 7100 8560 Open 12/3/2009 TVD MPR, GR Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~N Chips Received? °Y'7~ Analysis Y`t'1~ Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Y!,/ N Formation Tops ~N it Comments: DATA SUBMITTAL COMPLIANCE REPORT 2/8/2010 Permit to Drill 2080840 Well Name/No. KUPARUK RIV UNIT 1 D-04A Operator CONOCOPHILLIPS ALASKA INC MD 8560 TVD 6462 Completion Date 6!2112008 Completion Status 1-OIL Current Status 1-OIL ~. Compliance Reviewed By: API No. 50-029-20416-01-00 UIC N Date: r~ ~J •I • uzc v=c ConocoPhillias Alaska • RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wright, 907 263-4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk'`/ 333 West 7th Ave, Suite 100 in lieu of sepia** Electronic Anchorage, Alaska 99501 CGM /TIFF LIS BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk"/ David Douglas in lieu of sepia"* Electronic P.O. Box 196612 CGM /TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk*/ P.O.Box 196247 in lieu of sepia** Electronic Anchorage, Alaska 99519 CGM /TIFF LIS Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas 1 Disk*/ 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501-3510 LIS ~o~ -~ ~ t9A3a ~.. , w ~ ~~ ~` ao~-o~G/ !9 ~3 DEC ~ 3 2009 app-(~~"~o l 9 b3~ ~lask~ Uil ~ t~~s G®r,~ ~;pr~:~issi~r~ ~nchcr~Qc ~o~' ~o~l ~ 9 b 35_ ~p~_ ~ ~c~ I ~i~3 ~ ~ ~ ~~~~ BAKER Ht~1~1~1ES INTEL 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: August 08, 2008 Please find enclosed directional survey data for wells: 1 D-04A a. ~ ~ ~ ~ ~ ~ 1 D-04AL 1 1 D-04AL 1-O l 1 D-04AL 1-02 1D-12L1PB1 1D-12L1 1 D-12L2 Enclosed is: 1 ea 3.5" floppy diskette containing electronic survey file Cc: State of Alaska, AOGCC Christine Mahnken STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~ it fi 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC 25.105 2oAAC zs.~,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ~ 1b. Well Class: 008 ~(~j~ r~~~rr~ent ^ Exploratory ^ Servlc ~~~~ ~, tr a hic 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., orAband. 06/21/2008 ' iilY>y~.. 12. Permit to " 208-084 - 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 6/6/2008 13. API Number 50-029-20416-01-00 ' 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 6/9/2008 ~ 14. Well Name and Number: Kuparuk 1D-04A 120 FNL, 598 FEL, SEC. 23, T11N, R10E, UM. Top of Productive Horizon: 1793' FSL, 2430' FWL, SEC. 13, T11 N, R10E, UM 8. KB (ft above MSL): 105' ~ Ground (ft MSL): 15. Field /Pool(s): Kuparuk River Unit /Kuparuk Total Depth: 1799' FSL, 2484' FWL, SEC. 13, T11 N, R10E, UM 9. Plug Back Depth (MD+TVD) 8560' 6462' River Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 560490. y- 5959545 'Zone- ASP4 Surface: x- 10. Total Depth (MD+TVD) '8560' 6462' - 16. Property Designation: ADL 025650 - _ TPI: x- 563501 y- 5961483 Zone- ASP4 Zone- ASP4 Total Depth: x- 563555 ~ y- 5961490 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: _ 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): ,1400' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): '~ ~ 7/O ~ MWD DIR, GR, RES 6~~ r~D 22. CASING, LINER AND CEMENTING RECORD ?, (p. CASING SETTING: DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 2-3/8" 4.44# L-80 7730' 8560' 6523' 6462' 3" Uncemented Slotted Liner 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, IISt each I (MD+TVD of Top & Bottom; Pe nten/al Open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-3/8" Slotted Section Note: 3-1/2", 9.2#, J-55 6729' 6657' MD TVD MD TVD 7741 ~ - 8527 6521' - 6467 Well Branch Well Branch 1 D-04A 1 D-04A 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Departs From Is not Directly DEPTH INTERVAL MD AMOUNT Si KIND OF MATERIAL USED Well Branch Accessible 04AL1 1 D 02 - - PTD # 208-101 at 7727' MD ' (6524 TVD) 26. PRODUCTION TEST Date First Production: Reported on 1 D-04AL1-02 Method of Operation (Flowing, Gas Lift, etc.): See 1 D-04AL1-02 (Dated xxx, PTD # 208-101) for Production & Test Data Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No ' Sidewal l Cores Ac wired? ^Yes ®No' If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None 0 R I G ~~~`~'~ INAL V£R Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE 7~r8; 0` R V ~~~~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS RKERS ENCOUNTERED): 29. FORMATION TESTS NAME D TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Kuparuk C4 7105' 6461' None Kuparuk B Shale 7248' 6578' Kuparuk B Shale (Inverted) 7501' 6570' Kuparuk C4 (Inverted) 8505' 6470' Kuparuk D Shale (Inverted) 8560' ~ 6462' Formation at Total Depth (Name): Kuparuk D Shale 8505' 6470' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore ing is true and correct to the best of my knowledge. O u/ ~ ~/ ` Q~ Signed Terrie Hubble Title Drilling Technologist Date Kuparuk 1 D-04A 208-084 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Mel Rixse, 564-5620 Permit No. / A royal No. INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 16 Operations Summary Report -_ Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/3/2008 05:30 - 07:30 2.00 MOB P PRE Plck up rig mats and clean up around cellar area. Conduct pre move inspection of hydraulic systems. Inspect well area with CPF-2 DSO. 07:30 - 11:00 3.50 MOB P PRE Move from 2D pad to 2X pad entrance. 11:00 - 12:30 1.50 MOB P PRE Stand by for Kuparuk crew change. 12:30 - 14:45 2.25 MOB P PRE Move to 1 R access road 14:45 - 19:00 4.25 MOB P PRE Wait for SSA flights and then Field crew changeout 19:00 - 22:00 3.00 MOB P PRE Move from 1 R access road to 1 D pad. 22:00 - 22:30 0.50 MOB P PRE Move rig onto pad & down to 1 D-04. 22:30 - 23:00 0.50 MOB P PRE Wait for AES to finish rigging up MPD valuing. PJSM regarding moving over well. Shut in adjacent well. 23:00 - 00:00 1.00 MOB P PRE Spot rig over well. 6/4/2008 00:00 - 05:30 5.50 RIGU P PRE Rig accepted at 00:00. Level rig. Bring on boiler water. Order out 2% KCL with 2ppb Biozan milling fluid. Nipple up ROPE &MPD loop, (tree is crooked!). Rig up IA, OA & WHP gauges & crash frames. Rig up SSV &MPD SV hydraulic lines & function test same. Tighten tree bolts, found 3 loose studs. Spot tiger tank & rig up hardline. Spot cuttings box. Rig up Handy Berm around cellar. Rig up lubricator. Spot satellite camp & rig up BHI wires & main power cable. Off load miscellaneous rig equipment. MU BHI coil track tools for milling BHA on catwalk & test same. Get BOP stack measurements. Grease mud cross valves. Function test BOP's. 05:30 - 07:30 2.00 BOPSU P PRE FiII BOP stack with cold water. Perform shell test on BOP stack 07:30 - 12:20 4.83 BOPSU P PRE Test BOPE and MPD loop to 250/3500 w/ AOGCC in attendance 12:20 - 15:30 3.17 BOPSU N PRE Choke line HCR would not test. Rebuild, retest and failed 15:30 - 21:00 5.50 BOPSU N PRE Replace, grease & actuate. Retest -pass. Replaced gray lock seal on choke line HCR & test -pass. Fill coil with biozan. 21:00 - 21:45 0.75 BOPSU P PRE P.T. tiger tank line with 120psi of air & 400psi of fresh water - good. 21:45 - 22:00 0.25 RIGU P WEXIT PJSM regarding coil slack management & cutting coil. 22:00 - 22:40 0.67 RIGU P WEXIT PU injector & cut off coil connector. Prep a-line cable. Stab onto well. 22:40 - 23:15 0.58 BOPSU P WEXIT P.T. inner reel valve & injector packoffs per AOGCC regs 250/3500 psi -Pass. 23:15 - 23:30 0.25 RIGU P WEXIT Pump slack. Pop off well & check for wire. 23:30 - 23:40 0.17 RIGU P WEXIT PJSM regarding pulling BPV. 23:40 - 00:00 0.33 RIGU P WEXIT Hoist Cameron BPV lubricator to RF & RU same to pull BPV. 6/5/2008 00:00 - 01:15 1.25 RIGU P WEXIT Stab BPV lubricator onto well. P.T. 250/2000psi. Open master valve w/ 1500psi & let equalize, 450psi WHP. Recovered 3"'H' style BPV. Rig down Cameron lubricator. 01:15 - 04:15 3.00 RIGU P WEXIT Rig up coil cutter & cut 54ft of coil. Dress end of coil. MU Kendal CTC. Open well to Tiger tank & bleed off from 450psi to Opsi. Pull test to 30k -good. Head up BHI. Replace flow sub. Pressure test to 4000psi -good. 04:15 - 04:30 0.25 RIGU P WEXIT PJSM regarding making up BHA. 04:30 - 05:45 1.25 RIGU P WEXIT Flow check well. MU milling BHA. Stab onto well. Power up & test tools. Set depths. 05:45 - 07:00 1.25 STWHIP P WEXIT RIH with milling BHA, taking returns to Tiger tank. Circ thru EDC 0.8/1040 07:00 - 08:30 1.50 STWHIP P WEXIT Set down at 6738' CTD. Close EDC. Mill cement stringer from Printed: 6/30/2008 9:32:34 AM BP EXPLORATION Operations Summary Report Page 2 of 16 Legal Well Name: 1 D-04 Common Well Name: 1D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/5/2008 07:00 - 08:30 1.50 STWHIP P WEXIT 6738-6743' CTD 1.48/2750 and ream area twice, clean. Precaufionary ream 1.5/2585 at 25'/min to WS. Tag at min rate at 7108.0' and did not correct PVT 261 08:30 - 11:30 3.00 STWHIP P WEXIT PU 21.5k start motor 1.5/2600 Ease in hole to first MW and four stalls at 7107.70' with corresponding overpulls which is the assumed pinch point. Park at 7107.67' for 30 min and let CT straighten out (7.5k hanging wt). Begin time milling from 7107.7' ~ 11:30 - 15:45 4.25 STWHIP P WEXIT Mill from 7109.30' 1.52/2730 w/ 100 psi dill, 0.4k wob w/ 10.21 ECD after swap to pump #2 to replace swab in pump #1 PreSpud mtg 15:45 - 17:45 2.00 STWHIP P WEXIT Mill from 7112.2' (calc and probable BOW) 1.51/2910 w/ 100-200 psi dill, 2.0-2.5k wob w/ 10.22 ECD. Drilled very slow and had incr in dill at 7114.1', but was probably a siderite streak. Drilled formation to 7122'. Bottom's up was 90% formation sand, 5% siderite, 5% metal. 17:45 - 20:15 2.50 STWHIP P WEXIT Ream and backream window area 3 times. Dry run through window, tag up at 7109ft. Clean PU. Set down at 7107ft. Clean PU. Pump at 0.5bpm & got through with no weight bobbles. Work area. Dry tag at 7107ft. clean PU. Stop pumping & set 2k down, start pumping. Stalled after 2 min. 5k overpull. Work area. Dry tag at 7107ft, spin bit past & dry tag at 7122ft. 20:15 - 21:15 1.00 STWHIP P WEXIT Open EDC & swap well to 8.9ppg flo-pro. 5K overpull at 6745ft. Jet 7" casing. 21:15 - 21:30 0.25 STWHIP P WEXIT Flow check while at 6540ft - no flow. 21:30 - 22:40 1.17 STWHIP P WEXIT Continue to POH. PJSM regarding handling milling BHA while POH. 22:40 - 23:45 1.08 STWHIP P WEXIT Flow check well - no flow. Pop off well. Attempt to blow down tools with no luck. Lay down 2-3/8" drill collars. Mill was 2.73" no-go. Heavy scarring on face of mill caused from junk on the whipstock tray, resulting in the mill to be flat on the bottom. Recovered 2 large pieces of metal jammed in 2 of the 3 jets. Metal is serrated on one side, dished on the other side & off the top of the whipstock, eureka! 23:45 - 00:00 0.25 STWHIP N WEXIT Make up milling BHA consisting of 2.73" no-go Weatherford crayola tip mill and 2.73" string reamer. 6/6/2008 00:00 - 00:35 0.58 STWHIP N WEXIT Continue to make up window dressing BHA. C/O UOC o-rings. 00:35 - 02:00 1.42 STWHIP N WEXIT RIH with window dressing mill. 02:00 - 02:40 0.67 STWHIP N WEXIT Log down for tie-in from 6980ft (-12ft corr. 02:40 - 02:55 0.25 STWHIP N WEXIT RIH & dry tag twice at 7099ft. 02:55 - 04:15 1.33 STWHIP N WEXIT PU to 7095ft. Start pumping at 1.5bpm/2830psU10.37 ECD. Mill at 30ft/min from 7095ft to 7110ft with slight motor work at 7095ft. Divert bottom's up to tiger tank (oil). PU to 7085ft. Dry tag bottom at 7112ft, clean through the window. PU to 7085ft & ream one more time through the window. Run through window dry -clean. 04:15 - 05:55 1.67 STWHIP N WEXIT POH. PreSpud mtg while POH. 05:55 - 06:45 0.83 STWHIP N WEXIT Flow check. Crew chg/safety mtg 06:45 - 07:30 0.75 STWHIP N WEXIT Set injector on legs. LD milling BHA 07:30 - 08:45 1.25 DRILL N PROD1 BHI reconfigure the BHA for drilling and test Nordic begin changeout of pulsation dampener on pump #1 08:45 - 09:30 0.75 DRILL N PROD1 WO Nordic to fin pump #1 repair work 09:30 - 10:15 0.75 DRILL N PROD1 BHI noticed the well was beginning to flow over the lubricator Printed: 6/30/2008 9:32:34 AM BP EXPLORATION Page 3 of 16 Operations Summary Report Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To 'Hours Task Code NPT 6/6/2008 09:30 - 10:15 0.75 DRILL N 10:15 - 10:30 0.25 DRILL N 10:30 - 12:00 1.50 DRILL N 12:00 - 13:30 1.50 DRILL N 13:30 - 15:45 2.25 DRILL N 15:45 - 16:30 0.75 DRILL N 16:30 - 17:15 0.75 DRILL N 17:15 - 18:30 1.25 DRILL N 18:30 - 18:35 0.08 DRILL N 18:35 - 18:45 0.17 DRILL N 18:45 - 19:15 0.50 DRILL N 19:15 - 19:50 0.58 BOPSU N 19:50 - 20:05 0.25 DRILL P 20:05 - 21:15 1.17 DRILL P 21:15 - 22:40 1.42 DRILL P 22:40 - 23:00 0.33 DRILL P 23:00 - 23:05 0.08 DRILL P 23:05 - 00:00 0.92 DRILL P Spud Date: 6/1 /2008 Start: 5/30/2008 End: 6/21 /2008 Rig Release: 6/21/2008 Rig Number: Phase Description of Operations i PROD1 stub and driller recorded a 0.1 bbl gain. SI B/S rams and monitor pressure. After 30 min whp was 80 psi Nordic fin pulsation dampener replacement PROD1 Safety mtg re: MU nozzle assy PROD1 BHI reconfigure BHA. Close lower swab and bleed off 105 psi whp. MU nozzle BHA and had short in MWD LOC. Change it out and test okay. PT lub to 500 psi. Open swab to 115 psi whp PT pulsation dampener for pump #1 and leaked at factory MU flange PROD1 RIH w/ BHA #3 circ thru nozzle 0.35/835 holding 200 psi whp Safety mtg re: RD pulsation dampener Discuss future SIMOPS w/ Nordic 3 on D-122 w/ CPAI planner & Drlg Supv PROD1 Park at 7080' CTD Circ out crude influx w/ 8.9 ppg Flo Pro 1.25/2100 w/ 300 psi induced whp. Take 30 bbls of 7.45 ppg retums to tiger tank w/ BU at 8.3 ppg PVT 132 Second circ, incr rate to 1.60/2930 and bring retums inside at 8.9 ppg while hold 200 psi whp PVT 132 Third circ 1.6/2650 w/ open choke. Continue to circ while wo KWF Add 100 bbls of 8.9# mud to 118 bbls 9.5# mud on vac truck Remove pulsation dampner and find bladder had been baked inside rendering it useless PROD1 Add 100 bbls of 8.9# mud to 118 bbls of 9.5# mud on vac truck Find out that injection wells 1 C-10, 1 D-02, 1 D-05, 1 D-09, 1 D-10 and 1 D-11 are on line. 1 C-10 is the most likely culprit injecting 2000 bwpd in this fault block. The CPF-1 Engr had it SI PROD1 Start 9.25# Flo Pro 1.61/2600 Begin to install new bladder in old pulsation dampener PROD1 POOH circ 1.52/2350 while finish displacing wellbore to 9.25# mud. PROD1 Notified Chuck Scheve at AOGCC of taking a kick & shutting in blind rams due to well flowing. PROD1 Flow check well - no flow. PROD1 Blow down & lay down BHA & reconfigure same for drilling build BHA. Clean out high pressure screen in reel house -lots of goodies inside. PROD1 Pressure test blind rams & choke line & HCR per AOGCC regs, 250/3500psi -PASS. PROD1 PJSM regarding handling drilling BHA & making drift run of BHA with slickline. PROD1 MU build BHA. Deploy BHA conventionally into well using tugger with great difficulties. Stab onto well. Set counters. Power up & test tools. PROD1 RIH. Slight bobble at the D nipple. PROD1 Log down for tie-in from 7000ft (-18ft corr. PROD1 RIH, slight bobble at 7108ft in the window & tag bottom at 7112ft. PROD1 Drilling build with great difficulties from 7,112 ft to 7,123ft. With TF at HS Op 1.5/1.4 bpm at 3000 psi off bottom psi Printed: 6/30/2008 9:32:34 AM BP EXPLORATION Page 4 of 16 Operations Summary Report ---- - -- - - - -- - -- - Legal Well Name: 1 D-04 Common Well Name: 1D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To I Hours I Task Code NPT ~ Phase Description of Operations i 6/6/2008 23:05 - 00:00 0.92 DRILL P PROD1 Density = 9.07 / 9.35 ppg DHWOB = 0.8k to 1.5k. Vp = 453 bbl BHP /ECD /WHP = 3,612psi / 10.98ppg / 29psi 6/7/2008 00:00 - 02:30 2.50 DRILL P PROD1 Drilling build from 7,123ft to 7,160ft. With TF at HS Op 1.5/1.35 bpm at 3000 psi off bottom psi Density = 9.05 / 9.14 ppg DHWOB = 0.8k to 1.5k. Vp = 445 bbl BHP /ECD /WHP = 3,620psi / 10.93ppg / 29psi Build rate is 55 degrees/100ft -too high. 02:30 - 04:00 1.50 DRILL P PROD1 POH for 2 deg AKO motor. 4k overpull at window. PUH to 7080ft & open EDC & flow check - no flow. MWout = 9.1 ppg & BHP = 3050psi at the window. PJSM while POH regarding handling BHA. Lost 7 bbls on trip OOH. 04:00 - 04:45 0.75 DRILL P PROD1 Flow check - no flow. Pop off well. Short chain BHA & break off motor. Dial down motor to 2 deg AKO. Stab on well. Power up & test tools. Set counters. 04:45 - 06:30 1.75 DRILL P PROD1 RIH with 2 degree AKO build BHA. 06:30 - 07:10 0.67 DRILL P PROD1 Log tie-in down to GR marker at 7000', corr -12'. Close EDC. RIH thru window, clean at min rate. Log tie-in down to RA pip in WS for tie-in to mother wellbore 07:10 - 09:40 2.50 DRILL P PROD1 Drill from tag at 7160' 1.53/1.46/3100/1 R w/ open choke w/ 100-300 psi dill, 0.5-1.5k wob w/ 11.1 ECD at 10-40'/hr to 7245' where P rate slowed down which is near expected top of B Shale 09:40 - 11:40 2.00 DRILL P PROD1 Drill from 7245' 1.51/1.49/3140/258 w/ 100-300 psi dill, 0.8-1.8k wob w/ 10.96 ECD to 7300' and have 73 deg at bit 11:40 - 12:00 0.33 DRILL P PRODi Wiper to window was clean both ways 12:00 - 14:40 2.67 DRILL P PROD1 Drill from 7300' 1.51/1.46/3230/208 w/ 200-400 psi dill, 1.0-2.4k wob w/ 10.99 ECD while finish the build and land at 7345' (6498' TVD) at 90 deg. Continue invert to 7401' w/ 104 deg at bit 14:40 - 15:30 0.83 DRILL P PROD1 Wiper to window was clean. Pull thru window, open EDC. POOH jetting to 6700' 1.8/3300. RBIH jetting to window. Switch to 10.8# Flo Pro mud 15:30 - 16:00 0.50 DRILL P PROD1 Circ KWF mud to bit 16:00 - 17:20 1.33 DRILL P PROD1 POOH while displace wellbore to KWF 17:20 - 19:20 2.00 DRILL P PROD1 LD build assy. Reconfigure tools with resistivity. MU lateral section BHA with 1 deg AKO motor -tools went smooth into well with tugger. Swap 5ft lubricator for Oft lubricator. Get new deployment numbers. Power up & test tools. Set counters. 19:20 - 20:40 1.33 DRILL P PROD1 RIH with lateral BHA. Bleed down IA from 550psi (gas) to 100psi, OA is not traking. Open EDC & start swapping coil to 9.1 pg flo-pro while RIH. 20:40 - 21:00 0.33 DRILL P PROD1 Log down for tie-in from 7015ft (-15ft corr). 21:00 - 22:00 1.00 DRILL P PROD1 RIH to 7100ft & swap well to 9.1ppg Flo-Pro while slowly PUH to reduce losses. Attempt to hold 500psi on choke while closing EDC. Slowly bled down while RIH through the window. 22:00 - 22:10 0.17 DRILL P PROD1 Wiper to TD. Turn on centrifuge 'A' & gun lines. Tag bottom at 7401ft. 22:10 - 00:00 1.83 DRILL P PROD1 Drill invert from 7,401ft to 7,489ft. With TF 90-1808 Op 1.7/1.58 bpm at 3720 psi off bottom psi Printed: 6/30/2008 9:32:34 AM BP EXPLORATION Page 5 of 16 ~ Operations Summary Report - -- Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase ~ Description of Operations 6/7/2008 122:10 - 00:00 I 1.831 DRILL I P 6/8/2008 00:00 - 03:05 ~ 3.08 ~ DRILL ~ P PROD1 Density = 9.20 / 9.45 ppg DHWOB = 0.8k to 1.5k. Vp = 350 bbl BHP /ECD /WHP = 3,820psi / 11.55ppg / 40psi Continue drilling invert from 7,489ft to 7,550ft. With TF 90-1808 Op 1.7/1.62 bpm at 3720 psi off bottom Density = 9.28 / 9.35 ppg DHWOB = 0.8k to 3.5k Vp = 347 bbl BHP /ECD /WHP = 3,915psi / 11.65ppg / 40psi W iper to 7,410ft. Log MAD pass up from 7,410ft to 7,110ft at 300ft/hr. Wiper to TD. Drill invert from 7,550ft to 7,700ft. With TF 90-1808 Op 1.7/1.62 bpm at 3850 psi off bottom Density = 9.25 / 9.33 ppg DHWOB = 0.8k to 3.5k Vp = 335 bbl BHP /ECD /WHP = 3,927psi / 11.71 ppg / 40psi Bleed down OA from 600psi to 200psi (gas & fluid). Wiper to window was clean both ways PVT 318 Drill from 7700' 1.64/1.60/3650/1008 w/ 200-400 psi dill, 1.5-2.5k wob w/ 3897 psi dhp=11.67 ECD at 100 deg in the C2/C3 interface area. Drill to 7850' Wiper to window was clean. Pull thru window. Open EDC and jet solids out of the liners 1.74/3200 to EOT at 6700'. RBIH to 7000' Log tie-in to GR at 6996', corr +5'. Close EDC Wiper back to TD was clean PVT 305 Drill from 7850' 1.62/1.60/3670/908 w/ 200-400 psi dill, 1.0-3.Ok wob w/ 11.72 ECD at 95 deg in the C3. Swap to left at 7900'. Drill to 8000' W iper to window was clean both ways PVT 299 Drill from 8000' 1.55/1.51/3420/85L w/ 100-300 psi dill, 1.0-2.5k wob w/ 11.65 ECD at 93 deg in the C3 at 80-100'/hr. Get into siderite streaks from 8040' and have 3.Ok wob w/ +2k string wt. Point TF 10L at 8075' after it appears that siderite has stopped the inversion and are at 92 deg. Resume drilling in good sand w/ 1.Ok wob and 6k surface wt at 120'/hr and get back to 95 deg. Drill to 8150' Wiper to window Drill lateral from 8,150ft to 8,300ft. With TF 90L-100L Op 1.6/1.57 bpm at 3850 psi off bottom Density = 9.28 / 9.34 ppg DHWOB = 0.8k to 2.5k Vp = 284 bbl BHP /ECD /WHP = 3,950psi / 11.93ppg / 40psi Wiper to the window -clean. Stop pumping & trap 350psi, PUH through window -clean & open EDC. PUH while jetting 5" liner & 7" casing to 3.5" tubing at 6680ft. Log down for tie-in (+6ft). Close EDC. W iper to TD -clean. Conduct mud swap to 8.6ppg PROD1 03:05 - 03:15 0.17 DRILL P PROD1 03:15 - 04:10 0.92 DRILL P PROD1 04:10 - 04:25 0.25 DRILL P PROD1 04:25 - 06:40 2.25 DRILL P PROD1 06:40 - 07:15 0.58 DRILL P PROD1 07:15 - 09:00 1.75 DRILL P PRODi 09:00 - 09:50 0.83 DRILL P PROD1 09:50 - 10:05 0.25 DRILL P PROD1 10:05 - 10:30 0.42 DRILL P PROD1 10:30 - 12:30 2.00 DRILL P PROD1 12:30 - 13:30 1.00 DRILL P PROD1 13:30 - 16:40 3.17 DRILL P PROD1 16:40 - 17:40 1.00 DRILL P PROD1 17:40 - 20:10 2.50 DRILL P PROD1 20:10 - 21:45 1.581 DRILL I P I PROD1 21:45 - 21:55 0.17 DRILL P PROD1 21:55 - 22:35 0.67 DRILL P PROD1 Panted: wsorzoos s:sz:aa Ann BP EXPLORATION Page 6 of 16 Operations Summary Report Legal Well Name: 1 D-04 __ Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/8/2008 21:55 - 22:35 0.67 DRILL P PROD1 while RIH. Lost DC power to pumps & traction motor ~ 8249ft while RIH. 22:35 - 00:00 1.42 DRILL N RREP PROD1 Trouble shoot SCR problem. PJSM regarding pumping with Hot Oil. RU Hot Oil. P.T. to 4000psi. Begin pumping 8.6ppg Flo-pro down coil while holding 100psi WHP. 6/9/2008 00:00 - 01:30 1.50 DRILL N RREP PROD1 Trouble shoot SCR room. Start SLB traction motor & move pipe -clean PU. Continue to swap well to 8.6ppg, bottom's up was uneventful. Slowly PUH to 7900ft & discuss with rig electricians. Possible overheat situation on DC board. Will need to replace 4-12 volt batteries that supply DC side of SCR room next time OOH - 2hrs to replace. Swap to rig pumps. RD Hot Oil truck. RIH with coil. 01:30 - 04:30 3.00 DRILL P PRODi Drill lateral from 8,300ft to 8,450ft. With TF 908-1108 Op 1.7/1.68 bpm at 3350 psi off bottom Density = 8.75 / 8.78 ppg DHWOB = 0.8k to 2.Ok Vp = 327 bbl BHP /ECD /WHP = 3,677psi / 11.34ppg / 30psi 04:30 - 06:15 1.75 DRILL P PROD1 Wiper to the window & to TD was clean. Slow wiper at end while geo's decide strategy-will shoot the moon and look for D shale PVT 275 06:15 - 09:10 2.92 DRILL P PROD1 Drill from 8450' 1.53/1.50/3080/408 w/ 100-400 psi dill, 1.0-3.5k wob w/ 11.05 ECD at 94 deg and target the top of the C4/D Shale interface in this fault block. Spend and hour at 8505-12' in siderite. Drill to 8527' and find another one 09:10 - 10:25 1.25 DRILL P PROD1 Drill from 8527' 1.66/1.63/3250/708 w/ 100-200 psi dill, 1.5-3.5k wob w/ 11.15 ECD at 98 deg. Drill to 8550' and see 182 api rock on GR. Geo confirms 10-12' TVD feet before planned TD 10:25 - 10:35 0.17 DRILL P PROD1 100' wiper was clean PVT 270 10:35 - 11:10 0.58 DRILL P PROD1 Drill from 8550' 1.60/1.57/3100/608 w/ 100-300 psi dill, 1.5-3.2k wob w/ 11.20 ECD at 99 deg. Drill to 8556' 11:10 - 12:30 1.33 DRILL P PROD1 Slow wiper while geo checks sample. Call this deep enough. Continue wiper to window, clean. Pull thru window, clean. Open EDC and jet solids out of liners 1.76/2710 to EOT at 6700'. RBIH to 7000' 12:30 - 12:55 0.42 DRILL P PROD1 Log tie-in to cased hole marker at 6996', Corr +9'. Close EDC 12:55 - 14:20 1.42 DRILL P PROD1 Wiper back to TD was clean to wt loss starting at 8525'. Ream to 8540' and set down. Overpull and backream w/ more overpulls and MW to 8490'. Ream back in hole to TD tagged at 8560'. Backream again to 8490' and was clean. Ream to TD, clean and confirm 8560' TD 14:20 - 15:10 0.83 DRILL P PROD1 Wiper OOH leaving 2 ppb Alpine beads in open hole 15:10 - 16:40 1.50 DRILL P PROD1 POOH thru window and circ 10.8# Flo Pro to surface while POH 16:40 - 17:15 0.58 DRILL P PROD1 LD drilling BHA Send BTT to Deadhorse to put together an anchored WS 17:15 - 19:00 1.75 DRILL N RREP PROD1 Fill hole. SI swabs. SD rig power to replace batteries for ESD. Found loose & dirty wires. Start your engines! Let there be light! 19:00 - 19:25 0.42 DRILL P PROD1 PJSM regarding RU liner handling equipment & testing mud pump #1. 19:25 - 20:00 0.58 DRILL P PROD1 RU Farr tongs. RU 2-3/8" flat top elevators. MU TIW to 2" Printed: 6/302008 9:32:34 AM BP EXPLORATION Page 7 of 16 Operations Summary Report --- --- - _ - Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/9/2008 19:25 - 20:00 0.58 DRILL P PRODi safety joint. Open swabs & top off well -2bbls to fill hole. Reconfigure BOT tools for orientor on the catwalk, test same. HOT failed to test, C/O HOT & reprogram tools. 20:00 - 20:35 0.58 DRILL N WAIT PROD1 Wait for BOT to bring OH anchor assembly. 20:35 - 23:00 2.42 CASE P LNRi MU liner per program. RD Farr tongs. PU & injector, check CTC & stab onto BHI tools. Stab onto well. Power up & test tools. Set counters. 23:00 - 00:00 1.00 CASE P LNRi Top off hole - 3bbls. RIH w/ liner ~ 75ft/min. 6/10/2008 00:00 - 01:50 1.83 CASE P LNR1 RIH w/liner. WT ck at window = 22k & 11k RIW. Set 1k down at 7,269ft, clean PU. Orientate past, tag up at 7,274ft, clean PU. Log down for tie-in (-16ft corr. WT ck at 8,550ft = 23k & 8.8k RIW. Tag at 8,558ft. Orientate single slip at 160R. PU to neutral WOB. Pressure to 3900psi & set anchor. Set 2k down - holding. Clean PU, 21 k. 01:50 - 02:30 0.67 CASE P LNR1 POH filling across the top. 02:30 - 03:00 0.50 CASE P LNR1 Discrepancy in trip sheet. Stop at 5500ft EOP & flow check - no flow. Pump down coil, 4bbls, fluid fell out of coil. Crisis averted. 03:00 - 03`50 0.83 CASE P LNR1 POH pumping down coil at min rate. PJSM while POH regarding handling BHA. 03:50 - 04:00 0.17 CASE P LNR1 Tag up. Flow check - no flow. 04:00 - 05:15 1.25 CASE P LNR1 Pop off well. Short chain tools OOH. LD setting tool. Hoist up 2 new motors. Perform bi-weekly function test of BOPE per AOGCC regs. MU sidetrack BHA. MU coil to tools. Stab onto well. Power up & test tools. Set counters. 05:15 - 06:35 1.33 STWHIP P PROD2 Open EDC. RIH with sidetrack BHA. Swap coil to 8.6ppg Flo-Pro at min rate while RIH. 06:35 - 07:00 0.42 STWHIP P PROD2 Log tie-in down to GR marker at 6996', Corr -14'. Close EDC 07:00 - 07:30 0.50 STWHIP P PROD2 Wiper to top of liner while fin circ out KWF 07:30 - 08:30 1.00 STWHIP P PROD2 Tag billet at min rate at 7728'. Make two down passes from 7715' 1.55/1.53/2940/160L 08:30 - 10:10 1.67 STWHIP P PROD2 Time drill sidetrack from first MW at 7727.40'. Drill to 7729.30' stacked 3k and stalled? PU and had high circ press 1.35/3650. Assume either aluminum, motor rubber or trash in jets 10:10 - 10:30 0.33 STWHIP P PROD2 200' wiper while clearing jets, new parameters 1.53/3160 10:30 - 12:30 2.00 STWHIP P PROD2 Attempt to drill ahead slowly, but continue to stack wt and stall to 7731.3'. Acts like bit is balled up w/ aluminum since can stack 5k w/ little MW. Backream to shuck 12:30 - 13:40 1.17 STWHIP P PROD2 Get off and drill from 7731.3' 1.55/1.54/3120/160L w/ 100-200 psi dill, 1.0-1.5k wob w/ 10.96 ECD. Bring TF up from 7745' to 120E and drill to 7765' which should be far enough to meet targets PVT 301 13:40 - 14:30 0.83 STWHIP P PROD2 Ream and backream billet area 30L and 30R of DTF and was clean 14:30 - 15:00 0.50 STWHIP P PROD2 Wiper to window was clean 15:00 - 16:30 1.50 STWHIP P PROD2 Open EDC. POOH circ thru EDC 1.62/2800 following pressure schedule. 16:30 - 16:45 0.25 STWHIP P PROD2 PJSM regarding pressure undeploying side track BHA. 16:45 - 18:30 1.75 STWHIP P PROD2 Pressure undeploy BHA. Crew change, PJSM 18:30 - 22:15 3.75 STWHIP P PROD2 Pressure undeploy BHA. Bit had 1 plugged jet with aluminum. Change motor AKO, PU USR tool held PJSM and pressured deployment of BHA 22:15 - 23:35 1.33 DRILL P PROD2 RIH to 7,015 ft Printed: 6/30/2008 9:32:34 AM a BP EXPLORATION Page 8 of 16 Operations Summary Report Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: ~ Description of Operations Date From - To Hours Task Code NPT Phase 6/10/2008 23:35 - 23:50 0.25 DRILL P PROD2 Tie in at 7,015 ft and corrected -16 ft 23:50 - 00:00 0.17 DRILL P PROD2 Closed EDC and RIH with min Op through the build section and the OHST 6/11/2008 00:00 - 00:26 0.43 DRILL P PROD2 RIH and tagged bottom at 7765 ft 00:26 - 02:27 2.02 DRILL P PROD2 Drilling lateral TF at 170E HS Op = 1.57 / 1.58 bpm OBP = 3600 psi BHP /WHP = 3650 / 33 psi Density = 8.97 / 9.01 ppg Vp = 282 bbl's ROP at 60-9 fph API at 70 Units 02:27 - 02:36 0.15 DRILL P PROD2 Wiper trip to 7780 ft. Turned TF to R-side once back on bottom 02:36 - 04:40 2.07 DRILL P PROD2 Drilling lateral TF at 90R HS Op = 1.61 / 1.60 bpm OBP = 3445 psi BHP/WHP=3678/33 psi Density = 8.97 / 9.01 ppg Vp = 279 bbl's Drilled into something hard at 7,900 ft ROP at 16 fph. Finally worked through wheras the ROP increased to 90 fph. 04:40 - 05:05 0.42 DRILL P PROD2 Wiper trip, clean 05:05 - 07:15 2.17 DRILL P PROD2 Drilling lateral TF at 90R HS Op = 1.61 / 1.60 bpm OBP = 3445 psi BHP/WHP=3678/33 psi Density = 8.97 / 9.01 ppg Vp = 282 bbl's Drilled to 8200ft. 07:15 - 09:25 2.17 DRILL P PROD2 Wiper to window -clean. Stop pumping & pull through window - clean. Open EDC & jet 5" liner & 7" casing to 3-1/2° tubing at 6684ft & back down to 7030ft. Tie-in +3.5ft. Stop pumping & close EDC. Run through window -clean. Pump min rate through build section -clean & no pumps through billet area - clean. Wiper to TD -clean. 09:25 - 11:10 1.75 DRILL P PROD2 Drilling lateral TF at 90R HS Op = 1.7 / 1.65 bpm OBP = 3800 psi BHP/WHP=3790/44 psi Density = 9.02 / 9.05 ppg Vp = 285 bbl's Drilled to 8350ft. 11:10 - 11:55 0.75 DRILL P PROD2 Wiper to 7780ft and to TD -clean both ways. 11:55 - 13:45 1.83 DRILL P PROD2 Drilling lateral TF at 90L HS Op = 1.7 / 1.69 bpm OBP = 3850 psi BHP/WHP=3815/44 psi Density = 9.02 / 9.03 ppg Vp = 284 bbl's Drilled to 8500ft. 13:45 - 14:45 1.00 DRILL P PROD2 Wiper to 7780ft and to TD -clean both ways. 14:45 - 17:10 2.42 DRILL P PROD2 Conduct mud swap Drilling lateral TF at 90L HS Op = 1.82 / 1.80 bpm OBP = 3300 psi BHP/ WHP/ECD=3578/37 psi/10.57 Density = 8.65 / 8.73 ppg Vp = 47 bbl's Drilled to 8650ft. Printed: 6/30/2008 9:32:34 AM • • BP EXPLORATION Page 9 of 16 Operations Summary Report Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date ~ From - To Hours Task Code NPT ~ Phase Description of Operations 16/11/2008 117:10 - 19:15 I 2.081 DRILL I P 19:15 - 20:04 0.82 DRILL P 20:04 - 21:50 1.77 DRILL P 21:50 - 00:00 I 2.171 DRILL I P 6/12/2008 00:00 - 00:15 0.25 DRILL P 00:15 - 00:40 0.42 DRILL P 00:40 - 01:50 1.17 DRILL N 01:50 - 02:30 0.67 DRILL N 02:30 - 03:45 1.25 DRILL N 03:45 - 06:15 2.50 DRILL P 06:15 - 07:45 1.50 DRILL P 07:45 - 11:20 3.58 DRILL P 11:20 - 13:10 1.83 DRILL P 13:10 - 14:00 0.83 DRILL P PROD2 Wiper trip to the window. 8602ft, 6k overpull. Pulled above WS and open EDC. PUH pumping at max flowrate to 6600 ft and clean out the 5-1/2" casing. RIH at max rate and log tie at 7015 ft. Corrected +6 ft. Closed EDC PROD2 RIH, clean. PROD2 Drilling lateral TF at 90R HS Op = 1.82 / 1.80 bpm OBP = 3300 psi BHP / WHP /ECD = 3629 / 50 psi / 10.79 Density = 8.65 / 8.73 ppg Vp = 182 bbl's PROD2 Wiper trip while repairing cable to MWD shack. Nordic 3 started its move to 1 D Pad. Working on repairing the communications. RIH andwill use the Geosurvey directional spreadsheet from the Geologist. Placed the DD in the MWD shack and will drill using the direction spreadsheet instead of the Wellbore Architect software of BHI that is presently in question to drill the well. Without the spreadsheet would be shut down waiting on the cable coming from Deadhorse PROD2 RIH and setup to drill with the geo's spreadsheet from the MWD trailer PROD2 Drilling lateral TF at 90R HS from MWD shack Op = 1.70 / 1.70 bpm OBP = 3170 psi BHP/ WHP/ECD=3629/50 psi/10.79 Density = 8.65 / 8.69 ppg Vp = 375 bbl's WAIT PROD2 Wiper to casing to allow Nordic 3 to pass by the reel house on 1 D Pad WAIT PROD2 Open EDC at 7050 ft and Nordic 3 drove past the reel house with very little to spare. PU to 6,600 ft circulating at 2.21 bpm. RIH to 7015 ft at 75 fpm and Op = 2.21 bpm. Logging tie in, corrected Closed EDC WAIT PROD2 RIH with correct TF, no Qp through WS and low Op through build section. PROD2 Drilling lateral TF at 90R HS Op = 1.70 / 1.70 bpm OBP = 3170 psi BHP / WHP /ECD = 3629 / 40 psi / 10.79 Density = 8.65 / 8.69 ppg Vp = 367 bbl's Drilled to 8950ft. PROD2 Wiper to 7780ft and to TD -clean both ways. PROD2 Drilling lateral TF at 90R HS Op = 1.70 / 1.68 bpm OBP = 3250 psi BHP/ WHP/ECD=3620/40 psi/10.79 Density = 8.71 / 8.72 ppg Vp = 365 bbl's Drilled to 9100ft. PROD2 Wiper to 7780ft and to TD - 5k overpull at 9012ft & 8980ft, otherwise clean. Slight set down at 9012ft PROD2 Drilling lateral TF at 90R HS Op = 1.70 / 1.68 bpm OBP = 3250 psi BHP/ WHP/ECD=3620/40 psi/10.79 Density = 8.71 / 8.72 ppg Nnnteo: wsazuua a:u::w AM ' • BP EXPLORATION Page 10 of 16 Operations Summary Report --- - -- -_ Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ~ Task Code NPT Phase Description of Operations 6/12/2008 13:10 - 14:00 0.83 DRILL P PROD2 Vp = 412 bbl's Drill to 9130ft. 14:00 - 14:20 0.33 DRILL P PROD2 Stacking out, PUH, very ratty & 10k over pulls. Lots of set downs at 9100ft to 9125ft. Stack out on bottom with no motor work. PUH & work area. 14:20 - 16:10 1.83 DRILL P PROD2 Drilling lateral TF at 75R HS Turned TF to Left at 9200 ft Op = 1.70 / 1.68 bpm OBP = 3350 psi BHP/ WHP/ECD=3620/33 psi/10.86 Density = 8.71 / 8.80 ppg Vp = 412 bbl's Drill to 9250ft 16:10 - 20:35 4.42 DRILL P PROD2 Wiper to window. 5k overpull at 8,977ft. Above WS, open EDC and cir at max rate to 6,600 ft. WSL had 1 hr meeting with RLG. RIH and tied in and corected. Closed EDC and RIH with correct TF and flow rates. Tagged bottom at 9,255 ft 20:35 - 23:35 3.00 DRILL P PROD2 Drilling lateral TF at 60L HS Op = 1.70 / 1.68 bpm OBP = 3350 psi BHP/ WHP/ECD=3697/33 psi/11.09 Density = 8.71 / 8.80 ppg Vp = 387 bbl's ROP slowing down due to siderite. 23:35 - 00:00 0.42 DRILL P PROD2 Wiper trip to OHST 6/13/2008 00:00 - 01:30 1.50 DRILL P PROD2 Finish RIH on wiper trip 01:30 - 04:15 2.75 DRILL P PROD2 Drilling lateral TF at 90L HS Op = 1.70 / 1.68 bpm OBP = 3350 psi BHP/ WHP/ECD=3697/33 psi/11.09 Density = 8.71 / 8.80 ppg Vp = xxx bbl's ROP slowing down due to siderite or possible shale. RU to conduct mud swap. Non routine mud swap on Nordic 2 with Nordic 3 on location. Started mud swap (867 ft) at 03:20 hrs / 9,368 ft. 04:15 - 07:30 3.25 DRILL P PROD2 POOH. Open EDC at 7080 ft and circulated at max rate. PUH to 6600 ft, RIH to 7015 ft and tied in corrected +8ft, closed EDC. Wiper to TD. 07:30 - 07:35 0.08 DRILL P PROD2 Tag bottom at 9372ft. 07:35 - 09:40 2.08 DRILL P PROD2 Wiper to window. Start pumping 10.8ppg KWF down hole while POH. 09:40 - 10:25 0.75 DRILL P PROD2 Open EDC & circulate well to 10.8ppg. 10:25 - 10:35 0.17 DRILL P PROD2 Flow check. 10:35 - 11:50 1.25 DRILL P PROD2 POH. PJSM while POH regarding handling BHA & MU liner. 11:50 - 12:00 0.17 DRILL P PROD2 Close EDC & flow check. 12:00 - 13:00 1.00 CASE P LNR2 Blow down & LD BHA, motor was weak & bit was 2-2 BT. RU 2" safety joint. RU Farr tongs. 13:00 - 14:30 1.50 CASE P LNR2 MU liner. MU setting tool to liner. MU BHI tools to setting tool & scribe same. MU coil to BHI tools. Stab injector onto well. Power up & test tools. Set counters. 14:30 - 15:10 0.67 CASE P LNR2 RIH with liner. RIH to 3100ft & problems with DPS. 15:10 - 17:00 1.83 CASE N DFAL LNR2 POH pumping across the top. 17:00 - 17:45 0.75 CASE N DFAL LNR2 Pop off well. LD tools. Found problem. Replace EDC & test tools. MU to liner. Stab onto well. 17:45 - 19:15 1.50 CASE P LNR2 RIH. to 7240 ft 19:15 - 19:30 0.25 CASE P LNR2 Tie in at 7240 ft / 7015 ft. corrected . Wt chec = 22.5k up at 15 Printed: 6/30/2008 9:32:34 AM BP EXPLORATION Page 11 of 16 Operations Summary Report Legal Well Name: 1 D-04 Common Well Name: 1D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/13/2008 19:15 - 19:30 0.25 CASE P LNR2 fpm RIH 19:30 - 20:30 1.00 CASE P LNR2 RIH and tagged at 9373 ft. PU and flood vac line. 20:30 - 20:35 0.08 CASE P LNR2 Pump and set anchor at 3600 psi. Liner set at 9373 ft Top of Liner at 9139 ft 20:35 - 23:15 2.67 CASE P LNR2 PUH filling across the top 23:15 - 00:00 0.75 CASE P LNR2 LD CoilTrac and BOT CTLRT. 6/14/2008 00:00 - 00:50 0.83 STKOH P PRODS Circulate across wellhead. PJSM and RU to cut CT 00:50 - 02:30 1.67 STKOH P PRODS Cutting off 975 ft 2" CT for coiled tubing management. 02:30 - 03:30 1.00 STKOH P PRODS RD cutter and seal cable end. Rev cir and unable to move cable. Switch fluids around and displaced CT with 8.6 ppg flo-pro for slack management 03:30 - 05:00 1.50 STKOH P PRODS Circulating and even with the 8.6ppg flopro no wire movement. Removed 10.8 ppg from pits and lined up to load Pit 5 with freash water Line up and displace the CT with fresh water at 3 bpm. Popped off no wire movement. Back on well and try once move to get wire to move. Wire will not move 05:00 - 05:15 0.25 STKOH P PRODS Pad Evaluation with Nordic Screw. Muster up at the N3 camp and all people accounted for in 3 minutes. 05:15 - 07:30 2.25 STKOH P PRODS Pop off well and installed CTC, pull test to 40k and reheaded. Pressure test to 4000 psi -good. 07:30 - 07:35 0.08 STKOH P PRODS PJSM regarding handling BHA. 07:35 - 08:15 0.67 STKOH P PRODS MU 1.5 AKO motor to BHI tools. MU coil to BHI tools. Stab onto well. Set counters. Power up & test tools. 08:15 - 09:50 1.58 STKOH P PRODS RIH. 09:50 - 10:00 0.17 STKOH P PRODS Log down for tie-in (-15.5ft corr. 10:00 - 10:45 0.75 STKOH P PRODS Swap well to 8.6ppg Flo-Pro. Stop pumping & close EDC. 10:45 - 11:55 1.17 STKOH P PRODS W iper to TD. Dry tag billet at 9137ft. 11:55 - 12:25 0.50 STKOH P PRODS Trough 3 times from 9118ft to 9136.5ft TF at 160R HS Op = 1.56 / 1.56 bpm CTP = 2760 psi BHP/ WHP/ECD=3759/26psi/11.24 Density = 8.72 / 8.91 ppg Vp = 199 bbl's 12:25 - 15:35 3.17 STKOH P PRODS Drill at O.ift/min from 9136.5ft TF at 160R HS Op = 1.56 / 1.56 bpm CTP = 2760 psi BHP/ WHP/ECD=3759/26 psi/11.24 Density = 8.72 / 8.91 ppg Vp = 199 bbl's 15:35 - 17:05 1.50 STKOH P PRODS Drill formation from 9140ft TF at 160R HS Op = 1.65 / 1.63 bpm CTP = 3260 psi BHP/ WHP/ECD=3759/30 psi/11.36 Density = 8.81 / 8.86 ppg Vp = 390 bbl's Drill to 9155ft & NBI confirms LS KO. 17:05 - 18:00 0.92 STKOH P PRODS Ream & backream 45-60 degrees L & R of drilled TF from 9118ft to 9155ft. 18:00 - 20:30 2.50 STKOH P PRODS POH following pressure schedule. 20:30 - 20:45 0.25 STKOH P PRODS PJSM on undeploying BHA 20:45 - 22:20 1.58 STKOH P PRODS Pressure undeploy BHA 22:20 - 23:00 0.67 STKOH P PRODS Change out MWD and reset motor AKO from 1.5 to 1.0 deg. Cleaned out rock catcher with big holes. Fixed leak on the koomey line and SLB changed packoff. 23:00 - 23:10 0.17 STKOH P PRODS PJSM on Pressure deploying BHA Printed: 6/30/2008 9:32:34 AM BP EXPLORATION Page 12 of 16 Operations Summary Report ------ Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task .Code NPT Phase Description of Operations 6/14/2008 23:10 - 00:00 0.83 STKOH P PRODS Pressure deploying BHA 6/15/2008 00:00 - 00:30 0.50 DRILL P PRODS Finish pressure deploying BHA 00:30 - 02:00 1.50 DRILL P PRODS RIH with EDC open 02:00 - 02:22 0.37 DRILL P PRODS Log tie in at 7015 ft, Corrected -22 ft 02:22 - 03:55 1.55 DRILL P PRODS RIH, tagged bottom at 9156 ft 03:55 - 08:00 4.08 DRILL P PRODS Drilling lateral TF at 165R Op = 1.60 / 1.60 bpm OBP = 3070 psi Density = 8.75 / 8.80 ppg BHP /EDC /WHP 3685 psi / 10.97 ppg and 30 psi Work bit slowly to get started Drilled to 9300ft. 08:00 - 10:05 2.08 DRILL P PRODS Wiper to 7780ft & to TD -ratty at 9155ft, otherwise clean. 10:05 - 14:05 4.00 DRILL P PRODS Drilling lateral from 9300ft TF at 90-80R Op = 1.75 / 1.75 bpm OBP = 3760 psi Density = 8.78 / 8.80 ppg BHP /EDC /WHP 3820 psi / 11.45 ppg and 33 psi Lost resistivity for 25ft. Drilled to 9450ft. 14:05 - 14:20 0.25 DRILL P PRODS PUH to 9430ft. MAD pass up from 9430ft to 9395ft. 14:20 - 16:40 2.33 DRILL P PRODS Wiper to 7780ft. 1 k overpull at 9322ft. Slowly PUH through side track area to help open it up. Clean to 7780ft. Wiper to TD, minor set down at 9147ft & 9328ft. 16:40 - 19:45 3.08 DRILL P PRODS Drilling lateral from 9450ft TF at 125-80R Turned TF to 120R at 9,504 ft to extend the path. Made 200 ft wiper at crew change Op = 1.70 / 1.70 bpm OBP = 3,580 psi Density = 8.81 / 8.84 ppg BHP /EDC /WHP 3800 psi / 11.44 ppg and 50 psi Drilling with -3k to -6.5 k CTW ROP 10-30 fph 19:45 - 20:24 0.65 DRILL P PRODS Wiper to billet, just stacking wt MAD pass 9525 to 9550 ft 20:24 - 23:00 2.60 DRILL P PRODS Drilling lateral from 9550ft Op = 1.70 / 1.70 bpm OBP = 3,580 psi Density = 8.84 / 8.86 ppg BHP /EDC /WHP 3854 psi / 11.57 ppg and 55 psi Drilling with -3k to -6.5 k CTW ROP 10-30 fph 23:00 - 23:25 0.42 DRILL P PRODS Mini wiper, stacking 23:25 - 00:00 0.58 DRILL P PRODS Drilling lateral from 9642ft Op = 1.70 / 1.70 bpm OBP = 3,580 psi Density = 8.84 / 8.86 ppg BHP /EDC /WHP 3894 psi / 11.69 ppg and 33 psi Drilling with -3k to -6.5 k CTW ROP 10-30 fph 6/16/2008 00:00 - 02:55 2.92 DRILL P PRODS Drilling ahead. Oriented TD to 180deg (LS) and go find out where we are at in regards to geology to the C3. W iper trip at 9715 ft CTW at -6.7k 02:55 - 05:00 2.08 DRILL P PRODS Drilling lateral from 9715ft Op = 1.70 / 1.65 bpm OBP = 3,580 psi Density = 8.84 / 8.86 ppg BHP /EDC /WHP 3894 psi / 11.69 ppg and 33 psi Drilling with -3k to -6.8 k CTW ROP 5-40 fph Vp = 241 bbl Lost 51 bbl in this shift 05:00 - 05:40 0.67 DRILL P PRODS Drilling ahead looking for the C3. Drilled to 9,795 ft and called TD. 05:40 - 08:30 2.83 DRILL P PRODS Wiper to window -clean. Stop pumping &PUH through window Printed: 6/302008 9:32:34 AM • ~~ BP EXPLORATION Page 13 of 16 Operations Summary Report Legal Well Name: 1 D-04 Common Well Name: 1D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT 6/16/2008 05:40 - 08:30 2.83 DRILL P 08:30 - 09:15 0.75 DRILL P 09:15 - 11:10 1.92 DRILL P 11:10 - 12:45 1.58 DRILL P 12:45 - 14:50 2.08 DRILL P 14:50 - 16:05 1.25 DRILL P 16:05 - 17:00 0.92 DRILL P 17:00 - 20:30 3.50 CASE P 20:30 - 22:00 1.50 CASE P 22:00 - 22:45 0.75 CASE N SFAL 22:45 - 23:00 0.25 CASE P 23:00 - 23:25 0.42 CASE P 23:25 - 00:00 0.58 CASE P 6/17/2008 00:00 - 02:15 2.25 CASE P 02:15 - 03:00 0.75 CASE P 03:00 - 10:20 7.33 BOPSU P 10:20 - 10:25 0.08 STWHIP P 10:25 - 11:20 0.92 STWHIP P 11:20 - 12:35 1.25 STWHIP P 12:35 - 12:45 0.17 STWHIP P 12:45 - 13:35 0.83 STWHIP P 13:35 - 14:40 1.08 STWHIP P 14:40 - 15:20 0.67 STWHIP P 15:20 - 17:20 2.00 STWHIP P 17:20 - 17:30 0.17 STWHIP P Phase Description of Operations PROD3 -clean. Open EDC & jet 5" liner & 7" casing to 6600ft. PROD3 Log for tie-in +26ft correction. Stop pumping & close EDC. PROD3 Wiper to TD. Pump liner pill with 2ppb Alpine beads while wipering to TD. Check last 3 sunryes. Set down at 9758ft. Tag TD twice at 9810ft. PROD3 POH laying in liner pill keeping 3600psi BHP. PROD3 Slowly PUH while pumping 10.8ppg KW F from window to surface. Flow check - u-tubing. RIH to 7075ft & circulate some more. Flow check - no flow. PROD3 POH. PJSM while POH regarding handling BHA. PROD3 Tag up. Flow check - no flow. Pop off well. Blow down tools. Break BHI tools in three segments. LNR3 PJSM regarding making up liner. MU 2" safety joint & lift nubbin. C/O elevators. Hoist liner equipment to RF. Ran liner as per programme PU Billet and Coiltrac. Confirmed scribe. PU injector LNR3 Testing tool and RIH with liner Set down at 6,856 ft (6,033 ft slips). PU RIH Looks like the counter is 290 ft off. The 6,856 ft tag (7,146 ft) LNR3 Work CT and check the injector counter. Pull up into to casing and change counter out on injector head. LNR3 RIH with new counter Stopped at 7835 ft LNR3 Log tie in. Corrected 259.5 ft on the BHI counter and 33 ft on the SLB following the 894 ft BHA correction to the UDAC and 4 ft correct on the mechanical counter LNR3 RIH tagged at 9800 ft PU Wt = 25.2k Set shoe at 9807 ft with 1280 ft wt down. Confirm orient at 165 LHS to single slip. Pump dow CTwith closed EDC and pressured up to 4,500 psi SD pumps and tool set. 12 k down on tool. LNR3 POOH with liner running tools LNR3 LD Coiltrac and BOT CTLRT PROD4 BOP Test, 250psi/3500psi. Bob Noble with AOGCC wavered witness the BOP test. Retest lower 2" combi's. Pressure test injector packoffs & inner reel valve. ALL PASSED. FiII hole 2bbls to fill hole. PROD4 PJSM regarding handling sidetrack BHA. PROD4 Install check valves in UOC. MU sidetrack BHA. Stab onto well. Power up & test tools. Set counters. PROD4 Open EDC. Slowly circulate coil to 8.6ppg while RIH. PROD4 Log down for tie-in (-12ft corr. PROD4 Slowly PUH & swap well to 8.6ppg Flo-Pro. Close EDC. PROD4 Wiper to TD -clean. Dry tag billet twice at 8972.5ft. PROD4 Trough 3 times from 8971 ft to 8945ft. PROD4 Drill off AI billet at 8972 ft at 155R TF WOB 1.7 to 0.5 klbf off the billet at 8,975 ft Op = 1.68 / 1.68 bpm OBP 3,200 psi Density 8.82 / 8.93 ppg Vp = 330 psi. Turned on both centrifuges. PROD4 Gain 40 bbl in pits due to foaming from the flo-pro. Adding Defoam X and no decrease in volume. Ordered out Screen Clean from MIDF in Deadhorse. Lost 300 psi in pump pressure. SD centrifuge. Contacted town and shut down both centrifuge. rnnieo: ao~icwo a.oc..r. rw~ ~ ~ BP EXPLORATION Page 14 of 16 Operations Summary Report Legal Well Name: 1 D-04 __ _ __ _. Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date ~ From - To ~ Hours ~ Task Code NPT Phase Description of Operations 6/17/2008 17:30 - 20:00 2.50 STWHIP P PROD4 Stalled , SD pump and PUH to 8969 ft. Set TF and ream back 20:00 - 21:45 1.751 STWHIP~ P 21:45 - 00:00 2.25 STWHIP P 6/18/2008 00:00 - 00:30 0.50 STWHIP P 00:30 - 02:30 2.00 STWHIP P 02:30 - 04:15 1.75 DRILL P 04:15 - 06:15 2.00 DRILL P 06:15 - 07:07 0.87 DRILL P 07:07 - 09:30 2.38 DRILL P 09:30 - 09:49 0.32 DRILL P 09:49 - 11:15 1.43 DRILL P in the hole Working to get bit back to 8976 ft Drilled down 8973 ft and stalled. Working way back in hole. Mill to 8976'. PROD4 Drill ahead. 3400 psi fs at 1.72 iNout. 100-300 psi mtr work. Drill to 8999' at 155R TF. Back ream up past billet. Make three passes up and down. PROD4 Wiper trip to window. Circulate out of hole. PROD4 Hold PJSM to discuss handling BHA. Continue to POOH to surface. PROD4 Pressure undeploy sidetrack BHA. Bit in 1-1-0 condition. PROD4 MU lateral drill BHA with 1.0 deg mtr and Smith bicenter bit. Pressure deploy BHA. Stab coild and test mwd tools. Get on well. PROD4 Run in hole. Follow BHP schedule. Corrected -13 ft. Closed EDC and RIH PROD4 RIH and tagged at 8,999 ft PROD4 Drill lateral starting at 8,999 ft at 67-70 L HS TF Op = 1.73 / 1.71 bpm OBP 3,520 psi Density 8.9 / 8.9 ppg Vp = 358 psi. PROD4 Wiper trip PROD4 Drill lateral starting at 9,150 ft at 67-70 L HS TF Op = 1.73 / 1.71 bpm OBP 3,520 psi Density 8.9 / 8.9 ppg BHP /EDC /WHP = 3,843 psi / 11.44 ppg / 40psi Vp = 358 psi. 11:15 - 11:40 0.42 DRILL N DPRB PROD4 Pulled tight at 9215 ft Tight hole. PU wt at 22k. PU to 58k and down to -6k. Tried working with pump and without pump. Mix 150k LSRV pill 10 %Lube776. SWI and line up pumping down the annulus. Pump down well at 700 psi. Pi dropped to 550 psi and pulled free at 58k 11:40 - 16:15 4.58 DRILL P PROD4 Wiper trip to 7090 ft, Pulled above WS and open EDC. PUH at 2.4 bpm to 6600 ft. Tied in and corrected +10 ft RIH 16:15 - 19:00 2.75 DRILL P PROD4 Tagged bottom at 9215 ft. Pumped 150k LSRV /10% 776 Drilling from 9215 ft Op = 1.65 / 1.54 bpm Pob = 3680 psi BHP/ECD/WHP = 3970psi / 11.87 ppg / 37 psi Vp 300 bbl's. Drill to 9315'. 19:00 - 19:45 0.75 DRILL P PROD4 Drill ahead from 9315'. 3350 psi fs at 1.65 in/out. 100-200 psi mtr work. 19:45 - 20:15 0.50 DRILL P PROD4 Wiper trip to 8995'. Start 10 bbl hivis sweep down hole. Set do at 9160'. Reduce pump rate. Run to btm. 20:15 - 00:00 3.75 DRILL P PROD4 Drill ahead. 3700 psi fs at 1.63 iNout. 150-300 psi mtr work. WHP/BHP/ECD: 40/3900/11.67 ppg. Some trouble with weight transfer. Drill to 9495'. F'IIMEtl: ti/:1U/LUUC y::i"L::14 HM BP EXPLORATION Page 15 of 16 Operations Summary Report Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours j Task Code NPT Phase Description of Operations 6/19/2008 00:00 - 00:45 0.75 DRILL P 00:45 - 04:00 3.25 DRILL P 04:00 - 07:00 3.00 DRILL P 07:00 - 10:15 3.25 DRILL P 10:15 - 10:41 ~ 0.43 ~ DRILL ~ P 6/20/2008 10:41 - 11:30 0.82 DRILL P 11:30 - 15:00 3.50 DRILL P 15:00 - 16:05 1.08 DRILL P 16:05 - 17:19 1.23 DRILL P 17:19-20:15 I 2.931 DRILL IP 20:15 - 21:30 1.25 DRILL P 21:30 - 23:30 2.00 DRILL P 23:30 - 00:00 0.50 DRILL P 00:00 - 02:15 2.25 DRILL P 02:15 - 04:15 I 2.001 DRILL I P 04:15 - 05:00 0.75 DRILL P 05:00 - 05:45 0.75 CASE P 05:45 - 11:15 5.50 CASE P 11:15 - 12:54 1.65 CASE P 12:54 - 14:10 .1.27 CASE P 14:10 - 15:00 0.83 CASE P PROD4 Wiper trip to billet at 8975'. PROD4 Drill ahead to 9569' 3450 psi fs at 1.65 in/out. 100-250 psi mtr work. Having to stack a lot of surface coil wt to drill. Difficult to keep pipe moving. PROD4 Make long wiper trip to tbg. Open EDC above window. 4350 psi fs at 2.25 in/out. ~~ PROD4 Tagged bottom at 9,569 ft. Drilling in C3 w/ TF at 90R Op = 1.70 1.61 bpm fs at 3,900 psi Density = 9.0 / 9.0 ppg BHP/ECD/WHP 4,009 psi / 11.97 ppg / 30 psi Vp = 230 bbls. Called for mud swap LSRV's and PV/YP high PROD4 Started mud swap at 9620 ft Op = 1.701 1.50 bpm Wiper new mud around, Wiper trip to billet PROD4 Wiper to 8975 ft PROD4 Tagged bottom at 9,620 ft. Drilling in C3 w/ TF at 90R Op = 1.70 / 1.70 bpm fs at 3,280 psi Density = 8.63 / 8.63 ppg BHP/ECD/WHP 3,662 psi / 10.9 ppg / 33 psi ROP did improve with the new mud in the wellbore PROD4 Wiper to 9000 ft PROD4 Tagged bottom at 9,775 ft. Drilling in C3 w/ TF at 150R and looking for C2/C3 transition zone on the gamma ray log. TD could be approximately 9,850 ft MD Op = 1.70 / 1.70 bpm fs at 3,280 psi Density = 8.63 / 8.63 ppg BHP/ECD/WHP 3,662 psi / 10.9 ppg / 33 psi ROP did improve with the new mud in the wellbore Projected 80deg at bit, at 9,836 ft PROD4 Wiper trip to up in to tbg tail at 6600'. Open EDC in cased hole. 3885 psi fs at 2.37 in/out. Lots of cuttings noted at shaker from liner btms up. Run back in hole to gr tie in depth. PROD4 Log GR tie in from 7010'. Add 4.5' correction. Log CCL from 6550' to 6750'. Tbg tail logged at 6674'. PROD4 Close EDC. Make wiper trip to TD. Tag TD at 9852'. PROD4 Pull out of hole. Lay in liner pill with 2 ppb alpine beads from 9500'. PROD4 Pull up hole from TD at 9852'. Continue to lay in bead pill. Circulate KWF from 7000'. PROD4 KWF back to surface. Circulate out of hole. No fluid losses noted. PROD4 LD lateral drilling BHA. LNR4 Rig up floor to make up 2-3/8" liner assembly LNR4 PU and RIH with Liner LNR4 RIH and tagged at 9,852 ft Released from liner. Lost 13k downhole wt LNR4 POOH LNR4 LD Liner running tool and coil track. PU nozzel BHA. Printed: 6/30/2008 9:32:34 AM • BP EXPLORATION Page 16 of 16 Operations Summary Report -- -- - - -- -- Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/20/2008 15:00 - 16:15 1.25 CLEAN P CLEAN RIH with Nozzel BHA to 6625 ft. 16:15 - 18:30 2.25 CLEAN P CLEAN Cleaning out pits. Circulate out 10.8 ppg FloPro with seawater. POOH chasing 10.8ppg brine to surface 18:30 - 20:30 2.00 CLEAN P CLEAN Spot LRS diesel pumper. Hold PJSM with rig crew. RU to cementing line. Pump 25 bbls diesel in to coil. FP well to surface. POOH. Get off well. LD tools. 20:30 - 22:00 1.50 WHSUR P POST Hold PJSM to set BPV. PU and test lubricator to 1500 psi. Run and set Cameron 3-1/8" bpv. Draw down test the same. Rig down lubricator. Remove from rig. 22:00 - 00:00 2.00 DEMOB P POST Empty and clean pits. Hold PJSM to discuss using a hammer wrench and ND BOPs. ND BOPs and cellar plumbing. 6/21/2008 00:00 - 03:30 3.50 DEMOB P POST Rig down external equipment (tiger tank, cuttings box etc) LD lubricator on rig floor. ND BOP and cellar MPD components. Grease injector. Check chains.- Rig released at 0330 hrs. on 6/21/08 03:30 - 04:00 0.50 DEMOB P POST Back rig off well. Standby on edge of pad. Printed: 6/30/2008 9:32:34 AM ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. ~ Kuparuk River Unit Kuparuk 1 D Pad 1 D-04 1 D-04A Design: 1 D-04A Baker Hughes INTEQ Survey Report ~ 27 June, 2008 r~~r BAKER Nu+~NEs INTE[~ / ConocoPhillips ~~ s ConocoPhillips Baker Hughes INTEQ Survey Report NU~ Alaska INTEQ Company: ConocoPhUlips(Alaska) Inc Local Co-ordinate Reference: Weli 1 D-04 Project.• Kuparuk River Unit TVD Reference: 1D-04 ~ 105.OOft Site: Kuparuk 1D Pad MD Reference: 1D-04 ~ 105:OOft Well: 1 D-04 North Reference: True Wellbore: 1 D-04A Survey Calculation Method: Minimum Curvature Design: 1 D-04A Database: EDMv16 Prod Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Enact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1 D Pad _ _ Site Position: Northing: 5,959,669.68 ft Latitude: 70° 18' 1.318 N From: Map Eastlng: 561,086.44 ft Longitude: 149° 30' 18.921 W Position Uncertainty: 0.00 ft Slot Radius: 36 " Grid Convergence: 0.47 ° Wolf 1D-04 Well Position +NIS 0.00 ft Northing: 5,959,545.00 ft Latitude: 70° 18' 0.139 N +E/-W 0.00 ft Easting: 560,490.00 ft Longitude: 149° 30' 36.340 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft WeNbore 1 D-04A Magnetics Model Name Sample Date Declination Dip Angle Field Strength 1°- (°I InTI BGGM2007 5/13/2008 17.86 79.75 57,282 Design 1 D-04A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,000.00 Vertlcai Section: Depth From (TVD) +W-S +EI-W Direction Ift- Ift) Ift1 (°1 105.00 0.00 0.00 85.00 • 6/27/2008 2:04:07PM Page 2 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ProjecC Site: weu: weubore: Design: ConocoPhillips(Alaska) Inc: Kuparuk River Uhit Kuparuk 1D Pad 1D-04 tD-04A 1D-04A ConocoPhillips Baker Hughes INTEQ Survey Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: r>';<r s ~ ~ $ INTEQ Well 1 D-04 1 D-04 (c~ 105:OOft 1 D-04 ~ 105:OOft True Minimum Curvature EDMv16 Prod Survey Program Date Prom To (ft) (ftt Survey (Wellbore) Too! Name Description 200.00 7,000.00 1d04 (1D-04) SEEKER MS BHI Seeker multishot 7,097.15 8,560.00 1D-04A MWD (1D-04A) MWD MWD -Standard Survey MD Inc Azi TVDSS WS EM! Northing Easting DLS Vertical Section TPO lftl (°) (°) Iftl lft- (ft) lftl (ft) (°I100ft1 (ftl (°) { 7,000.00 1.78 72.80 6,251.54 1,593.57 1,821.90 5,961,153.03 562,298.83 0.65 1,953.85 -165.66 7,097.15 1.53 62.19 6,348.65 1,594.62 1,824.48 5,961,154.10 562,301.41 0.41 1,956.52 -134.80 7,098.00 1.78 57.71 6,349.50 1,594.63 1,824.50 5,961,154.11 562,301.43 33.72 1,956.54 -29.06 7,130.10 12.47 .36.50 6,381.31 1,597.69 1,826.99 5,961,157.19 562,303.90 33.73 1,959.29 -24.58 7,160.27 28.12 35.14 6,409.52 1,606.18 1,833.06 5,961,165.73 562,309.90 51.89 1,966.07 -2.38 7,190.19 38.39 34.60 6,434.50 1,619.63 1,842.42 5,961,179.25 562,319.15 34.34 1,976.57 -1.88 7,220.26 49.31 33.82 6,456.16 1,636.84 1,854.10 5,961,196.55 562,330.69 36.36 1,989.71 -3.12 7,261.36 62.63 39.93 6,479.12 1,663.92 1,874.59 5,961,223.79 562,350.96 34.65 2,012.48 22.60 7,290.98 73.36 45.03 6,490.21 1,684.10 1,893.14 5,961,244.12 562,369.34 39.57 2,032.72 24.79 7,322.85 83.89 48.54 6,496.49 1,705.45 1,915.89 5,961,265.65 562,391.91 34.75 2,057.24 18.47 7,358.40 93.25 51.93 6,497.37 1,728.15 1,943.17 5,961,288.57 562,419.01 28.00 2,086.40 19.97 7,380.86 99.92 56.12 6,494.80 1,741.25 1,961.21 5,961,301.81 562,436.94 35.00 2,105.51 31.75 7,400.92 104.74 57.55 6,490.52 1,751.97 1,977.61 5,961,312.66 562,453.25 25.02 2,122.78 16.02 7,430.94 105.08 61.40 6,482.79 1,766.70 2,002.59 5,961,327.59 562,478.11 12.44 2,148.95 84.28 7,460.32 105.46 64.46 6,475.05 1,779.60 2,027.83 5,961,340.69 562,503.24 10.13 2,175.21 82.26 7,490.22 104.60 67.05 6,467.29 1,791.45 2,054,15 5,961,352.76 562,529.47 8.85 2,202.47 108.63 7,520.72 104.03 70.11 6,459.75 1,802.24 2,081.66 5,961,363.77 562,558.89 9.90 2,230.82 100.50 7,550.56 103.62 73.23 6,452.62 1,811.35 2,109.16 5,961,373.10 562,584.31 10.25 2,259.01 97.33 7,580.66 102.54 75.75 6,445.81 1,819.19 2,137.41 5,961,381.16 562,612.50 8.91 2,287.83 113.46 7,611.26 101.57 78.84 6,439.41 1,825.77 2,166.60 5,961,387.98 562,641.63 10.37 2,317.48 107.47 7,640.39 101.03 81.32 6,433.71 1,830.69 2,194.74 5,961,393.12 562,669.72 8.55 2,345.94 102.27 • 6/27/2008 2:04:07PM Page 3 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhiilips(Alaska) Inc Project: Kuparuk River Unit Site: Kuparuk 1 D Pad WeB: 1 D-04` Wellbore: 1 D-04A Design: 1 D-04A Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: ri.r s ~~~ INTEQ VVe11 1 D-04 1 D-04 ~ 105.OOft 1 D-04 ~ 105.OOft True Minimum Curvature EDMv16 Prod Survey MD Inc Azi NDSS WS E1W Northing Easting DLS Vertical Section TFO Ift! 1°! 1°- 1~1 Iffl Ift1 (ff- (ft- (°noott) (s) (°! 7,671.54 100.50 84.18 6,427.89 1,834.55 2,225.09 5,961,397.23 562,700.04 9.18 2,376.52 100.41 7,710.70 99.35 87.90 6,421.13 1,837.21 2,263.57 5,961,400.20 562,738.49 9.81 2,415.08 107.10 7,741.12 98.63 90.64 6,416.38 1,837.60 2,293.61 5,961,400.82 562,768.52 9.21 2,445.04 104.68 7,773.04 97.67 93.27 6,411.85 1,836.52 2,325.18 5,961,400.00 562,800.10 8.69 2,476.40 110.05 7,803.56 96.81 96.57 6,408.01 1,833.92 2,355.34 5,961,397.64 562,830.28 11.09 2,506.22 104.51 7,834.40 95.82 98.85 6,404.61 1,829.81 2,385.72 5,961,393.78 562,860.68 8.02 2,536.12 113.47 7,871.16 95.29 102.62 6,401.05 1,822.99 2,421.66 5,961,387.25 562,896.67 10.31 2,571.32 97.85 7,904.36 94.83 105.53 6,398.13 1,814.95 2,453.73 5,961,379.47 562,928.81 8.84 2,602.58 98.89 7,939.10 93.32 102.49 6,395.66 1,806.56 2,487.35 5,961,371.35 562,962.49 9.75 2,635.33 -116.36 7,971.47 92.83 100.07 6,393.92 1,800.24 2,519.04 5,961,365.29 562,994.23 7.62 2,666.36 -101.40 8,005.17 93.10 98.49 6,392.18 1,794.82 2,552.26 5,961,360.13 563,027.48 4.75 2,698.97 -80.25 8,037.88 92.49 94.29 6,390.58 1,791.18 2,584.72 5,961,356.76 563,059.97 12.96 2,730.99 -98.17 8,067.28 94.42 91.70 6,388.81 1,789.65 2,614.02 5,961,355.46 563,089.28 10.97 2,760.05 -53.19 8,099.59 95.35 87.65 6,386.06 1,789.83 2,646.20 5,961,355.90 563,121.46 12.82 2,792.13 -76.85 8,130.82 94.89 82.48 6,383.27 1,792.50 2,677.18 5,961,358.82 563,152.41 16.55 2,823.22 -94.87 8,159.78 93.66 78.24 6,381.11 1,797.34 2,705.65 5,961,363.89 563,180.83 15.21 2,852.00 -106.05 8,190.74 91.97 73.88 6,379.59 1,804.79 2,735.65 5,961,371.58 563,210.77 15.09 2,882.54 -111.09 8,220.48 91.63 69.71 6,378.65 1,814.07 2,763.88 5,961,381.09 563,238.93 14.06 2,911.47 -94.60 8,250.67 91.97 65.03 6,377.70 1,825.68 2,791.73 5,961,392.92 563,266.67 15.54 2,940.22 -85.77 8,275.55 92.27 61.47 6,376.78 1,836.87 2,813.93 5,961,404.28 563,288.78 14.35 2,963.31 -85.12 8,300.76 92.71 58.24 6,375.69 1,849.52 2,835.70 5,961,417.10 563,310.45 12.92 2,986.11 -82.17 8,331.23 92.09 63.08 6,374.41 1,864.43 2,862.23 5,961,432.23 563,336.86 16.00 3,013.84 97.20 8,361.01 91.11 66.30 6,373.58 1,877.15 2,889.14 5,961,445.17 563,363.66 11.30 3,041.75 106.88 8,389.99 91.01 69.73 6,373.04 1,888.00 2,916.00 5,961,456.23 563,390.43 11.84 3,069.46 91.64 8,423.50 92.25 74.68 6,372.09 1,898.23 2,947.89 5,961,466.72 563,422.23 15.22 3,102.11 75.87 8,454.47 93.93 78.44 6,370.42 1,905.42 2,977.96 5,961,474.14 563,452.24 13.28 3,132.69 65.80 8,488.25 96.43 81.48 6,367.37 1,911.28 3,011.08 5,961,480.28 563,485.31 11.62 3,166.20 50.32 ConocoPhillips Baker Hughes INTEQ Survey Report 6/27/2008 2:04:07PM Page 4 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhUlips(Alaska) Inc Project: Kuparuk River Unit Site: Kuparuk 1D Pad Well: 1D-04 Wellfiore: 1 p-04A Design: 1 D=04A ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-oMinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: DataWse: ~c.r s~~$ INTEQ Well 1 D-04 1 D-04 ~ 105.OOft 1 D-04 ~ 105:OOft True Minimum Curvature EDMv16 Prod Survey MD Inc Azl NDSS WS E/W Northing Fasting DLS Vertical Section TFO (~) (°I 1°) 1~) Ift1 Iftl l~l Ift) (°noofll Iftl f°) 8,517.93 97.91 82.52 6,363.66 1,915.38 3,040.24 5,961,484.61 563,514.43 6.08 3,195.61 34.82 8,560.00 100.43 86.01 6,356.96 1,919.54 3,081.55 5,961,489.09 563,555.71 10.15 3,237.12 53.55 6/27/2008 2:04:07PM Page 5 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc Project: Kuparuk River UnU Site: Kuparuk 1D Pad: Welt: 1 D-04 WeUbore: 1 D-04A Design: 1 D-04A ConocoPhillips ~Ltr Baker Hughes INTEQ Survey Report sa ~~$ INTEQ Local Co-ordinate Reference: Well 1 D-04 ND Reference: 1 D-04.~ 105.OOft MD Reference; 1D-04 ~ tO5:00ft North Reference: True Survey Calculation Method: Minimum Curvature Database: EDMv16 Prod Targets Target Name - hWmiss target Dlp Angle Dip Dir. ND +N/-S +E/•W Northing Easting -Shape (°) (°) (ft) lftl (ft) Iftl (ft) Latitude Longitude 1D-04A Polygon 0.00 0.00 105.00 1,633.62 1,741.39 5,961,192.42 562,218.02 70° 18' 16.203 N 149° 29' 45.562 W - actual wellpath misses by 6252.19ft at 7000.OOft MD (6356.54 ND, 1593.57 N, 1821.90 E) -Polygon Point 1 105.00 1,633.62 1,741.39 5,961,192.42 562,218.02 Point 2 105.00 1,888.88 2,088.48 5,961,450.44 562,563.01 Point3 105.00 1,992.92 2,584.37 5,961,558.46 563,058.00 Point4 105.00 1,988.27 3,166.41 5,961,558.50 563,640.00 Point 5 105.00 1,853.91 3,834.42 5,961,429.53 564,309.01 Point6 105.00 1,818.89 4,211.19 5,961,397.55 564,686.01 Point? 105.00 1,489.14 5,049.66 5,961,074.59 565,527.03 Point 8 105.00 1,079.29 5,024.38 5,960,664.59 565,505.05 Point 9 105.00 1,498.97 3,820.58 5,961,074.53 564,298.02 Point 10 105.00 1,773.25 3,164.69 5,961,343.49 563,640.01 Point 11 105.00 1,721.23 2,917.24 5,961,289.49 563,393.01 Point 12 105.00 1,649.25 2,538.62 5,961,214.47 563,015.02 Point 13 105.00 1,630.69 2,107.41 5,961,192.44 562,584.01 Point 14 105.00 1,502.58 1,869.36 5,961,062.43 562,347.03 1D-04A Fault 1 0.00 0.00 105.00 1,633.62 1,741.39 5,961,192.42 562,218.02 70° 18' 16.203 N 149° 29' 45.562 W - actual wellpath misses by 6252.19ft at 7000.OOft MD (6356.54 ND, 1593.57 N, 1821.90 E) - Polygon Point 1 105.00 1,633.62 1,741.39 5,961,192.42 562,218.02 Point2 105.00 1,587.70 2,356.10 5,961,151.46 562,833.02 Point3 105.00 1,992.92 2,584.37 5,961,558.46 563,058.00 Point4 105.00 1,587.70 2,356.10 5,961,151.46 562,833.02 1D-04A Target 1 0.00 0.00 6,541.00 1,787.35 2,147.67 5,961,349.41 562,623.01 70° 18' 17.714 N 149° 29' 33.714 W - actual wellpath misses by 34.60ft at 7585.65ft MD (6549.73 ND, 1820.37 N, 2142.14 E) - Point 1D-04A Target 2 0.00 0.00 6,467.00 1,911.03 3,180.77 5,961,481.39 563,654.98 70° 18' 18.927 N 149° 29' 3.587 W - actual wellpath misses by 99.71ft at 8560.OOft MD (6461.96 ND, 1919.54 N, 3081.55 E) -Point J 6/27/2008 2:04:07PM Page 6 COMPASS 2003.18 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska)Jnc Project: Kuparuk River Unit Sits: Kuparuk 1 D Pad Well: tD-04 Weilbore: 1 D-04A Design: 1 D-04A ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculatbn Method: Database: r~c.-r s~R..c Well 1 D-04 1 D-04 ~ 105.OOft 7D-04 ~ 105.OOft True Minimum Curvature EDMv16 Prod Targets Target Name - hit/miss target DIp Angle Dip Dir. ND +N/-S +EI-W Northing Easting -Shape f°- (°- 1~) IfU Iftl Ift) (ftl Latitude Longitude 1D-04A Polygon 0.00 0.00 105.00 1,633.62 1,741.39 5,961,192.42 562,218.02 70° 18' 16.203 N 149° 29' 45.562 W - actual wellpath misses by 6252.19ft at 7000.OOft MD (6356.54 ND, 1593.57 N, 1821.90 E) - Polygon Point 1 105.00 1,633.62 1,741.39 5,961,192.42 562,218.02 Point2 105.00 1,888.88 2,088.48 5,961,450.44 562,563.01 Point 3 105.00 1,992.92 2,584.37 5,961,558.46 563,058.00 Point4 105.00 1,988.27 3,166.41 5,961,558.50 563,640.00 Points 105.00 1,853.91 3,834.42 5,961,429.53 564,309.01 Point6 105.00 1,818.89 4,211.19 5,961,397.55 564,686.01 Point? 105.00 1,489.14 5,049.66 5,961,074.59 565,527.03 PointB 105.00 1,079.29 5,024.38 5,960,664.59 565,505.05 Point9 105.00 1,498.97 3,820.58 5,961,074.53 564,298.02 Point 10 105.00 1,773.25 3,164.69 5,961,343.49 563,640.01 Point 11 105.00 1,721.23 2,917.24 5,961,289.49 563,393.01 Point 12 105.00 1,649.25 2,538.62 5,961,214.47 563,015.02 Point 13 105.00 1,630.69 2,107.41 5,961,192.44 562,584.01 Point 14 105.00 1,502.58 1,869.36 5,961,062.43 562,347.03 1D-04A Fault 1 0.00 0.00 105.00 1,633.62 1,741.39 5,961,192.42 562,218.02 70° 18' 16.203 N 149° 29' 45.562 W - actual wellpath misses by 6252.19ft at 7000.OOft MD (6356.54 ND, 1593.57 N, 1821.90 E) -Polygon Point 1 105.00 1,633.62 1,741.39 5,961,192.42 562,218.02 Point2 105.00 1,587.70 2,356.10 5,961,151.46 562,833.02 Point 3 105.00 1,992.92 2,584.37 5,961,558.46 563,058.00 Point4 105.00 1,587.70 2,356.10 5,961,151.46 562,633.02 1D-04A Target 1 0.00 0.00 6,541.00 1,787.35 2,147.67 5,961,349.41 562,623.01 70° 18' 17.714 N 149° 29' 33.714 W - actual wellpath misses by 34.60ft at 7585.65ft MD (6549.73 ND, 1820.37 N, 2142.14 E) - Point 1D-04A Target2 0.00 0.00 6,467.00 1,911.03 3,180.77 5,861,481.39 563,654.98 70° 18' 18.927 N 149° 29' 3.587 W - actual wellpath misses by 99.71ft at 8560.OOft MD (6461.96 ND, 1919.54 N, 3081.55 E) - Point ~J u 6/27/2008 2:04:07PM Page 7 COMPASS 2003.16 Build 42F / ConocoPhillips Conoc oPhillips Baker Hughes INTEQ Survey Report Alaska Company: ConocoPhillips(Aleska) Inc. Local Co-ordinate Reference: Project: Kuparuk River Unit ND Reference: Site: KuparuklD Pad MD Reference: Well: 1D-04 North Reference: Wellbore: 1 D-04A Survey Calculation Method: Design: 1 D-04A Database: ri.r s i~alt;tes LNTEQ We111 D-04 1 D-04 (~ 105.OOft 1D-04 ~ 105.OOft TfUe Minimum Curvature EDMv16 Prod Targets Target Name - hit/miss target Dip Angle Dip Dir. ND +W-S +EI-W Northing Easting • Shape (°) (°) Iftl Ift! (ft) lft1 Ift1 Latitude Longitude i 1D-04A Polygon 0.00 0.00 105.00 1,633.62 1,741.39 5,961,192.42 562,218.02 70° 18' 16.203 N 149° 29' 45.562 W - actual wellpath misses by 6252.19ft at 7000.OOft MD (6356.54 ND, 1593.57 N, 1821.90 E) - Polygon Point 1 105.00 1,633.62 1,741.39 5,961,192.42 562,218.02 Point2 105.00 1,888.88 2,088.48 5,961,450.44 562,563.01 Point 3 105.00 1,992.92 2,584.37 5,961,558.46 563,058.00 Point4 105.00 1,988.27 3,166.41 5,961,558.50 563,640.00 Point 5 105.00 1,853.91 3,834.42 5,961,429.53 564,309.01 Point6 105.00 1,818.89 4,211.19 5,961,397.55 564,686.01 Point? 105.00 1,489.14 5,049.66 5,961,074.59 565,527.03 PointB 105.00 1,079.29 5,024.38 5,960,664.59 565,505.05 Point9 105.00 1,498.97 3,820.58 5,961,074.53 564,298.02 Point 10 105.00 1,773.25 3,164.69 5,961,343.49 563,640.01 Point 11 105.00 1,721.23 2,917.24 5,961,289.49 563,393.01 Point 12 105.00 1,649.25 2,538.62 5,961,214.47 563,015.02 Point 13 105.00 1,630.69 2,107.41 5,961,192.44 562,584.01 Point 14 105.00 1,502.58 1,869.36 5,961,062.43 562,347.03 1D-04A Fault 1 0.00 0.00 105.00 1,633.62 1,741.39 5,961,192.42 562,218.02 70° 18' 16.203 N 149° 29' 45.562 W - actual wellpath misses by 6252.19ft at 7000.OOft MD (6356.54 ND, 1593.57 N, 1821.90 E) - Polygon Point 1 105.00 1,633.62 1,741.39 5,961,192.42 562,218.02 Point2 105.00 1,587.70 2,356.10 5,961,151.46 562,833.02 Point 3 105.00 1,992.92 2,584.37 5,961,558.46 563,058.00 Point4 105.00 1,587.70 2,356.10 5,961,151.46 562,833.02 1D-04A Target 1 0.00 0.00 6,541.00 1,787.35 2,147.67 5,961,349.41 562,623.01 70° 18' 17.714 N 149° 29' 33.714 W - actual wellpath misses by 34.60ft at 7585.65ft MD (6549.73 ND, 1820.37 N, 2142.14 E) - Point 1D-04A Target 2 0.00 0.00 6,467.00 1,911.03 3,180.77 5,961,481.39 563,654.98 70° 18' 18.927 N 149° 29' 3.587 W - actual wellpath misses by 99.71ft at 8560.OOft MD (6461.96 ND, 1919.54 N, 3081.55 E) - Point 6/27/2008 2:04:07PM Page 8 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc: Project: Kuparuk River Unit Site: Kuparuk 1D Pad wale 1D-oa Wellbore: 1 D-04A Design: 1 D-04A ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-ordinate Ref®rence: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: ri.r BAKER~~ INTEQ Well 1 D-04 1D-04 @ 10$.OOft 1 D-04 ~ 105.OOft True Minimum Curvature EDMv16 Prod Checked By: Approved By: Date: I u 6/27/2008 2:04:07PM Page 9 COMPASS 2003.16 Build 42F • Well Name: 1D-04 Wellbore Diagram (6/3/08) API # 50-029-20416-01-00 ~'"~ PTD: 20&064 ConocoPh i I I i ps h 10-3/7" 36#/fl K-55 BTC -- Alaska ~.1~ 557 ft Camco DS Nipple 2.875" I.D. RA Marker 7105 k TOWS 7097 k Abandoned C-Sand Abandoned A-Sand ST at 7,728k (~ 180 deg L ti ST ~.8,979k 55 deg R 5" 14.9#/ft K-55 Liner -- 7500.0 h ST at 9,735 k ~ 780 dea R 1D-04A TD:8,560ft i 1D-04AL1 TD:9,372ft 1 D-04AL7-02 TD: 9,952k C:\Documents and'.`igllillgs\hubbletl\Local Settings\Temporary Internet Files\OLKCE\1 D-04AL1 L12 WBD .xls ~;.~ _M_ ~. ~a' ~ s ~`a [",~ L. d-I-~ ~.,~- ~ ~N~ ' SARAH PA ~~ ~~,~, ~_~ LlN, GOVERNOR CO~(~'+L'17o.trO n ~ I~ 333 W. 7th AVENUE, SUITE 100 jlASAii L.~l•.iuii~7a ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mel Rixse CT Drilling Engineer ConocoPhillips Alaska, Inc. c/o P.O. Box 196612 Anchorage, AK 99519-6612 Re: Kuparuk River Field, Kuparuk River Pool, Kuparuk 1D-04A ConocoPhillips Alaska, Inc. Permit No: 208-084 Surface Location: 120' FNL, 598' FEL, SEC. 23, T11N, R10E, UM Bottomhole Location: 1815' FSL, 2598' FWL, SEC. 13, T11N, R10E, UM Dear Mr. Rixse: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required perrmits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit iri the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this3~ d~y of Ma , 2008 Y Sincerely, Daniel T. Seamount, Jr. Chair cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ' "' STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMI N MAY ~ ~ 2008 PERMIT TO DRILL ~' ~~~ 20 AAC 25.005 ~y~sk~ Oii Gas Cons. Commission 1 a. Type of work ^ Drill ®F~edrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is pr ^Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: Kuparuk 1 D-04A 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 8650 TVD 6362ss 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: 1 8' FEL T1 R10E UM ' SEC 7. Property Designation: ADL 025650 • River Pool ' , , 20 FNL, 59 . 23, 1N, Top of Productive Horizon: 1480' FSL, 1199' FWL, SEC. 13, T11N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: June 1, 2008 Total Depth: 1815' FSL, 2598' FWL, SEC. 13, T11N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 13,500' 4b. Location of Well (State Base Plane Coordinates): Surface: x-560490 • y-5959545 ' Zone-ASP4 10. KB Elevation (Height above GL): 105' ~ feet 15. Distance to Nearest Well Within Pool: 2300' 16. Deviated Wells: Kickoff Depth: 7130 'feet Maximum Hole An le: 110 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2917 ' Surface: 2279 98. Casin Pr ram: S e ' `t' s To - Se in De th - Bo om uanti of m nt c.f. or sa ks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 900' 7750' 7006'ss 8650' 6362'ss Uncemented lotted Liner g, PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 7502' Total Depth TVD (ft): Plugs (measured): 6863' None Effective Depth MD (ft): 7450' Effective Depth TVD (ft}: 6811' Junk (measured): None Casing Length' ize CemenYVolume MD D Conductor /Structural 72' 1 264 sx Ar ticset I I 72' 72' Surface 2890' 10-3/4" 3300 sx Arcticset II 2890' 2690' Intermediate 7042' 7" 1600 sx Self-Stress Cement 7042' 6403' Produ i n Liner 754' 5" 120 sx Self-Stress Cement 6746' - 7500' 6108' - 6861' Perforation Depth MD (ft): 7102' - 7354' Perforation Depth TVD (ft): 6463' - 6715' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoin is true and correct. Contact Mel Rixse, 564-5620 Printed Name Rix Title CT Drilling Engineer Prepared By Name/Number: Si natu Phone 564-5620 Date iZa' Terrie Hubble, 564-4628 Commission Use Onf Permit To Drill Number: ~-~ API Number: 50-029-20416-01-00 Permit Approval See cover letter for D te: • ~~ o h rre uiremen Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed met~~ha``ne, gas hydrates, or gas contained shales: Samples Req'd: ayes I~ruo Mud Log Req'd: ^ yes QNo HzS Measures: Yes ^ No Directional Survey Req'd: Yes ^ No Other: 35~ i~S t ~~ ~ ~ S ~~~Q Q~ ~ APPROVED BY THE COMMISSION U Date ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~ , ~ ~ Submit In Duplicate ., KRU 1 D-04A, KRU 1 D-04~ &KRU 1 D-04AL1-01 Trilateral ~iled Tubing Drilling To: Tom Maunder Petroleum Engineer h Alaska Oil & Gas Conservation Commission From: Mel Rixse CTD Engineer Date: May 15, 2008 Re: 1 D-04A, 1 D-04AL1, 1 D-04AL1-01 Application for Permit to Drill Request A coiled tubing drilling rig will drill three laterals in well KRU 1 D-04 using the managed pressure drilling technique. These horizontal laterals will target Kuparuk C3/C4 sand reserves to capture and protect currently nonrecoverable resources. The perforations in the motherbore will be cement squeezed. 2hg~,later;31 will,e~cit .themotharbore: a# 7110' MD, and drill a i 54Q' ia~ , w~ii~h .will target. the C4 sands to the east. It will be completed with 23/8" slotted liner from 8650' MD to a TC1L of 7750' MD. The AL1 lateral will exit the A lateral off a flow throug finer top si etrac billet and drill a 2000' horizontal targeting the C4 sands in a fault block further east. It will be completed with 23/8" slotted liner from TD at 9750' MD to 8850'MD. The AL1-01 lateral will exit the AL1 lateral off a flow through liner top sidetrack billet and drill 1000' horizontal targeting the C3 sands in the same fault block. It will be completed with 2-3/8" slotted liner from TD at 9840'MD to the window, then with stolid liner to 4' into tubing tail at 6660' ELMD. CTD Drill and Complete lD-t34A~~-1D-04AL1, 1D-04AL1-01 program: Spud in June 1, 2008 CTD Sidetrack Summary Pre-Rig Work: 1. O PT Master & Swab valve to 4500 psi. Drawdown test MV and SV to 0 psi DONE 2. O MIT-OA DONE 3. O PPPOT-T & IC DONE 4. O TIFL DONE 5. S Drift to 7127'MD for Baker 2-5/8" X 5" Thru-Tubing Whipstock. DONE 6. S Calliper log 5" liner and 3-1/2" tubing to surface. DONE 7. E Video log of 5" liner -Found collapsed liner at 7127' ELM DONE 8. S Dummy Gas Lift Valve's 9. O Load tubing & IA, MIT-IA 10. O Obtain static bottom hole pressure ; 11.E Set Whipstock (TOWS 7110' MD) using gyro-orienter for vertical hole 12. C Test for infectivity 13. C Lay in cement above perfs, Squeeze cement past whipstock. 14. O Function test LDS. 15. O Set BPV 16. O Bleed production flow lines and GL lines down to zero and blind flange 17. O Install second swab valve & SSV 18. O Remove wellhouse, level pad, drill mouse hole. Rig Sidetrack Operations: (Scheduled to begin on June 15, 2008) 1. NU 7-1/16" CT Drilling BOPE and test to 250 psi low and 3500 psi high 2. Pull BPV. Page 1 of 5 May 15, 2008 • KRU 1 D-04A, KRU 1 D-04AL1 &KRU 1 D-04AL1-01 Trilateral -Coiled Tubing Drilling.. 3. Mill 2.74" window at 7110'. Swap well to Flo-Pro. Use managed pressure drilling techniques to maintain 800 psi pressure over formation pressure at the window. 4. Drill build/turn section with 3" bicenter bit, and land well. ~ ~~ ~ ~` 5. Drill lateral section to 8,650' MD. 6. Circulate in kill weight fluid from window to surface. 7. Run 2-3/8" slotted liner to TD. Place aluminium liner to billet at 7 750' MD. ~ i etrac 1 lateral off liner top billet. 9. Drill L1 lateral to 9750' MD. ~ 10. Circulate in kill weight fluid from window to surface. 11. Run 2-3/8" slotted liner to TD. Place aluminium liner top billet at 8,850' MD. 12. Sidetrack AL1-01 lateral off liner top billet. 13. Drill L1-01 lateral to 9840' MD. 14. Circulate in kill weight fluid from window to surface. 15. Run 2-3/8" solid/slotted liner to TD. Place TOL in 3-1/2" tubing tael at 6660' ELMD. 16. FP well to 2500' with diesel. 17. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 18. RDMO Nordic 2. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run Live gas lift design 4. RU test separator, flow test well. Mud Program: • Well kill: 11.8 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Maintain 800 psi ~ overbalance on reservoir while drilling. Disposal: • No annular injection on this well. • Class II liquids to KRU 1 R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 1 D-04A : 2-3/8", 4.6#, L-80, STL from TD(8650'MD) to 7750' MD ..----~' 2-3/8"slotted (2" slots, 0.1875" slot width, 8 slots per ft, 2 slot per row, 90 deg phasing). Flow through aluminum billet at TOL. • 1 D-04AL1 : 2-3/8", 4.6#, L-80, STL from TD(9,750'MD) to 8850' MD 2-3/8"slotted (2" slots, 0.1875" slot width, 8 slots per ft, 2 slot per row, 90 deg phasing). Flow through aluminum billet at TOL. • 1 D-04AL1-01:2-3/8", 4.6#, L-80, STL from TD(~9,840 MD) to 6,660' ELMD. 2-3/8"slotted (2" slots, 0.1875" slot width, a slots per ft, 2 riot per row, 90 deg phasing) with blanks across B-shale, inside existing casing, and across faults where shales may be exposed. Top of liner placed ~ 6660' ELMD (4' above 3-1/2" Tubing Tail) CasinNLiner Information Page 2 of 5 May 15, 2008 KRU 1 D-04A, KRU 1 D-04~ &KRU 1 D-04AL1-01 Trilateral oiled Tubing Drilling 10 3/4"", K-55, 45.5#, Burst 3580 psi; collapse 2090 psi. 7", K-55, 26#, Burst 4980, collapse 4320 5", K-55, 9.3#, Burst 5,700; collapse 5,500 psi Well Control: • Two well bore volumes (200 bbls) of KWF will be on location during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan for 1 D-04A, AL1, AL1-01 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • The nearest well to 1 D-04A, AL1, AL1-01 is 1 D-09 which is 2300 ft. away. • Distance to the nearest property line is 13,500 (measured at closest point). Logging • MWD directional and Gamma Ray and Resistivity will be run over all of the open hole section. Hazards • Possible losses due to faulting. • Possibility may drill into D shale above the C4. Will be forced to do an open hole sidetrack. • KRU~pad is considered an H2S pad. 1 D-04 has an H2S level of 80 ppm. The closest SHL .~ to 1 D-04 is 1 D-118 and has an H2S level of 5 ppm H2S. 1 D-12 has the closest BHL an H2S level of 100 ppm. All H2S monitoring equipment will be operational. ~~"~ Reservoir Pressure • The most recent SBHP survey (April -08) was gauged at 2917 psi Cud 6389' SSTVD. The EMW is 8.8 ppg at 6389' TVD. Max. surface pressure with gas (0.1 psi/ft) to surface is 2279 psi. - Managed Pressure Drilling / Managed pressure drilling techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stabili Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. This well does not have a functioning tubing sub-surface safety valve that will be utilized to facilitate BHA deployments and liner running. It is possible that deployment of the BHA under trapped wellhead pressure may be necessary. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (2-3/8" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at the 1 D-04A, AL1, AL1-01 TD: Estimated reservoir pressure: 2917 psi at 6389' TVD, 8.8 ppg EMW. Page 3 of 5 May 15, 2008 KRU 1 D-04A, KRU 1 D-04~ &KRU 1 D-04AL1-01 Trilateral oiled Tubing Drilling • Expected annular friction losses while circulating: 650 psi at KOP and 885 psi at TD (assuming 90 psi/ft, fora 2740' lateral). • Planned mud density: 8.6 ppg equates to 2840 psi hydrostatic pressure at the window. ' • While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 3633 psi or 10.7 ppg ECD. 150 psi surface pressure while drilling will be maintained to assure a EMWt. at the window of 10.7#/gal. • When circulation is stopped, a minimum of 790 psi surface pressure will be applied to the well to maintain constant BHP -3630 psi. Mel Rixse CTD Engineer 564-5620 CC: Well File Sondra Stewman/Terrie Hubble Page 4 of 5 May 15, 2008 • KRU 1 D-04 ConocoPhillips Alaska, Inc. 1 D-04 API: 500292041600 Well T e: PROD Angle~S: 2 de 7099 ~siNO o-s7zs, ~:3 eoo SSSV Type: Nipple Orig Com letion: 1/28/1980 Angle @ TD: 3 deg @ 7502 . , xzssz> I Annular Fluid: Last W/O: 5/31/2000 Rev Reason: TAG FILL Reference L Ref L Date: Last U ate: 4/13/2008 Last Ta : 7244' RKB TD: 7502 ftKB Last Ta Date: 4/5/2008 Max Hole An Ie: 36 de 4100 Casin Strin -ALL STRINGS Descri lion Size To Bottom TVD Wl Grade Thread CONDUCTOR 16.000 0 80 80 65.00 H-40 ~ SUR. CASING 10.750 0 2890 2690 45.50 K-55 PROD. CASING 7.000 0 7042 6399 26.00 K-55 LINER _ 5.000 6746 7500 6856 14.87 K-55 Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 6729 6086 9.20 J-55 BTC Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 7102 - 7114 6458 - 6470 C-4 12 4 8/10/1980 IPERF 2 1/8" Ener et 7114 - 7123 6470 -6479 C-4 9 8 8/10/1980 IPERF 2 1/8" Ener et 7123 - 7186 6479 - 6542 C-4,C-3,C-2 63 4 8/10/1980 IPERF 2 1/8" Ener et 7337 - 7354 6693 - 6710 A-5 17 4 7/28/1980 IPERF 2 1/8" Ener et Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2657 2492 Camco KBUG CAMCO GLV 1.0 BK 0.156 1214 8/26/2007 2 4036 3640 Camco KBUG CAMCO GLV 1.0 BK 0.188 1252 8/26/2007 3 4949 4386 Camco KBUG CAMCO OV 1.0 BTM 0.188 0 8/26/2007 4 5620 4996 Camco KBUG CAMCO DMY 1.0 BK 0.000 0 5/31/2000 ' 5 6135 5495 Camco KBUG CAMCO DMY 1.0 BK 0.000 0 5/31/2000 6 6558 5915 Camco MMM CAMCO DMY 1.5 RK 0.000 0 6/4/2000 Other lu s, a ui ., etc. -COMPLETION De th TVD T e Descri lion ID 557 557 NIP Camco DS NIPPLE 2875 6635 5992 NIP HES X NIPPLE 2.810 5657 6014 PKR Baker'SAB-3' 3.250 ^ -5673 6030 NIP Camco D NIPPLE 2.750 1684 6041 WLEG TTL ELMD 6664' 2.992 " ~ General Notes Date Note 2/25/200 NOTE: WAIVERED WELL: IA X OA COMMUNICATION Perf 02-7123) Perf 537-7354) 1 D-04A , 1 D-04AL1, 1 D-04AL1-07 10-3/4" shoe ~ 2890' RKB 5" liner top ®6746' RKB (6741' ELMD) 7" shoe ®7042' RKB - C-sand perfs 7102' - 7186' ELMD (squeezed) A-sand perfs 7337' - 7354" MD 5" 14.9# K-55 Shoe ~ 7500' 3-1/2" Camco DS nipple ~ 557' RKB 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco KBUG gas lift mandrels ~ 2657', 4036', 4949', 5620', 6135' RKB 3-1/2" Camco KBUG gas lift marxirels ~ 6558' RKB 3-1/2" HES "X" landing nipple ~ 6635' RKB (2.812" min ID) Baker3-1/2" PBR ~ 6643' RKB Baker SAB-3 packer ~ 6657' RKB (3.25" ID) 3-1/2" Camco D landing nipple ~ 6673' RKB (2.75" min ID, No-Go) Mill out to 2.80" pre-rig 3-1/2" tubing tail ~ 6684' RKB (6664' ELMD) in ,~~ \ // Aluminum billet ~ // 8850' MD (wp07) " " ' \ ALt TD ~ 9750' MD (w~ ~ ~ i ~ ~ ~~~~r; fr: Aluminum billet ~ ~ y1•ti•ti•+•+•ti•ti•1• 7750 MD (wp07) ~ :rtir•r•r•r•r•r.r.r 1"1"4N,"ti"1.ti. r•r•r•r•r•r•r•r.r of}fti.ti"tin•ti.ti.ti• 2.3/8" STL r•r•r•r•r•r•r \ :r:r rtir~.ti.ti.ti.ti. _- _~ti~tiltiltilti{tiftif.J slotted liner 2-3/8" STL blank • ConocoPhillips ~~~ ConocoPhillips(Alaska) Inc. , Kuparuk River Unit Kuparuk 1 D Pad 1 D-04 Plan 7, 1 D-04A Plan: Plan #7 Baker Hughes INTEQ Planning Report i 14 May, 2008 ~~~~ BAKER N~IliNES iNTE~ / ConocoPhillips spp~~~1.R~r ConocoF~illps Baker Hughes INTEQ Planning Report ~R1fiilf = a INTEQ Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well 1D-04 Project: Kuparuk River Unit TVD Reference: Mean Sea Level Site: Kuparuk 1 D Pad MD Reference: 1 D-04 @ 105.OOft Well: 1D-04 North Reference: True - Wellbore: Plan 7, 1D-04A Survey Calculatio n Method: Minimum Curvature Design: Plan #7 Database: EDMv16 Prod Survey Tool Program Date ' From To (ft) (ft) Survey (Wellbo re) Tool Name pescription 200.00 7,100.00 1d04 (1D-04) SEEKER MS BHI Seeker multishot ~ 7,100.00 8,650.00 Plan #7 (Plan 7, 1D-04A) MWD MWD -Standard Planned Survey _ - - - I MD Inc Azi TVDSS N/S E/W Northing Easting DLS Vertical Section TFO (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) C/100ft) (ft) (°) !, 7,100.00 ~ 1.52 61.83 6,351.50 1,594.65 1,824.55 5,961,154.14 562,301.48 0.41 1,956.59 -134.86 TIP ~ 7,110.00 1.65 62.96 6,361.50 1,594.78 1,824.79 5,961,154.27 562,301.72 1.34 1,956.84 14.08 KOP 7,130.00 ~ 3.45 65.57 6,381.47 1,595.16 1,825.60 5,961,154.65 562,302.52 9.00 1,957.68 5.00 i End of 9 Deg1100' DLS 7,200.00 32.83 70.10 6,447.27 1,602.66 1,845.80 5,961,162.31 562,322.67 42.00 1,978.46 5.00 7,300.00 74.83 70.48 6,504.97 1,629.21 1,920.14 5,961,189.46 562,396.78 42.00 2,054.83 0.55 ~ 7,383.73 110.00 70.67 6,501.49 1,656.60 1,997.80 5,961,217.47 562,474.21 42.00 2,134.58 0.31 End of 42 Deg/100' DLS 7,400.00 109.99 72.75 6,495.93 1,661.40 2,012.31 5,961,222.39 562,488.68 12.00 2,149.46 90.0 7,473.73 109.63 82.15 6,470.89 1,676.45 2,079.93 5,961,237.98 562,556.17 12.00 2,218.13 90.71 5 7,500.00 106.48 82.15 6,462.75 1,679.86 2,104.67 5,961,241.59 562,580.88 12.00 2,243.07 180.00 7,563.73 98.83 82.15 6,448.80 1,688.35 2,166.22 5,961,250.57 562,642.35 12.00 2,305.13 -180.00 6 7,600.00 98.96 77.74 6,443.19 1,694.61 2,201.50 5,961,257.11 562,677.57 12.00 2,340.81 -88.00 7,700.00 99.03 65.59 6,427.50 1,725.62 2,295.07 5,961,288.87 562,770.89 12.00 2,436.73 -88.68 7,800.00 98.71 53.45 6,412.02 1,775.64 2,380.05 5,961,339.57 562,855.45 12.00 2,525.75 -90.59 7,813.73 98.64 51.79 6,409.95 1,783.88 2,390.84 5,961,347.89 562,866.17 12.00 2,537.21 -92.47 7 7,900.00 97.37 62.16 6,397.90 1,830.36 2,462.36 5,961,394.95 562,937.32 12.00 2,612.52 96.30 8,000.00 95.60 74.11 6,386.56 1,867.28 2,554.41 5,961,432.60 563,029.05 12.00 2,707.43 97.75 5H4/2008 4:51:04PM Page 3 COMPASS 2003.16 Build 42F ~ ConocoPhillips ~Gi1~ C0110~0~~~~IpS Baker Hughes INTEQ Planning Report INTEQ Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well 1D-04 Project: Kuparuk River Unit TVD Reference: Mean Sea Level Site: Kuparuk 1D Pad MD Reference: 1D-04 @ 105.OOft Well: 1D-04 North Reference: True Wellbore: Plan 7, 1D-04A Survey Calculation Method: Minimum Curvature Design: Plan #7 Database: EDMv16 Prod Planned Survey MD Inc Azi TVDSS N/S lJW Northing Easting DLS Vertical Section TFO (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (°I100ft) (ft) (°) 8,100.00 93.60 85.98 6,378.51 1,884.46 2,652.41 5,961,450.57 563,126.90 12.00 2,806.55 99.1 8,188.73 91.69 96.47 6,374.41 1,882.57 2,740.89 5,961,449.39 563,215.39 12.00 2,894.54 100.0 8 8,200.00 91.69 95.11 6,374.08 1,881.43 2,752.10 5,961,448.35 563,226.60 12.00 2,905.60 -90.00 8,300.00 91.64 83.11 6,371.16 1,882.99 2,851.86 5,961,450.70 563,326.34 12.00 3,005.12 -90.04 8,400.00 91.53 71.10 6,368.38 1,905.25 2,949.12 5,961,473.75 563,423.41 12.00 3,103.96 -90.39 8,413.73 91.51 69.46 6,368.02 1,909.88 2,962.04 5,961,478.48 563,436.29 12.00 3,117.23 -90.72 9 8,500.00 91.48 79.81 6,365.76 1,932.71 3,045.09 5,961,501.97 563,519.14 12.00 3,201.95 90.00 8,600.00 91.39 91.81 6,363.24 1,939.99 3,144.61 5,961,510.05 563,618.59 12.00 3,301.72 90.27 8,650.00 91.33 97.82 6,362.06 1,935.80 3,194.39 5,961,506.26 563,668.40 12.00 3,350.95 90.57 TD - 2.375" 5/14/2008 4:51:04PM Page 4 COMPASS 2003.16 Build 42F ConocoPhillips Targal AfiImN6 Orgin Type Nl9 E]rV From NO User NU Targal lFreeOantl) 05005b1 000 0.00 000 t 0-04 (Q 105008 vmpn, Keparwl ww.r unn Sne. KupvuK 1D Patl Wall: tDL1 w11 ~ WNMOrv: %r ], 1D-01A e,,.~n w.llh.i.. uw Plan: %an YT 11D-0UPlan ), 1D-0Y) leae In ]Imm WELL DETAILS: tD-01 Grountl LevMD.00 +W~S +E/.W N9~hing Eevling Lstklutla L9ngttutl6 8191 0.00 O.OOi959296.5t 1700531.96)0° 17' 59.08) M9° 30' 41501 W 8196 6381 W 1581.18 1821 l0 1.>t 11 Ds 1966 & ] )130 BO 3n5 655) &381./] IS9S 18 162660 900 SW 195)66 1 )M3.)) IfOW 108) 650119 1858.60 189150 1]00 SW 21]156 6 )1]3 ]) 1W 63 8115 61]069 18]816 20)98] 1100 90.W 221613 6 )Y3 ]J 9803 8215 BM8.60 1668.)6 216622 1100 160.W 13031] 1 1813.)) 96.b 51.19 6108.95 1]8388 2)90.81 1200 2]100 29].Tt 8 8188 )) 9t BB 9611 8J]I 11 IPBi 51 1]10 69 12 W 96 ]0 289151 B 611313 9t St 8918 6]86.02 19W.Btl 2B01p 11.W 2>pW ]1111] 10 8650.W %33 9182 6362W 183580 318139 12W 90.W 3S5[r 93 ANNOTATIONS :t Tw nPO A fi35150 )100.00 T fi36150 )11000 KOP 6301 J1 )1]11.00 EM o1 6501 e9 ]3003 EW of 6J]0.09 )J]313 8 61J600 )303.)3 8 6109.93 )81313 ] 0100)3 8 6360 02 011313 9 6]62.06 0630.00 TO °°°' -- -- '"` Contact Information: ~,m„ - - - - Bill Michaelson Cell: 907-301-3570 Email : bill.michaelson@inleq.com - `.__ .T_ j + ~ I 13 P i. 11 11 ~•. ' I ~ II MA1 2 -__~. .-. - I I - a ~~ - - _ .. __ --. . ~ ~ t~ i t ~I f l i 1 D NA NL ' J __. - :5 .-.. ~0 _ ~- T i .. P 6 . .. 3 J i T S 1 -__ ~-.-_- i ~--~_ _ s .1. I _ I m I I I i i I j I I t ~ ~ ~ I ~ ~~ ~ I I I ~ ~ I I .. L. _ ~ ~ :_ ~. ~ I - I 4 I- I _I ~ I ~ I I I I ~ em aaol xNlror m I ~ ~ ~ I r l ~ I ~ ~ I I ~ I - i; .t ~ :~ t I I ~ ~ f I f I ~ ~ r ~ -- - 1 . l ~ l ~ I I I ! I I I ~ -- t I ~- ~ 1 _ - 7 I I l i I ~~ I I i ~ I I t I I -_ I ~ t J I:II I I II t I VII I Ir f II 'll~ ~~i 11- ~1 I t I 1 II:~ 1~,~ 't ~ ::l _ ~Il ~ 'I i-: I~ ) f ~ + -- - - I I _ __. , xlnl _WO Slwl II_0 SEW - SJNS JS_11 -W i W I6N0 1]60 364U 3 4_0 NKKI N1NU JI6U ~Nl J32U uNN JJPU J56U JNU venial se.Um n x3pl lxa luNl ConocoPhillips Type Toga Azimuth Organ Type WS EAY Fram ND User No Targa tfreehan0) BB.OO Sbt 000 0.00 000 io 00 ~ ms.oon nrelea: tcwertra Rivar Unn sne: tcw,.ax ro v.a „ , welt iDm `.. PIw: Ylanptl0-0YPlvn 1, 1D-0MI ~•~~~•~^ mw REFERENCE INFORMATION ___ Co-orGinate (N/E) Relemnce: We„ 7D-04, True North w m ~ °~ Vertical (ND) Refer :Mean Sea Level Section (VS) Reference cSbt - (O.OON, O.OOE) Meas retl Depth Rafere ce 1 D-O4 Q 105.00(1 Calwlalion Melhod:nMinimum Curvature t f Manual Wing Valve 3.1/8" SSV used as an ESD Check Valve Pressure Transducer Hose for flow in from Mud manifoltl Hose far flow out to Swaco Superchoke Manual Block Valves Double Swab Valves ~ Surface Safety Valve 't Master Valve Piping for flow cross, manual wing valve and ESD to be flanged connections. (Piping upstream from ESD to be 2" hammer unions. to be 1 ", 5000 psi, Arctic rated. ~ ~ TRANSMITTAL LETTER CHEC/KLIST WELL NAME /~/'~ lj{ /?,~ -'O `~~ PTD# L!~ ~ ~~ 7 V Development; Service Exploratory Stratigraphic Test Non-Conventional Well ~ ~ POOL: ~ / FIELD: _~~A~.- ~~ /< / v~-r ~~G-,u~~trt~ ©~ ( c~1~ f Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), atl records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingept upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional please note the following special condition of this permit: Welt production or production testing of coal bed methane is not allowed for (name of well) until after (Company Namel has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/1 !/2008 WELL ~}~~~~ GHECKL~$T Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNiT 1 D-04A Program DEV Well bore seg ^ PTD#:2080840 Company egNOCOPHILLIPSALASKA INC Inftial ClasslType DEV! PEND GeoArea 890 Unit 11160 On10ff Shore 4n Annular Disposal ^ Administration 1 Pe[roitfee attached- - - - - - - - - - - - - - - - - - - ~A- - - - - - - - - - - - - - - - - - - - - - - - - - - 2 Lease numberappropriate____________----_-------____---_---- Yes- ------Entire weft bore inADLQ25$50___________-------------___-------_--_-- 3 Uniquawell_nameandnumbe[--_-_-.------------------------_--- Yes- -- --- 4 !111e11 Iocaked in a-definedpool- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - _ - _KUPARUK RIVER,-KUPARUK RV Oll. - 490100, governed by Conservation Order No.4320._ - - - - - . _ _ 5 Well located proper distance from drilling unit_boundary- - - - - - - - - - - - - - - - _ - Yes - _ . _ Conservation Order No. 4320 contains no spacing restrictions with respect-t4 drilling unit boundaries. _ _ _ - - - _ 6 Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - _ - - - Conservation Order No. 4320 has no interwell spaeing.restrictions, - - - _ _ - - - - - - - - _ _ _ - _ _ - - - _ - - _ _ - 7 Sufficient aereageayailable in drilling un)t- - - - - - - - - - - - - - - - - - - _ - - - - Yes - - - _ . - Conservation Orde[ No. 4320 has no intenvell_spacing_rQStrictions, Wellbore-will be-more than 5Q0' from _ - _ _ _ _ 8 If deviated, is wellbore plat included _ _ _ - - _ - - - - _ - - - - - _ - - _ Yes - - _ - - _ an external property linewhe[eovmership or_land9wnershpchanges- - - - - - - - - - - - - - - - - - - - - - 9 Operator only affected party-- ---- - -- -- -- ----- Yes- -- - -- -- - -- --- - --- --- -- ----- -- -- --- 10 Operator bas_appropriatebor>dinfors~e------ -- - -- - ---- Yes - --- -- - - -- - ----------- ---- -- --- 11 Pemiikcanbeissuedwithoutconservafionorder___________________.------ Yes- --------------.------------------------------------------------ ---- Appr Date 12 PermikcahbeissuedwRhoutadministratipe_approval-------------------,- -- Yes- ------------------------------------------------------------------------ 13 Can perms be approved before 15-daywait - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - SFD 512812008 14 Well locatedwtthinareaandslrataauthorizedby_Injectkon0tder~(put10#in_comments)_(For_ Yes_ ---------_----------___-------------_---------.--------_-__-----__ 15 All wells withintf4_roileareaofreyiew)dentified(Forsenricewellonly)__-__-__---_-- ~-- ------------------___.----- 96 Pre-produced injectorduration_ofpre~taduc~ionlessthan3monihs_(Forssrvice~elionly)-- -NA- ----------------------------------------------------------------------- 17 NonGOnven. gas e9nfonna to AS31.05.030(y1.A)~(1.2.A-D) - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - Engineering 18 Conductor stringP-rovided---------------------------------------- -NA-- ------Conductor_setin1Q-04(179.994)•----------------------------------------- 19 Su_rfacecasingprotecisa4knownUSDWS_________-------------------- Nq- __-__Allaqurfersexempked,40CFR_147.102(b){3).---_---__-__-__-____-_---_-_-.--_---_.- 20 CMTvoladequate-tocirculate_oncon_ducto[&surfcsg_______________________ NA__ ____Surf_acecasingsetiniD-04._____________---_-___-__--_--__---_------_------- 21 CMT-voladequate_tctia-in_IOngstrirrg to surfcsg-------------------------- NA- ------Production-casing set in_1A-04,----------------------------------------------- 22 CMT-will cover all known-productiyehorizons_-__-_____-_-----_- -_--- No-- _-----Slotfedliner-completionplanned~_______________-__----_----_--_-__-_---_-- 23 Casing desgns adequate for C, T t3 &_pe_rroaf[ost- - - - - - - - - - - - - - - - - - - - - - - Yes - - - - _ - - Original welkroet design specifications. _ NA for slotted liner._ _ _ _ _ - - _ _ _ - _ - _ - - - _ - - - - 24 Adequate tankage or _reservepit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ - Rig equipped with steel pits, No reserve pit planned._ All waste_to approved disposal well(s), - - - . - _ - - _ 25 Ifa-re-drill,has_a10-403 for abandonmentbeerrapproved---------------------- Yes- ------308.182------------------------------------------------------------ 26 Adequate wehbore separation_ptoposed- - - - - - - - - - - - - - - - - - _ - - - - - - - _ . _ - Yes _ - - - - - Nearest segmentis abandoned portion of 1 D-Q4 and-pakhs diverge. - - - - - - - - _ - - - - - - - - - _ _ - - _ 27 If-d)verterrsquired,doesitmeekregulati9ns-----------------------__---_ NA _---SOPStack_willalreadY_beinplace,_____________-____-___---------_--__---_---. Appr Date 28 Drilling fluid RrQgraro schematic & equiplist adequate_ - - - - - - - - - -- - - - - - - - - - - Yes - - - _ - - _ Maximum expected formation pressure 8,8-EMW._ Managed pressure_driUing technique to be used_with 8,6_ppg - - TEM 5130!2008 29 BOPEs,.do they meetregulation - - - - - - - - - - - - - - - - - - - - - - - - - - - _ - Yes - _ - - - _ - - M1N-and applied pressure, Actual BH_EMW may be as high as_11,8:ppg to_roaintain constant-BkIP, _ _ _ - _ ~(~ ryy~ • 30 BOP)=.press rating appropriate; test ko_(put psig in c9mments)- - - - - - - - - - - - - - - - - - - - Yes - 80P iestplanged, _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ : _ - _ _ _ - _ . - - _ MASP calculated ai 2279psi, 3500_psi li 1 31 Chgke_roan'rfoldsAmplieswlAPl_RP-53(N1ay$4)___.-____------------------ Yes- = _ _ _ _ _______-____- 32 Work will9ccurwithoutoperalbnshutdown_-______-_____-__--__- -- Yes- -----.----------------------------------------------------------------- 33 1s presence of H2S gas probable - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ - - - _ _ H2$ is reported-at 1D pad. _Mud should preclude H2S on rig. _ Rig haasensors and alarms. - - - - - - - - - _ 34 _Mechanical condition of wells within AQR verified (FOrseNice well onlya - - - _ _ - - - _ - - - NA_ _ _ _ _ _ _ _ _ _ - - - - - - _ - ------------------------------------------------ Geology 35 Perroitcan be issuedw/o hydcogen_sulfidemsasures - - - - - - - - - - - - - - - - - - - - - - - - - N0. _ - _ _ _ _ _ KRU 1D-04 measured 69 ppm H2$ on J4ne 1$,_2096. H2S measures_required. _ _ _ . - - - - - - - - - _ .. - - - - - 36 Data_pteseoted on potential overpressurezone8_ . - - - - - - - - - - - - - - - - - - - - - Yes _ - - - _ - . RecentBHP-survey measured 8,8_ppg EMNL. - W_eh will be drilled using-coiledtubir~q rig with $.6ppg mud and- - _ Appr Date 37 Seismic-analysis-of shallow gaszones_ _ _ _ - _ - - - - _ - - - - - - - - - - - - - - - - _ _ _ _ NA_ _ _ _ _ _ - _ $00_psi_overbalancewill bemaintained on reservoir, _ _ _ _ _ _ _ _ _ _ - _ - - _ - . - - . - - - - - - - SFD 5128!2008 38 Seabed conditionsuryey_(ifoff-shore)---------------------------------- NA_ -__---_--------- 39 ContactnamelphoneforweekN-Rm3r'essreporls_[exploratcryonlyj----------------- NA- ----------------------.----------------------------------------------- Geologic Commissioner: Engineering Public Date: Commissioner: Date Commissioner Date ~'~~~~ s 3~~8 ~J
