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Home My WebLink About200-104Originated: Delivered to:12-Nov-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1D-30 50-029-22965-00 910358412 Kuparuk River Leak Detect Log Field- Final 14-Oct-25 0 12 1D-30 50-029-22965-00 910358412 Kuparuk River Multi Finger Caliper Field & Processed 15-Oct-25 0 13 1D-30 50-029-22965-00 910390851 Kuparuk River Packer Setting Record Field- Final 31-Oct-25 0 14 1E-02 50-029-20472-00 910390619 Kuparuk RiverMulti Finger CaliperField & Processed 28-Oct-25 0 15 1E-36 50-029-22927-00 910357198 Kuparuk River Tubing Cut Record Field- Final 19-Oct-25 0 16 2U-06 50-029-21282-00 910390614 Kuparuk River Multi Finger Caliper Field & Processed 19-Oct-25 0 17 3K-20 50-029-23019-00 910390195 Kuparuk River Packer Setting Record Field- Final 22-Oct-25 0 18 3R-17 50-029-22242-00 910433126 Kuparuk River Packer Setting Record Field- Final 11-Nov-25 0 1910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:200-104180-050198-213185-019201-088192-005T41088T41088T41088T41089T41090T41091T41092T41093Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.11.12 11:46:38 -09'00'200-1041D-3050-029-22965-00 910358412Kuparuk RiverLeakDetect LogField- Final14-Oct-25012 1D-3050-029-22965-00 910358412Kuparuk RiverMulti Finger CaliperField & Processed15-Oct-250131D-3050-029-22965-00 910390851KuparukRiverPacker Setting RecordField- Final31-Oct-2501 Originated: Delivered to:9-Oct-25Alaska Oil & Gas Conservation Commiss09Oct25-NR !"#$$%$ !&$$'($)*%+ ($)*%,-.WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED3T-613 50-103-20914-00-00 225-036 Kuparuk River WL TTiX-FSI FINAL FIELD 15-Sep-251D-30 50-029-22965-00-00 200-104 Kuparuk River WL Lee-LDL FINAL FIELD 21-Sep-253M-12 50-029-21719-00-00 187-050 Kuparuk River WL IPROF FINAL FIELD 28-Sep-252X-01 50-029-20963-00-00 183-084 Kuparuk River WL IPROF FINAL FIELD 30-Sep-25Transmittal Receipt//////////////////////////////// 0///////////////////////////////// + ! 1Please return via courier or sign/scan and email a copy to Schlumberger."2"3 +45 %TRANSMITTAL DATETRANSMITTAL #1 67 8" ! - +"8#!(3 . 8)"3 8#!9 3 : 8" +868 8 "8#!;" " 3 - 3" 3""+ 3 + <+3!% T40984T40985T40986T409871D-3050-029-22965-00-00200-104Kuparuk RiverWLLee-LDLFINAL FIELD21-Sep-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.10.10 08:21:47 -08'00' TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 1D-07 50-029-20430-00 179112_1D-07_SCMT_14Oct23 1D-11 50-029-22946-00 199072_1D-11_IPROF_04Apr2022 1D-117 50-029-22844-00 197237_1D-117_RBP_10Jun2022 1D-135 50-029-22816-00 197184_1D-135_LDL_05Jun2022 1D-30 50-029-22965-00 2000104_1D-30_Plug_11May2023 1D-34 50-029-22975-00 200143_1D-34_CHC_02Aug2022 1D-36 50-029-22973-00 200130_1D-36_RBP_19Jul2023 _1E-02 50-029-20472-00 180050_1E-02_CHC_29Mar2023 180050_1E-02_RBP_24Mar2023 _1E-102 50-029-23236-00 204231_1E-102_Pres-Temp_29Jul2023 _1E-12L1 50-029-20736-60 210004_1E-12_JetCutter_12Jun2022 210004_1E-12_MechCutter_06Jun2022 210004_1E-12_SBHPS-RBP-LDL_03Jun2022 2of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38317 T38318 T38321 T38322 T38323 T38324 T38325 T38326 T38327 T38328 2/29/2024 1D-30 50-029-22965-00 2000104_1D-30_Plug_11May2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:18:42 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 12044'feet N/A feet true vertical 6663'feet N/A feet Effective Depth measured 11807'feet 7876', 7896', 11161'feet true vertical 6554'feet 4782', 4791', 6261'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 11179' MD 6269' TVD Packers and SSSV (type, measured and true vertical depth) 7876' MD 7896' MD 11161' MD N/A 4782' TVD 4791' TVD 6261' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: Baker ZXP Liner Top Packer SSSV: None Jan Byrne jan.byrne@conocophillips.com (907) 659-7224Senior Well Integrity Specialist 11760-11816' 6533-6558' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 159 Gas-Mcf MD 1100 Size 110' 623 8401447 0 12000 155 measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-104 50-029-22965-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0028248 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1D-30 Plugs Junk measured Length Production Liner 11274' 888' Casing 6327' 3-1/2" 11305' 12041' 6659' 6839' 110'Conductor Surface Intermediate 16" 9-5/8" 75' 6873' 4341' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Jan Byrne DN: OU=Well Integrity, O=Conocophillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorge Alaska Date: 2023.06.07 13:51:29-08'00' Foxit PDF Editor Version: 12.0.1 Jan Byrne By Kayla Junke at 3:31 pm, Jun 07, 2023 DTTMSTART JOBTYP SUMMARYOPS 5/3/2023 REPAIR WELL RIH W/ 2.5" X 5' BAILER, S/D @ 8518' SLM, UNABLE TO WORK PAST (RECOVERED ASPHALTINES). PULLED OFF FOR HIGHER PRIORITY JOB, TO RETURN AFTER. JOB IN PROGRESS 5/4/2023 REPAIR WELL LRS PUMP 75 BBL DSL HOT, RUN 2.5" BAILER S/D @ 8520' SLM, METAL MARKS ON BAILER BOTTOM, RUN 2.70" LIB JOB IN PROGRESS 5/5/2023 REPAIR WELL RUN 2.74" TAPERED LIB TO 8520' SLM, RUN UP TO 2.25" BAILER TO 8544' SLM, WORKED 2.77" CENT FROM 8520' - 8530' SLM. JOB IN PROGRESS 5/6/2023 REPAIR WELL RUN 2.73" TAPERED LIB TO 8520' SLM, RUN UP TO 2.73" SWEDGE TO 8550' SLM RUN 2.50" BAILER TO SAME JOB IN PROGRESS 5/7/2023 REPAIR WELL RUN UP TO 2.81" BROACH TO 8545' SLM, RUN 2.72" PATCH DRIFT TO 8550' SLM, PULL STATION 6 GLV @11089' RKB. JOB IN PROGRESS 5/7/2023 REPAIR WELL CIRC OUT PUMPED 320 BBLS INHIBITED SW FOLLOWED BY 70 BBLS DSL DWN TBG TAKING RETURNS UP IA TO 1D-28 U TUBED FOR FREEZE PROTECT PERFORMED CMIT T x IA AT 2500 PSI - PASSED *SEE INFO BELOW BLED T x IA TO 1125 PSI 5/8/2023 REPAIR WELL SET DV IN ST#6 @ 11089' RKB. PULL EXT PKG DV / SET HIGH SEALABLILLITY OV IN ST#3 @ 7859' RKB. DRIFT 2.84" GAUGE RING TO CSV @ 11141' RKB, RUN 3-1/2 GR TO CSV @ 11141' RKB, EQUALIZE, BUT SHEAR GR. RIG DOWN FOR HIGHER PRIORITY WORK, JOB IN PROGRESS 5/9/2023 REPAIR WELL JARRED FOR 30min ON 3-1/2" DS-CSV @ 11141' RKB, NO MOVEMENT, IN PROGRESS 5/10/2023 REPAIR WELL PULLED DS-CSV FROM 11141' RKB. BRUSH & FLUSK TBG DOWN TO 7950' SLM, FOCUSED ON 7800' - 7950' SLM, READY FOR PATCH, 5/11/2023 REPAIR WELL SET 2.725" PIIP LOWER PACKER W/ MOE = 7898' RKB, CCL TO MID ELEMENT = 9.75', CCL STOP DEPTH = 7888.25', CORRELATED TO LDL DATED 3-14-23 (CONFIRMED W/ TALLY DATED 8-12-2000). JOB IS READY FOR SL SERIAL #: CPP35198 5/13/2023 REPAIR WELL RAN TTS TEST TOOL TO P2P LOWER PACKER @ 7898' RKB, PERFORMED PASSING CMIT-TxIA @ 2500psi. SET TTS P2P UPPER PACKER & SPACER PIPE (22' MID ELEMENT TO MID ELEMENT) @ 7876' RKB. RAN TTS TEST TOOL TO UPPER PACKER, PERFORMED PASSING MIT-T & CMIT-TxIA @ 2500psi, PULLED TEST TOOL, JOB COMPLETE P2P PACKER # CPP35335 ANCHOR LATCH# CPAL35202 1D-30 Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:11,807.0 1D-30 8/16/2004 WV5.3 Conversion Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set upper patch 1D-30 5/13/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: 1D-30L1 WELLBORE ADDED 9/8/2004 osborl General Notes: Last 3 entries Com Date Last Mod By CTD SIDETRACK 9/2004, WITH FLOW TO SURFACE INJECTION VALVE IN ORIGINAL MAIN WELLBORE YIELDING TWO PRODUCING LEGS 9/8/2004 Admin ORIGINAL COMPLETION AND CTD COMPLETION LEG A ARE BOTH PRODUCING 9/8/2004 Admin Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.06 35.0 110.0 110.0 62.58 H-40 WELDED SURFACE 9 5/8 8.83 34.4 6,873.5 4,341.3 40.00 L-80 BTC-MOD PRODUCTION 7 6.28 30.9 11,305.4 6,327.0 26.00 L-80 BTC-MOD WINDOW 4 3.00 11,710.0 11,720.0 6,514.4 9.30 LINER 3 1/2 2.99 11,153.3 12,041.0 6,659.5 9.30 L-80 SLHT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 30.4 Set Depth 11,178.6 Set Depth 6,268.8 String Ma 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 30.4 30.4 0.02 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 527.3 527.3 2.29 NIPPLE 4.540 CAMCO DS NIPPLE w/ NO GO PROFILE 2.875 3,030.1 2,616.1 62.71 GAS LIFT 5.968 CAMCO MMG 2.920 6,037.4 3,976.9 63.69 GAS LIFT 5.968 CAMCO MMG 2.920 7,859.4 4,775.0 63.52 GAS LIFT 5.968 CAMCO MMG 2.920 9,366.9 5,447.0 63.25 GAS LIFT 5.968 CAMCO MMG 2.920 10,574.3 5,996.3 63.83 GAS LIFT 5.968 CAMCO MMG 2.920 11,089.4 6,228.3 63.12 GAS LIFT 5.968 CAMCO MMG 2.920 11,141.4 6,251.8 62.97 NIPPLE 3.500 CAMCO DS NIPPLE w/ NO GO PROFILE 2.813 11,177.2 6,268.2 62.81 SEAL ASSY 5.125 BAKER NO GO LOCATOR/GBH-22 SEA ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,876.0 4,782.4 63.50 PACKER - PATCH - UPR UPPER PACKER ASSEMBLY P2P PACKER, XO, SPACER PIPE, & ANCHOR LATCH (OAL 23.94') TTS P2P CPP3 5335/ CPAL 35202 5/13/2023 1.625 7,878.1 4,783.4 63.49 SPACER PIPE Spacer pipe (INCLUDED IN UPPER PATCH ASSEMBLY) 5/13/2023 1.600 7,881.0 4,784.7 63.49 LEAK - TUBING LEAK IDENTIFIED ON LDL RUN 3/14/23 3/14/2023 2.992 7,890.0 4,788.7 63.48 LEAK - TUBING LEAK IDENTIFIED ON LDL RUN 3/14/23 3/14/2023 2.992 7,895.6 4,791.2 63.47 PACKER - PATCH - LWR 2.725" PIIP LOWER PACKER W/ MOE = 7898' RKB, OAL = 4.01' TTS PIIP CPP3 5198 5/11/2023 1.625 11,710.0 6,509.9 63.18 WHIPSTOCK FLO-THRU WHIPSTOCK 8/20/2004 2.992 11,727.0 6,517.6 63.08 VALVE WEATHERFORD FTS STANDING VALVE - PRE- LATERAL DRILL 8/24/2004 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 3,030.1 2,616.1 62.71 1 GAS LIFT GLV RK 1 1/2 1,232.0 3/5/2023 0.188 6,037.4 3,976.9 63.69 2 GAS LIFT GLV RK 1 1/2 1,299.0 3/5/2023 0.188 7,859.4 4,775.0 63.52 3 GAS LIFT OV RK 1 1/2 0.0 5/8/2023 High Seala bility PKG 0.188 9,366.9 5,447.0 63.25 4 GAS LIFT DMY RK 1 1/2 0.0 8/19/2012 0.000 10,574.3 5,996.3 63.83 5 GAS LIFT DMY RK 1 1/2 0.0 8/19/2012 0.000 11,089.4 6,228.3 63.12 6 GAS LIFT DMY RK 1 1/2 0.0 5/8/2023 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 11,153.3 6,257.3 62.92 TIEBACK 6.000 LINER TIE BACK SLEEVE 5.250 11,160.6 6,260.6 62.89 PACKER 7.000 BAKER 5x7" ZXP LINER TOP PACKER w/ 5" RS NIPPLE & TCK COUPLING 5.250 11,237.8 6,295.9 62.65 NIPPLE 4.520 XN NIPPLE w/2.75" NO GO 2.750 1D-30, 6/5/2023 10:43:59 AM Vertical schematic (actual) LINER; 11,153.3-12,041.0 RPERF; 11,796.0-11,816.0 FRAC; 11,800.0 IPERF; 11,800.0-11,805.0 APERF; 11,760.0-11,800.0 VALVE; 11,727.0 WINDOW; 11,710.0-11,720.0 WHIPSTOCK; 11,710.0 L1 LINER; 11,465.7-13,516.0 SLOTS; 11,478.8-13,503.5 PRODUCTION; 30.9-11,305.4 GAS LIFT; 11,089.4 GAS LIFT; 10,574.3 GAS LIFT; 9,366.9 PACKER - PATCH - LWR; 7,895.6 LEAK - TUBING; 7,890.0 SPACER PIPE; 7,878.1 LEAK - TUBING; 7,881.0 PACKER - PATCH - UPR; 7,876.0 GAS LIFT; 7,859.4 SURFACE; 34.4-6,873.5 GAS LIFT; 6,037.4 GAS LIFT; 3,030.1 NIPPLE; 527.3 CONDUCTOR; 35.0-110.0 KUP PROD KB-Grd (ft) 36.60 RR Date 8/12/2000 Other Elev 1D-30 ... TD Act Btm (ftKB) 12,044.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292296500 Wellbore Status PROD Max Angle & MD Incl (°) 65.24 MD (ftKB) 6,099.48 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NIPPLE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 11,974.8 6,630.2 63.69 LANDING COLLAR 3.500 2.992 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 11,760.0 11,800.0 6,532.6 6,550.8 C-3, C-2, 1D-30 3/26/2001 4.0 APERF 2.5" HC, DP, 60/120 deg ph 11,796.0 11,816.0 6,549.0 6,558.1 C-2, 1D-30 3/26/2001 4.0 RPERF 2.5" HC, DP, 60/120 deg ph 11,800.0 11,805.0 6,550.8 6,553.1 C-2, 1D-30 8/19/2000 4.0 IPERF 2.5 HSD Big Hole; orntd 0 & 180 f/high side Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 11,800.0 11,805.0 1 FRAC 8/21/2000 0.0 0.00 0.00 1D-30, 6/5/2023 10:44:02 AM Vertical schematic (actual) LINER; 11,153.3-12,041.0 RPERF; 11,796.0-11,816.0 FRAC; 11,800.0 IPERF; 11,800.0-11,805.0 APERF; 11,760.0-11,800.0 VALVE; 11,727.0 WINDOW; 11,710.0-11,720.0 WHIPSTOCK; 11,710.0 L1 LINER; 11,465.7-13,516.0 SLOTS; 11,478.8-13,503.5 PRODUCTION; 30.9-11,305.4 GAS LIFT; 11,089.4 GAS LIFT; 10,574.3 GAS LIFT; 9,366.9 PACKER - PATCH - LWR; 7,895.6 LEAK - TUBING; 7,890.0 SPACER PIPE; 7,878.1 LEAK - TUBING; 7,881.0 PACKER - PATCH - UPR; 7,876.0 GAS LIFT; 7,859.4 SURFACE; 34.4-6,873.5 GAS LIFT; 6,037.4 GAS LIFT; 3,030.1 NIPPLE; 527.3 CONDUCTOR; 35.0-110.0 KUP PROD 1D-30 ... WELLNAME WELLBORE 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Offset for Marcit Trtmnt Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured feet None feet true vertical feet None feet Effective Depth measured feet 7876', 7896', 11161' feet 4782', 4791', 6261' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 11179' MD 6269' TVD Packers and SSSV (type, measured and true vertical depth) 7876' MD 7896' MD 11161' MD N/A 4782' TVD 4791' TVD 6261' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 6873' 4341' Burst Collapse 11274' 888' Casing 6327' 3-1/2" 11305' 6839' 110'Conductor Surface Intermediate 16" 9-5/8" 75' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 200-104 50-029-22965-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0028248 Kuparuk River Field/ Kuparuk River Oil Pool KRU 1D-30 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 110' ~ ~~ ~~ ~ Production N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: Baker ZXP Liner Top Packer SSSV: None Allen Eschete allen.eschete@conocophillips.com (907) 265-6558Interventions Engineer 11760-11800', 11796-11816', 6533-6551', 6549-6558' Offset Injector remains Shut-in Liner Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov 12044' 6661' 12044' true vertical feet6661' 12041' 6660' By Grace Christianson at 3:12 pm, May 22, 2023 Digitally signed by Allen Eschete DN: CN=Allen Eschete, E=Allen.Eschete@ ConocoPhillips.com Reason: I have reviewed this document Location: Date: 2023.05.22 11:24:51-08'00' Foxit PDF Editor Version: 12.0.1 Allen Eschete DTTMSTART JOBTYP SUMMARYOPS 3/29/2023 SUPPORT OTHER OPERATIONS PULLED 4.5" SLIP STOP & CHOKE @ 541' RKB; BRUSH n' FLUSHED D-NIPPLE @ 11,008' RKB; SET 2.25" CA-2 PLUG @ 11,008' RKB. READY FOR E-LINE IPROF.ttttt 4/1/2023 SUPPORT OTHER OPERATIONS PERFORM INJECTION PROFILE. WELL INJECTING AT 6250 BWPD, 900 PSI. PERFORM UP/DOWN PASS AND VERIFY ALL INJECTION IS GOING INTO LATERAL 2, CONFIRMED PLUG IN LATERAL 1 IS HOLDING (NO INJECTION INTO L1). JOB COMPLETE 4/19/2023 SUPPORT OTHER OPERATIONS Continue rigging up, spotting up equipment. Stage liquid and dry product. Troubleshoot generator issues. Perform safety / operations pre job walk down. Freeze protect 1D-11 flow line and 1D-10 tubing. Fill tank farm tanks with seawater from process line. Flood SNF mixing unit. Calibrate gel mixer, verify skid function. Performed step rate test, start 4000 ppm Marcit non cross linked, SNF skid unable to deliver mixed product at rate to LRS pump. Troubleshoot issue. 200 bbl polymer injected. No cross linker. - In Progress- 4/20/2023 SUPPORT OTHER OPERATIONS Continue to troubleshoot SNF skid mixing issues. Replace automated mixing tank valve, adjust marcit mother solution concentration and dilution pump ratios, trial changes on non cross linked gel, begin to pump stage #1, 4000 ppm Marcit polymer with Chromic Acetate cross linker @ maximum rate, skid performance limited, of 3 bpm. Totals - 3,199 bbls 4k gel stage one, WH 1,225 psi. - In Progress- 4/21/2023 SUPPORT OTHER OPERATIONS Pumped 3,650 bbls, 4k ppm Marcit gel in stage #1. Well head climbed from 1,225 to 1,300 psi, total gel pumped in stage one is 6,849 bbls. Main generator powering NSF skid started shutting down @ 22:00. Trouble shoot and restart multiple times. 1D-28 and 1D-41 floc tests both negative. - In Progress- 4/22/2023 SUPPORT OTHER OPERATIONS Continue to troubleshoot generator with nights field mechanic with no success. Flush and FP X-linked Marcit from surface with 120 bbl's diesel. Request replacement generator. Wrap and heat additional surface lines. Spot replacement generator and stand by for electricians to disconnect / reconnect. Electricians determined replacement generator not compatible with bolt up connections. Stand by for days field mechanic. Mechanic restarted generator, test run for 1 hr, energize NSF skid, test run. On line with 4000 ppm Marcit to establish injection. Pumped remaining 4000 ppm cross linked stage #1 - 7,639 bbls. Start pumping stage two, 5000 ppm Marcit 1D-28 and 1D-41 floc tests both negative. Total stage #2, 2,063 bbls - total vol. treatment 9,701 bbls - In Progress- 4/23/2023 SUPPORT OTHER OPERATIONS Pumped 4,230 bbls, 5k ppm Marcit gel in stage #2. Well head climbed from 1,475 to 1,550 psi. 1D-28 and 1D-41 floc tests both negative. Total stage #2, 6,293 bbls - total vol. treatment 13,931 bbls - In Progress- 4/24/2023 SUPPORT OTHER OPERATIONS Completed stage two, 7,804 bbls 5000 ppm Marcit. Completed stage three, 798 bbls 6000 ppm Marcit. Started stage four, 8000 ppm Marcit. Total stage #4, 1,293 bbls - total vol. treatment 17,534 bbls. Well head built from 1,325 psi to 1,450 psi during stage #4. 1D-28 and 1D-41 floc tests both negative. - In Progress- 4/25/2023 SUPPORT OTHER OPERATIONS Completed stage four, 2,108 bbls total of 8,000 ppm Marcit. Started final stage five, 10,000 ppm Marcit. Total stage #5, 1,205 bbls - total vol. treatment 19,553 bbls. Well head built from 1,500 psi to 1,700 psi during stage #4 & 5. 1D-28 and 1D-41 floc tests both negative. - In Progress- 1D-11 Marcit Treatment 4/26/2023 SUPPORT OTHER OPERATIONS Pumped stage five, 10,000 ppm Marcit to completion. Flushed Marcit with 147 bbls water and 35 bbls diesel FP. Contacted PE to flag well 'do not inject'. FP seawater header flow line on 1D-10 with 10 bbls MetOH. Vac our surface lines, upright tanks and SNF skid. Job complete. Begin rig down of treating equipment. Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:11,807.0 1D-30 8/16/2004 WV5.3 Conversion Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set upper patch 1D-30 5/13/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: 1D-30L1 WELLBORE ADDED 9/8/2004 osborl General Notes: Last 3 entries Com Date Last Mod By CTD SIDETRACK 9/2004, WITH FLOW TO SURFACE INJECTION VALVE IN ORIGINAL MAIN WELLBORE YIELDING TWO PRODUCING LEGS 9/8/2004 Admin ORIGINAL COMPLETION AND CTD COMPLETION LEG A ARE BOTH PRODUCING 9/8/2004 Admin Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 16 15.06 35.0 110.0 110.0 62.58 H-40 WELDED SURFACE 9 5/8 8.83 34.4 6,873.5 4,341.3 40.00 L-80 BTC-MOD PRODUCTION 7 6.28 30.9 11,305.4 6,327.0 26.00 L-80 BTC-MOD WINDOW 4 3.00 11,710.0 11,720.0 6,514.4 9.30 LINER 3 1/2 2.99 11,153.3 12,041.0 6,659.5 9.30 L-80 SLHT Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 30.4 Set Depth 11,178.6 Set Depth 6,268.8 String Ma 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 30.4 30.4 0.02 HANGER 8.000 FMC GEN V TUBING HANGER 3.500 527.3 527.3 2.29 NIPPLE 4.540 CAMCO DS NIPPLE w/ NO GO PROFILE 2.875 3,030.1 2,616.1 62.71 GAS LIFT 5.968 CAMCO MMG 2.920 6,037.4 3,976.9 63.69 GAS LIFT 5.968 CAMCO MMG 2.920 7,859.4 4,775.0 63.52 GAS LIFT 5.968 CAMCO MMG 2.920 9,366.9 5,447.0 63.25 GAS LIFT 5.968 CAMCO MMG 2.920 10,574.3 5,996.3 63.83 GAS LIFT 5.968 CAMCO MMG 2.920 11,089.4 6,228.3 63.12 GAS LIFT 5.968 CAMCO MMG 2.920 11,141.4 6,251.8 62.97 NIPPLE 3.500 CAMCO DS NIPPLE w/ NO GO PROFILE 2.813 11,177.2 6,268.2 62.81 SEAL ASSY 5.125 BAKER NO GO LOCATOR/GBH-22 SEA ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,876.0 4,782.4 63.50 PACKER - PATCH - UPR UPPER PACKER ASSEMBLY P2P PACKER, XO, SPACER PIPE, & ANCHOR LATCH (OAL 23.94') TTS P2P CPP3 5335/ CPAL 35202 5/13/2023 1.625 7,878.1 4,783.4 63.49 SPACER PIPE Spacer pipe (INCLUDED IN UPPER PATCH ASSEMBLY) 5/13/2023 1.600 7,881.0 4,784.7 63.49 LEAK - TUBING LEAK IDENTIFIED ON LDL RUN 3/14/23 3/14/2023 2.992 7,890.0 4,788.7 63.48 LEAK - TUBING LEAK IDENTIFIED ON LDL RUN 3/14/23 3/14/2023 2.992 7,895.6 4,791.2 63.47 PACKER - PATCH - LWR 2.725" PIIP LOWER PACKER W/ MOE = 7898' RKB, OAL = 4.01' TTS PIIP CPP3 5198 5/11/2023 1.625 11,710.0 6,509.9 63.18 WHIPSTOCK FLO-THRU WHIPSTOCK 8/20/2004 2.992 11,727.0 6,517.6 63.08 VALVE WEATHERFORD FTS STANDING VALVE - PRE- LATERAL DRILL 8/24/2004 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 3,030.1 2,616.1 62.71 1 GAS LIFT GLV RK 1 1/2 1,232.0 3/5/2023 0.188 6,037.4 3,976.9 63.69 2 GAS LIFT GLV RK 1 1/2 1,299.0 3/5/2023 0.188 7,859.4 4,775.0 63.52 3 GAS LIFT OV RK 1 1/2 0.0 5/8/2023 High Seala bility PKG 0.188 9,366.9 5,447.0 63.25 4 GAS LIFT DMY RK 1 1/2 0.0 8/19/2012 0.000 10,574.3 5,996.3 63.83 5 GAS LIFT DMY RK 1 1/2 0.0 8/19/2012 0.000 11,089.4 6,228.3 63.12 6 GAS LIFT DMY RK 1 1/2 0.0 5/8/2023 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 11,153.3 6,257.3 62.92 TIEBACK 6.000 LINER TIE BACK SLEEVE 5.250 11,160.6 6,260.6 62.89 PACKER 7.000 BAKER 5x7" ZXP LINER TOP PACKER w/ 5" RS NIPPLE & TCK COUPLING 5.250 11,237.8 6,295.9 62.65 NIPPLE 4.520 XN NIPPLE w/2.75" NO GO 2.750 1D-30, 5/16/2023 4:36:43 PM Vertical schematic (actual) LINER; 11,153.3-12,041.0 RPERF; 11,796.0-11,816.0 FRAC; 11,800.0 IPERF; 11,800.0-11,805.0 APERF; 11,760.0-11,800.0 VALVE; 11,727.0 WINDOW; 11,710.0-11,720.0 WHIPSTOCK; 11,710.0 L1 LINER; 11,465.7-13,516.0 SLOTS; 11,478.8-13,503.5 PRODUCTION; 30.9-11,305.4 GAS LIFT; 11,089.4 GAS LIFT; 10,574.3 GAS LIFT; 9,366.9 PACKER - PATCH - LWR; 7,895.6 LEAK - TUBING; 7,890.0 SPACER PIPE; 7,878.1 LEAK - TUBING; 7,881.0 PACKER - PATCH - UPR; 7,876.0 GAS LIFT; 7,859.4 SURFACE; 34.4-6,873.5 GAS LIFT; 6,037.4 GAS LIFT; 3,030.1 NIPPLE; 527.3 CONDUCTOR; 35.0-110.0 KUP PROD KB-Grd (ft) 36.60 RR Date 8/12/2000 Other Elev 1D-30 ... TD Act Btm (ftKB) 12,044.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292296500 Wellbore Status PROD Max Angle & MD Incl (°) 65.24 MD (ftKB) 6,099.48 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NIPPLE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 11,974.8 6,630.2 63.69 LANDING COLLAR 3.500 2.992 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 11,760.0 11,800.0 6,532.6 6,550.8 C-3, C-2, 1D-30 3/26/2001 4.0 APERF 2.5" HC, DP, 60/120 deg ph 11,796.0 11,816.0 6,549.0 6,558.1 C-2, 1D-30 3/26/2001 4.0 RPERF 2.5" HC, DP, 60/120 deg ph 11,800.0 11,805.0 6,550.8 6,553.1 C-2, 1D-30 8/19/2000 4.0 IPERF 2.5 HSD Big Hole; orntd 0 & 180 f/high side Stimulation Intervals Top (ftKB)Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 11,800.0 11,805.0 1 FRAC 8/21/2000 0.0 0.00 0.00 1D-30, 5/16/2023 4:36:45 PM Vertical schematic (actual) LINER; 11,153.3-12,041.0 RPERF; 11,796.0-11,816.0 FRAC; 11,800.0 IPERF; 11,800.0-11,805.0 APERF; 11,760.0-11,800.0 VALVE; 11,727.0 WINDOW; 11,710.0-11,720.0 WHIPSTOCK; 11,710.0 L1 LINER; 11,465.7-13,516.0 SLOTS; 11,478.8-13,503.5 PRODUCTION; 30.9-11,305.4 GAS LIFT; 11,089.4 GAS LIFT; 10,574.3 GAS LIFT; 9,366.9 PACKER - PATCH - LWR; 7,895.6 LEAK - TUBING; 7,890.0 SPACER PIPE; 7,878.1 LEAK - TUBING; 7,881.0 PACKER - PATCH - UPR; 7,876.0 GAS LIFT; 7,859.4 SURFACE; 34.4-6,873.5 GAS LIFT; 6,037.4 GAS LIFT; 3,030.1 NIPPLE; 527.3 CONDUCTOR; 35.0-110.0 KUP PROD 1D-30 ... WELLNAME WELLBORE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: 1D-30L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: GLV C/O 1D-30L1 8/20/2012 ninam Notes: General & Safety Annotation End Date Last Mod By NOTE: 1D-30L1 WELLBORE ADDED 9/8/2004 osborl General Notes: Last 3 entries Com Date Last Mod By CTD SIDETRACK 9/2004, WITH FLOW TO SURFACE INJECTION VALVE IN ORIGINAL MAIN WELLBORE YIELDING TWO PRODUCING LEGS 9/8/2004 Admin ORIGINAL COMPLETION AND CTD COMPLETION LEG A ARE BOTH PRODUCING 9/8/2004 Admin Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread L1 LINER 2 3/8 2.00 11,465.7 13,516.0 6,534.2 4.70 L-80 STL Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 11,465.7 6,399.6 63.02 DEPLOY 2.650 L1 LINER BAKER DEPLOYMENT SLEEVE (2.25" POLISHED BORE) FOR LATERAL L1 set 9/8/2004 1.995 13,503.5 6,534.4 90.75 O-RING 2.380 BAKER O-RING SUB 1.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,478.8 13,503.5 6,405.5 6,534.4 C-1, C-2, C-1, 1D-30L1 9/8/2004 8.0 SLOTS 2-3/8" PRE-DRILLED LINER 1D-30L1, 5/16/2023 4:36:47 PM Vertical schematic (actual) L1 LINER; 11,465.7-13,516.0 SLOTS; 11,478.8-13,503.5 LINER; 11,153.3-12,041.0 PRODUCTION; 30.9-11,305.4 GAS LIFT; 11,089.4 GAS LIFT; 10,574.3 GAS LIFT; 9,366.9 PACKER - PATCH - LWR; 7,895.6 LEAK - TUBING; 7,890.0 SPACER PIPE; 7,878.1 LEAK - TUBING; 7,881.0 PACKER - PATCH - UPR; 7,876.0 GAS LIFT; 7,859.4 SURFACE; 34.4-6,873.5 GAS LIFT; 6,037.4 GAS LIFT; 3,030.1 NIPPLE; 527.3 CONDUCTOR; 35.0-110.0 KUP PROD KB-Grd (ft) 36.60 RR Date 8/12/2000 Other Elev 1D-30L1 ... TD Act Btm (ftKB) 13,715.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292296560 Wellbore Status PROD Max Angle & MD Incl (°) 96.68 MD (ftKB) 13,382.87 WELLNAME WELLBORE1D-30 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Imag~roject Well History File Cover~mge 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. o_9- RES(~AN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. ~/' Maps: [] Grayscale items: 1:3 Other, No/Type [] Other items scannable by large scanner [:3 Poor Quality Originals: OVERSIZED (Non-Scannable) n Other: [] o Logs of various kinds NOTES: -* Other Scanning Preparation ~ x 30 = ~)~) + ~:? = 'OTALPAG,S ?._~"J Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES ..,: Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPA~E FOUND'. YES (SCANNING IS COMPLETE AT THIS POINT UNLESS ~PEClAL ATTENTION IS REQUIRED ON ~JJ~/tDUAL PAGE BASIS ~ DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) NO NO RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: IsI General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd . . Conoc~illips Alaska RECEIVED AUG 2 9 2007 Araska Oir & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 23, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 sCANNED SEP 0 6 2001 ~fJO - .l <? Lf Dear Mr. Maunder: Enclosed please.find a spreadsheet with a list of wells trom the Kuparuk field (KRU). Each of these wells was fôund to have a void in the conductor. These voids were filled with a corròsion inhibitor, engineered to prevent water trom entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 1 0~404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped between August 19 & 21, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907~659-7043, if you have any questions. ;~:j~~. M.J.¿el~d ConocoPhiIlips Well futegrlty Projects Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/21/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date -- ft bbls ft Qal 1 0-28 204-237 18" N/A N/A N/A 10 8/19/2007 10-30 200-104 24" N/A N/A N/A 6.5 8/19/2007 1 0-34 200-143 14" N/A N/A N/A 4 8/19/2007 10-12 199-084 1" N/A N/A N/A 1.7 8/20/2007 10-14 199-089 2" N/A N/A N/A 3.4 8/20/2007 10-140 200-136 29'9" 3.4 12" 12/16/2006 14.5 8/20/2007 10-141 200-112 SF N/A N/A N/A 0.5 8/20/2007 -1C-11 199-172 - SF NA NA NA _]).5 8/21/2007 1C-12 196-177 SF NA NA NA 0.5 8/21/2007 1C-15 198-229 SF NA NA NA 0.5 8/21/2007 1C-16 198-246 22" NA NA NA 8 8/21/2007 1C-17 198-224 17" NA NA NA 1.7 8/21/2007 1C-18 199-005 SF NA NA NA 0.5 8/21/20Q7 1 C-24 201-248 20" NA NA NA 11 8/21/2007 1C-26 199-051 3" NA NA NA 0.85 8/21/2007 1 C-27 199-043 4" NA NA NA 1.7 8/21/2007 1 C-28 205-104 SF NA NA NA 0.5 8/21/2007 1 C-117 201-121 26" NA NA NA 12.3 8/21/2007 F:\LaserFiche\CvrPgs _Inserts\Microfilm _ Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ......i.'.. ~,. "':'" ~~. ....... ~" " '. " 1101, ) ) cLds,l. "jELL LOG TRANSMITTAL ) a~O-(ot ~ ocr 1 .2: 2004 ProActive Diagnostic Services, 'nc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage. Alaska 99501 RE: Distribution - Final Print[sJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR BLUE LINE Open Hole 1 Res. Eva!. CH 1 1 1 Mech. CH 1 0-30 8-16-04 Caliper Survey 1 Rpt or 2 Color Signed:~. ~ ~~ Print Name: c/kj;¡J.r tr.Iv-,u¡{U.,l Date : /0 po /of PRoAcTivE DiAGNOSTic SERVicES, INC., PO Box I }b9 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 . F\ E-mail\l)9S~wnorylog.com Website: www.memorylog.com SCANNEl) NO" h 5 '- . d ð'O -/0 1 Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 10-30 Log Date: August 16, 2004 Field: Kuparuk Log No.: 5488 State: Alaska Run No.: 1 API No.: 50-029-21651-00 Pipe1 Desc.: 3.5" 9.3 lb. L-80 Top Log Intvl1.: 10,793 Ft. (MO) Pipe1 Use: Tubing Bot. Log Intvl1.: 11,789 Ft. (MO) Inspection Type: Side Track Candidacy Inspection COMMENTS: This caliper data is tied into the XN Nip @ 11,242' (Driller's Depth). This log was run to assess the condition of the tubing and liner with respect to corrosive and mechanical damage to determine potential side track candidacy. The caliper recordings indicate that the interval of 3.5" tubing logged is in good to fair condition. A 23% and 20% wall penetration are recorded in joints 351 and 355 respectively. The damage recorded appears in the form of shallow general corrosion and isolated pitting. The remainder and majority of the tubing logged appears to be in good condition. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded. A 3-D Log Plot of the caliper recordings across the proposed whipstock placement interval is included in this report. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. The joint numbering used in this report is an estimation based on average joint length. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting Shallow Pitting ( 23%) ( 20%) Jt. Jt. 351 355 @ @ 10,998 Ft. (MD) 11,212 Ft. (MD) No other significant wall penetrations (> 19%) are recorded throughout the interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 12%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. I Field Engineer: R.A. Richey Analyst: M. Lawrence Witness: M. Chaney I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ( ð(c-l-(, r Q. Well: Field: Company: Country: 1 D-30 Kuparuk ConocoPhillips Alaska, Inc. USA Tubing: Weight 9.3 f Grade & Thread L-80 Nom.OD 3.5 ins Penetration and Metal Loss (% wall) - penetration body 40 - metal loss body 30 20 10 0 0 to 1% 1 to 10% 10 to 20 to 40 to over 20% 40% 85% 85% NumQ~"of joints analysed (tot(il= 35) . pene. 0 6 28 1 0 loss 0 34 1 0 0 0 0 Damage Configuration ( body) 20 10 0 isolated pitting general line ring hole I poss corrosion corrosion corrosion ihle hole 0 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Rngers: Analyst: Nom.lD 2.992 ins August 16, 2004 MFC 24 No. 99628 1.69 24 M. Lawrence Upper Jen. 1.2 ins Lower len. 1.2 ins Nom. Upset 3.5 ins Damage Profile (% wall) - penetration body 0 344 - metal loss body 50 100 GLM6 359 369 Bottom of Survey = 373 Analysis Overview page 2 Q PDS Multifinger Caliper 3D Log Plot Company: ConocoPhilllps Alaska, Inc. Field: Kuparuk Well: 10-30 Date: August 16, 2004 Description: Detail of Caliper Recordings Across Proposed Whipstock Placement II: '" Dl;nn IIIN In 1111nnn in \ 1~nn IIAYln . ,\ '~nß -- ...-.. m_._. ,",. ¡.y" --- - -- --- - - -- -.. --- 11660 Joint 369 - -. -- -.-. -- -" -. - .-- --.- - -- -- )- -- .~- 11670 -. .- -.. 11680 1 Joint 370 11690 » 11700 ~ --- t ~ ] '..'Y-l'".' 11710 ~ -- " - /¡i~ ~W; , 11720 Joint 371 ,,'<, .; ¡u;;j!i 1 -". -- jr 11730 --- . .., ÍI!J I-- -- 1--- t 11740 j ;> Joint 372 I-- --- -- ...:II"'" " '1 « AA""A l Wi' 4J ~ '" ,§. ~ i 0.14 Q .... ¡;: Q PDS Caliper Statistical Evaluation Report Well: Field: Company: Country: Survey Date: Tool: Tool Size: Tubing 1.0.: Tubing 0.0.: Wall Thickness: MFC 24 No. 99628 1.69 inches 2.992 inches 3.5 inches 0.254 inches 10-30 Kuparuk ConocoPhillìps Alaska Inc. USA August 16, 2004 10 Percent Probability of Hole 20 50 tOO 0.24 Standard Deviation n,.o " .11 . of v,"", 'u.. 0.005 - - - ¡.- - - - . I- ~ ¡.. - - - - - ~ -- - - ----- -- - '- --- ---- ---- -- -- --f- .... 0.19 0.09 0.04 0.1 10 Average Rank Maximum Probable Penetration* 0.060 inches (23.8 % Wall Thidnen) Percent Probability of Recording a Hole* Less than 10% . Derived from data with average rank value less than or equal to 20. 100 Pipe: Body Wall: Upset Wall: NominaILD.: Joint No. 344 345 346 347 348 349 350 351 352 352.1 352.2 352.3 353 353.1 353.2 353.3 354 354.1 354.2 354.3 355 355.1 356 I 357 358 359 360 361 362 363 364 365 366 367 368 369 370 371 372 373 Jt. Depth (Ft.) 10793 10810 10841 10872 10904 10935 1 0966 10998 11029 11061 11066 11075 11082 11113 11119 11120 11126 11158 11164 11201 11207 11242 11243 11275 11305 11336 11366 11397 11428 11459 11490 11521 11552 11582 11613 11644 11675 11706 11737 11764 PDS REPORT JOINT TABULATION SHEET 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Pen. Pen. Upset Body (Ins.) (Ins.) 0 0.03 0 0.04 0 0.04 0 0.03 0 0.04 () 0.04 0 0.05 () 0.06 () 0.04 0 0.03 () 0 () 0.03 0 0.05 () 0.04 () 0 () 0.03 () 0.04 0 0.03 () 0 0 0 0 0.05 0 0 0 0.04 0 0.02 () 0.03 () 0.03 0 0.03 0 0.05 0 0.04 0 0.02 () 0.04 0 0.03 () 0.03 () 0.04 0 0.03 0 0.03 0 0.03 0 0.02 () 0.02 0 0.01 Pen. Metal Min. % Loss 1.0. °;', (Ins.) 12 2.94 9 2.91 3 2.89 2 2.92 4 2.88 3 2.90 4 2.88 6 2.90 7 2.93 4 2.83 0 N/A 6 2.81 7 2.91 5 2.88 0 2.81 4 2.90 3 2.93 2 2.88 0 2.95 0 4.00 2 2.94 0 2.75 4 2.92 9 2.91 6 2.92 5 2.94 3 2.92 4 2.91 4 2.92 6 2.93 3 2.93 2 2.92 4 2.91 6 2.94 4 2.93 6 2.91 4 2.90 .5 2.88 8 2.89 6 2.85 13 16 17 11 17 15 18 23 16 11 0 12 18 18 0 13 17 12 0 0 20 () 16 9 13 11 13 19 16 9 15 11 10 14 11 12 11 9 9 5 Well: Field: Company: Country: Survey Date: 1 D-30 Kuparuk ConocoPhillips Alaska, Inc. USA Au~ust 16, 2004 Comments Shallow nittine. Shallow corrosion. Shallow nittine. .-. Shallow Dittin\!:. Lt. DeDosits. Shallow Dittin\!:. Lt. DeDosits. Shallow Dittin\!:. Lt. Denosits. Isolated Dittin\!:. Lt. Denosits. Shallow corrosion. Lt. Denosits. PUP Lt. DeDosits. GLM 6 {Latch @ 8:00\ PUP Shallow corrosion. PUP Shallow Dittin\!:. Lt. DeDosits. OS NIP PUP Shallow Dittinp. Shallow Ditting. PUP Lt. Denosits. Packer SBE Shallow Dittin\!:. XN NIP Shallow Dittin\!:. Shallow Dittine. Shallow Dittin\!:. Lt. DeDosits. Shallow Dittin\!:. Shallow Dittin\!:. Shallow Ditting. Shallow pitting. Lt. Denosits. Perforations. SliD Mash. Perforations. Lt. DeDosits. Page 1 Damage Profile (%wall) 0 50 100 . . . . . ~ II. . III ~ I Penetration Body Metal Loss Body <Ids. Well: Field: Company: Country: Tubing: PDS Report Cross Sections 10-30 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins Survey Date: August 16, 2004 Tool Type: MFC 24 No. 99628 Tool Size: 1.69 No. of Fingers: 24 9.3 ppf Lo80 Analyst: M. Lawrence Cross Section for joint 351 at depth 10998.28 ft Tool speed = 46 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 99 % Tool deviation = 700 Finger 18 Penetration = 0.058 ins Isolated Pitting 0.06 ins = 23% Wall Penetration HIGH SIDE = UP Cross Sections page 1 cIas. Well; Field: Company: Country: Tubing: PDS Report Cross Sections 1D-30 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ppf L-BO Survey Date: Tool Type: Tool Size: No. of Fingers: Analïst: August 1 G, 2004 MFC 24 No. 99628 1.69 24 M. Lawrence Cross Section for Joint 355 at depth 11211.54 ft Tool speed = 45 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 100 % Tool deviation = 64 0 Finger 21 Penetration = 0.05 ins Shallow pitting 0.05 ins = 20% Wall Penetration HIGH SIDE = UP Cross Sections page 2 . KRU 1 D-30 _COnOCOPhiIliPS A~,:a.I~:'500292296000 w,,>T, PROD_. ~"TS, ,~"... ~~~- . ~~.~.'i~~.:W.~E... t...__Rð"F.~.t.~:r....::B... ~~;;oo.~o.~;~ en ~ - e.... ~ .:1~ ~~, _H"'T:",I ~ :; ~ tvo I Yh !..... . . "- :~; . . ..~.~g1. i~ -==:b.. . } 00).:', i-. g .l 1~it.3==f. i~; f~...!~:.n..: ":~D J I .-= T_~:r~..~~';'53 ~ó;;w.~~ 9:~iÏ:... SLeT -1 (' (~5 Pérfor~s ~~ :::1::=11178 . 6269~jQ-LJ,-80"--,-------- . 8RD -=- ~I' -Irderval .T---rvD 'Zone . Status .rif' SPF Date ~.. "--Cõiñiñëm- '1176ò:'117~_6533-6549 C.3.C-2 ~.36 4 3/26/2001 APERF~ê,oP.6O1120~Ph Gal; un - 11796 .1 ~ i 6549. 6553 C..:L-l -I 9 8. 3/2612001 APERF 2,5' HC. DP. 60/120 ~ ';!~~ =~l,~~~f) C-L.l -==:t. 1 III 3/26/2001 LRPE. RF2's" He. OP. 601.120 ~ 00 s.9G8) - lrurva.-::=c--i'>.. ¡ T'4IMI ,----r-:::::===- _èoma.w ~~. j , 11_BOO-11~UMl/2000 jF~__---rFrãë:~ 142MlOOo/Øfop'nCsana_- .1' -;:.:ï - ~:1::~ì": "-1- v;¡¡;-¡ V T... -- V 00 -'<-"'\TO" . ~l ¿::. I 00 5_) ,1 303.0- 2616 Cameo, MMG- I cðmeiti° i)MY ¡ ,15 Ri< 0.000-+-0- 81B12~, ----' . ""':"" ~ ~. ¡o,~ ~ ~1 ~. g~lli) :~ ~:~ g ~~. .~ Go$ un - " 9366 5447 Cameo MMG Cameo DMY, 1.5 RK 0,000 0 ~~ "--I : 'ndreli~7:6 5 ïÒ574 5996 CamCo ~Cßmeo ~... ¡ 1.5 RK 0,000 0 MlI200~ --'1 :1OSbt~~¡ ~~,- ,6~.28~=-):_.J~$;liâmco ...pMY 'I W~:~~K I o,ooo~ J811òÏ2004~. ." ~ TVD. T --~ Descri~. - - -.;---'!L-- 527, 527~1'p Ca~S Nipple wI~rif~ - --- .==ü.'875 ' 11133 6248!--.J:!!P Ca~t-lipple wINo Go )I"~-- . - ' 2.813 ¡ 11160 6260 '.' PKR Baker5xTZ)(~TopPðCkerw/5"RSr"pplc&TCKcouplln!L-..- 5000 11180 ' 6270 t . SEAL *r SBE '80-40' 4" IDwfTKC c~ . ì 4000 !-'illf16296 I . NIP. XN - wI2, 75' No Go - ---." ~ --=-- "=-~ "4 ¡ I . I , I . ¡ I '_.U ¡' Gos Lill - IndreilOommy I Valwa :11œg.1'.090, 00$-) NP- '11133-11134, 00.3.500) I :11,eo-ll~~~- II OO~B:--- 10.11178, 00.3.500. 10 2 992) I Perf 117~11800) I llN~R _. :11153-12041. 00.3,500. I WI 9.30) Perf :11800-11805) FRAC l",aoo-,,:: 1~18~- J Permit to Drill 2001040 MD 12044 "" TVD DATA SUBMITTAL COMPLIANCE REPORT ,~jJ~ ~-- 9/9/2002 Well Name/No. KUPARUK RIV UNIT 1D-30 Operator PHILLIPS ALASKA INC. APl No. 50-029-22965-00-00 6663 .----- Completion Dat 8/19/2000 Completion Statu 1-OIL Current Status 1-OIL REQUIRED INFORMATION Sampl~~ Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Name 9809 SRVY RPT SRVY RPT CMR TOTAL PORO 2 CMR TOTAL PORO 5 STAT TEM PRES 5 DGR/CNP/CTN/SLD- 2/5 DGR/CNP/CTN/SLD.- 2/5 DGR/EWR-TVD , 2/5 DGR/EWR-MD~ 2/5 CMR 2/5 PEX-DT/CNP 2/5 PEX-AIT-RXO. 2/5 (data taken from Logs Portion of Master Well Data Maint) Log Log Scale Media Interval Run No Start Stop OH I CH Received 11230 12016 6816 11989 1 Open , 10/13/2000 Open 9/19/2000 OH 9/19/2000 0 12044 OH 0 12044 OH FINAL 11630 11960 OH FINAL 11630 11960 OH FINAL 24 11913 CH FINAL~'~) 4341 6661 OH FINAL/~'.~ 6873 12044 OH FINAL 4341 6661 OH FINAL 6873 12044 OH FINAL 11632 11958 OH FINAL 11230 12008 OH FINAL 11230 12016 OH 8/23/2000 8/30/2000 9~8/2000 9/8/2000 8/28/2000 10/24/2000 10/24/2000 10/24/2000 10/24/2000 10/13/2000 10/13/2000 10/13/2000 Dataset Number Comments 09758 ~-~ 1~30-12016 MPT/GPJEWR4/CNPISLD SPERRY 0-12044. SPERRY 0-12044. BL(C) 11630-11960 BL(C) 11630-11960 24-11913 4341-6661 7/22/00 THRU 6873-12044 7/22/00 THRU 4341-6661 7/22/00 THRU 6873-12044 7/22/00 THRU 11632-11958 11230-12008 11230-12016 Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Permit to Drill 2001040 MD 12044 TVD Well Cored? Y ~ Chips R Analysis DATA SUBMITTAL COMPLIANCE REPORT 9/9/2002 Well Name/No. KUPARUK RIV UNIT 1D-30 Operator PHILLIPS ALASKA INC. 6663 Completion Dat 8/19/2000 Completion Statu 1-OIL Current Status Daily History Received? ~ N Formation Tops ~t' / N 1-OIL APl No. $0-029-22965-00-00 Comments: Compliance Reviewed By: Date: ~annutar vtsposat aunng tne tntra t~uarter oj ". h(1) ~ h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-27 28133 100 0 28233 3633 31866 June 2001 July 2001 1C-127, 1C-117, lC-111, 1C-123 CD2'42 13465 100 0 13565 18134 31699 May 2001 July 2OOl CD2-24, CD2-33 CD2-24 . 30443 100 0 30543 375 30918 June 2001 Sept 2OOl CD2-33, CD2-39, CD2-14 2N-318 520 100 0 620 16978 17598 Dec 2000 July 20Ol 2N-314, 2N-302, 2N-332' 31453 100 0 31553 325 31878 Aug 2001 Sept 2001 2N-348, 2N-350 1C-16 19579 100 0 19679 0 19679 Sept 2001 Sept 2001 1C-102, 1C-131 1C-26 34160 100 0 34260 0 34260 Aug2001 Sept2001 1C-123, 1C-119, 1C-102 CD2-39 279 100 0 379 0 379 Sept 2001 .Sept 2001 Freeze protect volume from CD2-39 CD2-14 276 100 0 376 0 376 Sept 2001 Sept 2001 Freeze protect volume from CD2-14 Total Volumes into Annuli ~or which Disposal Authorization Expired during the third quarter 2001: ............................... j ............. ~ ......................... · ~ Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus CD1-43 30937 100 0 31037 Open, Freeze Protected Jan 2001 Feb 2001 CD1-NQ1, CD1-21 2N-332' 225 100 0 325 Open, Freeze Protected July 2000 July 2000 Freeze protect 2N-332 only 2N-347 31540 100 0 31640 Open, Freeze Protected Sept 2000 Sept 2001 2N-349, 2N-305 1D-38 33907 100 0 34007 Open, Freeze Protected July 2000 Sept 2000 1D-30, 1D-40, 1D-141, 1D-36 1D-30 31622 100 0 31722 Open, Freeze Protected Sept 2000 Oct 2000 1D-36, 1D-34 2N-318 - 17498 100 0 17598 open, Freeze Protected Dec 2000 July 2001 2N-314, 2N-302 ~N-316 240 100 0 340 Open, Freeze Protected Aug 2000 Aug 2000 Freeze protect 2N-316 '2N-332 was permitted for annular disposal the first time in July 2000 (300-187) and re-permitted (301-219) in August 2001. The volumes for the expired permit applies just to that permit. Ph(',.LIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 May 2, 2001 f ,~. o-~ , Commissioner State of Alaska Alaska Oil & Gas Conservation .Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 "' Subject: Report of Sundry Well Operations 1D-30 (200-104) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforation operations on the KRU well 1D-30. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Staff Engineer Phillips Drilling MM/skad RECEivED MAY 0'4 2001 Alaska Oil & c~ Cons. Corr~ission OR GINAL REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Pedorate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 386' FNL, 420' FEL, Sec. 23, T11 N, R10E, UM At top of productive interval 43' FNL, 1652' FWL, Sec. 30, T11 N, R11 E, UM At effective depth At total depth 228' FNL, 3071' FEL, Sec. 30, T11N, R11 E, UM 5. Type of Well: Development _X Explorato~__ Stratigraph ~__ Service__ (asp% 560671, 5959279) (asp's 568065, 5954410) (asp's 568315, 5954224) 6. Datum elevation (DF or KB feet) RKB 105 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 D-30 9. Permit number / approval number 200-104 / 10. APl number 50-029-22965 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 110' SURF CASING 6768' PROD CASING 11200' LINER 888' 12044 feet Plugs (measured) 6663 feet 11975 feet Junk (measured) 6632 feet Size Cemented Measured Depth True vertical Depth 16" 16.5 cu yds AS IType 3 114' 114' 9-5/8" 71o sx AS III Lite, 460 Sx 6873' 4342' LiteCRETE 7" 18o sx c~ass G 11305' 6328' 3-1/2" 212 sx Class G 12041' 6662' Perforation depth: measured 11800'-11805', 11760'-11800',11796'-11816' RECEIVED.. true vertical 6551'-6553', 6534'-6552', 6550'-6559' ~'~ Y 0 'z~" ~001 Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 11178' MD. Alaska C~I& Gas Cons A ~ C°tr~issio~ Packers & SSSV (type & measured depth) BAKER 5X7" ZXP LINER TOP PACKER W/5" RS NIPPLE & TCK COUPLING @ 11160' M~D~ CAMCO DS NIPPLE W/NO GO PROFILE @ 527' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached description Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Prior to well operation 444 1120 2 Subsequent to operation 508 809 1 Casing Pressure Tubing Pressure 225 220 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations ._X Oil __X Gas __ Suspended _ 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~, ~,~ Title Staff Engineer Michael Mooney Form 10-404 Rev 06/15/88 · Service ORIGINAL Date -~'/.,~///~ / Prepared by Sharon AIlsul~Drake 263-4612 SUBMIT IN DUPLICATE Date Comment 1D-30 Event History 03/09/01 03/26/01 03/27/01 DRIFT TBG W/22' X 2.65" HC DUMMY PERF GUN, TAGGED FILL @ 11824' RKB. COMPLETEI I-I-ag] PERFORATE 11796-11816 W/6 SPF 60 DEG PHASED DEEP PENETRATING CHARGES. THIS IS 1 OF 3 PERFORATING RUNS FOR THIS PROJECT.~ [Perf] PERFORATE 11760'-11800' RKB W/2-1/2" HSD, 4 SPF, DP, 60/120 DEG PHASING (6 SPF CARRIERS LOADED 4 SPF)~ [Perf] Page I of 1 5/2/01 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 'Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 January 23,2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2000 (Revision 1) Dear Ms. Mahan: Please find the revised report belOw with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2000, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2000. The revision is for the annulus of Well 1D-42. An annular disposal report for 12/26/00 of 2437 barrels was not counted in the total for the Quarter. The revised total for Well 1D-42 is 15,118 from 12,681 barrels as noted in the table below. Annular Disposal during th~: fourth quarter of 2000: h(1)' h(2)- hi3) Totalfor Previous New Well Name Volume Volume, Volume Quarter Total Total 2N-343 13713 100 0 13813 17995 31808 2L-313 9017 100 0 9117 17273 26390 CD1-45 26735 100 0 26835 5501 32336 CD1-42 26447 100 0 26547 4807 31354 - CD1-44 22410 100 0 22510 0 22510 2N-347 16434 100 0 16534 15106 31640 1D-30 1030 100 0 1130 30592 31722 2N-318 1199 100 0' 1299 320 1619 1D-36 30104 ' 100 0 30204 0 30204 2N-305 280 100 0 380 0 380 , 1D-34 32133 100 0 32233 0 32233 1D-42 15018 100 0 15118 0 15118 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 January 19, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7~ Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Fourth Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the fourth quarter of 2000, as well as total volumes injected into annuli for which disposal authorization expired during the fourth quarter of 2000. Annular Disposal-during th,.~ fourth quarter of 2000: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-343 13713 100 0 13813 17995 31808 2L-313 9017. 100 0 9117 17273 26390 CD1-45 26735 100 0 26835 5501 32336 CD1-42 26447 100 0 26547 4807 31354 CD1-44 22410 100 0 22510 0 22510 2N-347' 16434 100 0 16534 15106 31640 1D-30 1030 100 0 1130 30592 31722 2N-318 1199 100 0 1299 320 1619 1D-36 30104 100 0 30204 0 30204 2N-305 280 100 0 380 0 380 1D-34 32133 100 0 32233 0 32233 1D-42 12581 100 0 12681 0 12681. Ms. Wendy Mahan AOGCC Fourth Quarter 2000 Annular Disposal RePOrt page Two Total Volumes into Annuli for which Disposal Authorization Expired during the fourth quarter 2000: .. Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CDI-16 28950 100 0 29050 Open, Freeze Protected CD1-45 32236 100 0 32336 Open, Freeze Protected CD1-32 33413 100 0 33513 Open, Freeze Protected CD1-42 31234 100 0 31334 Open, Freeze Protected CD 1-36 33567 100 0 33667 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel ! Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files spenn d-sur( I~1:tl Ll--I ffi G SEI:tVI r- E S WELL LOG TRANSMITTAL Stateof-,aJaska--- Oetob~ t~ 2000 Alaska Oil and Gas Conservation Comm. A~t~.-: Loff~aylor 3001 Porcupine Dr. ~-~zlaomge, ~ Atastm--.99.501 RE: MWD Formation Evaluation Logs 1D-30, AK-MM-00108 to the attention of.' 2"x 5" TVD Resistivity & Gamma Ray Logs: 2"x 5" MD Neutron & Density Logs: 5~296-5-0¢ 2"x 5" TVD Neutron & Density Logs: 50-029-2296-5-06 .... FBlueline ~-'Fot~ Sepia 1 Blueline 1--.Folde~ Sepia 1 Blueline t..Fotdee[ Sepia 1 Blueline OCT 24 2000 Naska 0il a Gas Cons. O0mmi~, Anchora~ 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 October 13, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kupamk Area Annular Injection, Third Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into ...... ~"'" .... ' ' surface casing by p~uct~on casing ~nuli during the third qumer of 2000, as well as tot~ volumes injected into annuli for which injection authorization expired during the third qumer of 2000. Annular Injection during the third quarter of 2000: h(1) h(~) h(3) Totalfor Previous New Well Name Volume Volume Volume Quarter Total Total CD1-45 5036 100 0 5136 365 5501 CD1-03 33505 100 0 33605 385 33990. 1D-14 33916 100 0 34016 1487.5 35503.6 CD1-25 24860 100 0 24960 8627 33587 2N-341 '13544 100 0 13644 20506 34150 2N-335 25395 100 0 25495 0 25495 2N-347 14666 100 0 14766 340 15106 1D-38 33907. 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 340 CD1-43 285 100 0 385 0 385 "iD' 1o'5 '/.,OO. o q O° Ms. Wendy Mahan AOGCC Third Quarter 2000 Annular Injection Report Page Two Total Volumes into Annuli for which Injection Authorization Expired during the third quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CD1-39 31408 100 0 31508 Open, Freeze Protected 11)-12 32791 100 0 32891 Open, Freeze Protected CD1-37 32487 100 0 32587 Open, Freeze Protected CI)1-23 33886 100 0 33986 Open, Freeze Protected CD1-01 5121 100 0 5221 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC.' Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel ! Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files PHILLIPS Alaska, Inc.. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 October 13, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kupamk Area Annular Injection, Third Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected intO surface casing by production casing annuli during the third quarter of 2000, as well as total volumes injected into annuli for which injection authorization expired during the third quarter of 2000. Annular Injection during the third quarter of 2000: T h(l)' h(~) h(3) Totalfor Previous New Well Name Volume Volume Volume Quarter Total Total CD1-45 5036 100 0 5136 365 5501 ag CD1-03 33505 100 0 33605 385 33990 ? 1D-14 33916 100 0 34016 1487.5 35503.6 ~'CD1-25 24860 100 0 24960 8627. 33587 2N-341 13544 100 0 13644 20506 34150 2N-335 25395 100 0 25495 0 25495 2N-347 14666 100 0 14766 340 15106 1D-38 33907 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 340 CD1-43 285 100 0 385 0 385 ] O/] 0/00 Scklmberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie 593 Company: Alaska Oil & GaS Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD 1D-30 'T~ cT' '] ~-"~ 20340 AITIPEX/CMR'. ' 000808 1 1D-30 20340· PEX-AIT . . 000808 1 1 1D-30 20340 PEX-DENSITY CEE POROSITY 000808 1 1 1D-30 20340 CMR 000808 I 1 · · · · · . , · , . · · · II~'lm,~ Im It I1" %. . KI'LI~! V I~ J SIGNED=~'~'~-~ L-~---/~ ~//~~ DATE: OCT 1~ ~000 ~ 0il & Gas ~. ~mml~i~ Please sign and return one copy of this transmiffal to Sherrie at the above address or fax to (907) 561-8317. Thank you. A~ch0rage ( o. ^,AS RECEIVED ALASKA OIL AND GAS CONSERVATION COM ;:::;ION WELL COMPLETION OR RECOMPLETION REPORT IP71 i . Classilication~J'~ervi~ ~Vel]''" 1. Status of well Classitication~oJ'~ervi~e ~vel~- Alaska 0il & Gas Cons. Oil I~] Gas D Suspended D Abandoned D Service D 2. Name of Operator 7. Permit Numb~r~i~,,,~,..~C Phillips Alaska, Inc. 200-104 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~ 50-029-22965-00 4. Location of well at surface ...... -- -' 9. Unit or Lease Name 387'' FNL, 419' FEL, Sec. 23, TllN, R10E, UM (ASP: 560671, 5959279) ........... 1' ...... Kuparuk River Unit At Top Producing Interval _~/_~_,~_ ~ · 10. Well Number 43' FNL, 1652' FWL, Sec. 30, TllN, RllE, UM (ASP: 568065,5954410) V~X!f::!F~D i 1D-30 At Total Depth .... _~ ! 11. Field and Pool 231' FNL, 1900'. FWL, Sec. 30, T11N, R11 E, UM (ASP: 568315, 5954224} ~ Kuparuk fliver Field 5. Elevation in leet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 34 feetI ADL 28248, 25650, 28243 ALK 591 12. Date Spudded 18. Date T.D. Reached 14. Date Comp., ~$p.,Oj Aband. 115. Water Depth, Jf ottshore 16. No. ol Completions I ,July 22, 2000 August 7, 2000 August ,.~', 2'~'0 N/A feet MSL , 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 12o. Depth where 888V set 21. Thickness of Permafrost 12044' MD / 6663' TVD 11975' MD / 6632' TVD YES r~ No E]I N/A feet MD 1668' 22. Type Electric or Other Logs Run GR/Res/Neu Dens, GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-I'OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 135' 20" 16.5 cu. Yards, ASl, type III 9.625" 40# L-80 Surface 6873' 12.25" 710 sx AS III Lite, 460 sx LiteCRETE 7" 26# L-80 Surface 11305' 8.5" 180 sx Class G 3.5" 9.3# L-80 11153' 12041' 6.125" 212 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 11179' 11161' 11800'-11805' MD 6551'-6553' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11800'-11805' 11000# 20/40 and 131498# 12/18 behind pipe 2~. PRODUCTION TEST [ ~ ~ I ~ i I~l /-~ L Date First Production Method of Operation (Flowing, gas li~t, etc.) August 28, 2000 Flowing Date o! lest Hours lested Production for Otl-BBL C_~S-MCF WAIER-BBL CHOKE SIZE I GAS-OIL RAIIO I 9/1/2000 6.0 lest Period > 436 838 0 50 I 2105 Flow lubing Casing Pressure Calculated OIL-BBL C_~S-MGF WAIER-BBL OIL GRAVIIY - APl (con') press. 550 psi not available 24-Hour Rate > 1601 3465 0 24° 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS~ FORMATION TESTS NAME Include interval tested, pressure data, all lluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time o! each phase. Top Kuparuk C 11694' 6504' RECEIVED Base Top Kuparuk A 12044' 6663' Base Kuparuk A 12044' 6663' SEP 2 7 ;)000 Alaska 0ii & Gas Cons. Commission Anchorage Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is tree and correct to the best of my knowledge. Questions? Call Tom Brockway 263-4135 Signed ('1~,~ \ Title Ddllin,qEn,qineerin.qSupervisor Date ~) ~ ~J~ "~~ "~/ --- J. Trantham - - ~ Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5.' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21.- Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 09/21/00 RF ,' IVED_ SEP 27 2000 ARCO ALASKA INC. ~a~a ~[ & ~85 C0~$. COIB~,~II1 Page: 1 WELL SUMMARY REPORT A~0{~j~ WELL:iD-30 STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:07/22/00 START COMP: RIG:NABORS 16E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22965-00 07/21/00 (D1) TD/TVD: 0/0 SUPV: MW: 0.0 VISC: 0) PREP FOR SPUD 0 PV/YP: 0/ 0 APIWL: 0.0 Jack up, move rig from 1D-38 to 1D-30, spot rig over hole. 07/22/00 (D2) MW: 9.3 VISC: 225 PV/YP: 33/40 APIWL: 6.8 TD/TVD: 1269/1212 (1269) DRILLING AT 1923' SUPV:M.WINFREE Move rig over hole on 1D-30. Accept rig 0100 hrs. 7/22/00. NU stack and diverter. RIH tag bottom at 135'. Function test diverter. Hold spud meeting. Drill from 135' to 1269' 07/23/00 (D3) MW: 9.5 VISC: 280 PV/YP: 32/46 TD/TVD: 1269/1212 ( 0) CIRC AFTER SHORT TRIP SUPV:M.WINFREE Drill 1269' to 3239' APIWL: 5.8 07/24/00 (D4) MW: 9.7 VISC: 275 PV/YP: 33/42 TD/TVD: 4994/3500 (3725) MAKING SHORT TRIP SUPV:M.WINFREE APIWL: 5.4 Circ hi vis, hi density sweep, monitor well, pump dry job. POOH, hole swabbing 1150', pump out 1150 to 990', hole pulled clean 990' to 700' no swabbing. RIH. Circ BU circ out thick mud, lots of cuttings over shaker. Drill from 3239' to 4994' 07/25/00 (D5) TD/TVD: 4994/3500 ( SUPV:M.WINFREE MW: 9.7 VISC: 205 PV/YP: 39/44 0) DRILLING AT 5775 APIWL: 5.4 Drill from 4994' to 5213' Pump hi visc, hi density sweep, circ hole clean. Short trip to 3000', run back in 5213' hole in good shape. Circ BU circ until shakers clean up. Drill from 5213' to 5306'. Sperry Sun MWD tool failed. POOH. Work BHA. RIH. CBU. Drill from 5306' to 5405' 07/26/00 (D6) MW: 9.6 VISC: 190 PV/YP: 34/34 APIWL: 4.0 TD/TVD: 6883/4345 (1889) CIRC &COND FOR CASING SUPV:FRED HERBERT Drilling 12.25" hole from 5405' to 5494'. Repair washout on #2 pump discharge manifold. Drilling 12.25" hole from 5494' to 6883'. Circ densified sweep around. Monitor well for flow. Date: 09/21/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 07/27/00 (D7) TD/TVD: 6883/4345 ( SUPV:FRED HERBERT MW: 9.6 VISC: 211 PV/YP: 43/48 0) HOLD PJSM. RUN 9.625" CASING APIWL: 4.0 Wiper trip, hole swabbing. Pump out from 6816' to 5218', POOH to 5050', OK. RIH to bttm, no problems. Break circ slowly, monitor returns for losses. Pump weighted sweep, circ and cond for casing. Monitor well. POOH. Swabbing at 1350'. Pump out from 1350' to 1000' POOH. RIH with hole opener assy. No hole problems. Break circ slowly. Pump weighted sweep. Pump slug. POOH to run casing. 07/28/00 (D8) TD/TVD: 6883/4345 ( SUPV:FRED HERBERT MW: 9.6 VISC: 66 PV/YP: 16/17 0) NIPPLE UP BOPE APIWL: 5.8 POOH w/hole opener. Hold PJSM. Run 9-5/8" casing. Circ casing volume. Land casing shoe @ 6873'. Circ and cond mud for cement job. Hold PJSM. Pump cement. 07/29/00 (D9) TD/TVD: 6883/4345 ( SUPV:FRED HERBERT MW: 8.5 VISC: 41 PV/YP: 10/14 0) DRILLING AHEAD @ 6960' APIWL: 8.8 Displace cement w/rig pump. Did not bump plug. Check floats (OK). ND diverter. NU BOPE and test to 250/5000 psi. 07/30/00 (D10) MW: 8.8 VISC: 43 PV/YP: 14/16 TD/TVD: 8300/4973 (1417) DRILLING SUPV:FRED HERBERT APIWL: 5.2 Drill cement, float equipment, & 20' new hole to 6903' Tagged float collar, & shoe @ 6882'. Circ & cement contaminated mud (thick). Displace well w/LSND mud. Perform LOT, EMW=13.8 ppg. Drilling 8.5" hole from 6903' to 7121' Cir bttms up for PWD baseline test. Perform test. Drilling 8.5" hole from 7121' to 7874'. Repair leak on bell nipple. Drilling 8.5" hole from 7874' to 8062'. Change out swab on #1 mud pump. Drilling 8.5" hole from 8062' to 8300' 07/31/00 (Dll) MW: 9.1 VISC: 44 PV/YP: 14/16 TD/TVD: 9700/5598 (1400) DRILLING @ 10160' SUPV:FRED HERBERT APIWL: 4.4 Drilling 8.5" hole from 8300' to 8817'. Circ hi density sweep around. POOH to shoe, no problems. RIH to bottom. No problems. Pump hi density sweep. Drilling 8.5" hole from 8817' to 9356'. Repair leak in bell nipple. Drilling 8.5" hole from 9356' to 9700' RECEIVED SEP 2 7 .000 A~a~ka Oi~ & Gas Cons. Commis,~ion Date: 09/21/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 08/01/00 (D12) MW: 9.8 VISC: 44 PV/YP: 17/17 TD/TVD:10998/6193 (1298) POOH TO SHOE FOR LOT SUPV:FRED HERBERT APIWL: 4.4 Drilling 8.5" hole from 9706' to 10506'. Circ, finish pumping sweep around. Drilling 8.5" hole from 10506' to 10788'. Circ sweep around. Monitor well. Pump dry job. POOH to 8817'. No problems. RIH to bottom. Break circ, pump weighted sweep. Drilling 8.5" hole from 10788' to 10998' 08/02/00 (D13) MW: 9.8 VISC: 49 PV/YP: 19/21 TD/TVD:l1315/6332 (317) L/D BHA, DOWN LOAD LWD. SUPV:FRED HERBERT APIWL: 4.6 Drilling 8.5" hole from 10998' to 11093' Circ hi density sweep around. Pump slug and POOH to shoe @ 6873'. Circ out dry job. Balance out mud weight @ 9.8. Perform LOT, 11.7 EMW.RIH. Pump hi density sweep. Drilling 8.5" hole from 11093' to 11315'. Wiper trip to 10400'. Circ & cond to run 7" casing pump sweep. Monitor well. POOH to run casing. 08/03/00 (D14) MW: 9.8 VISC: 43 PV/YP: 18/14 APIWL: 4.4 TD/TVD:l1315/6332 ( 0) INSTALL PACK OFF & TEST SAME SUPV:FRED HERBERT POOH to run casing. Hold PJSM. Run 7" casing. Circ 1 casing. volume @ 4000'. Run 7" casing to shoe. Circ & cond @ shoe. Run 7" casing to 9000'. Circ bttoms up @ 9000'. Run 7" casing. Shoe @ 11305' 08/04/00 (D15) MW: 11.0 VISC: 60 PV/YP: 24/40 APIWL: 3.8 TD/TVD:l1315/6332 ( 0) TEST BOP'S SUPV:FRED HERBERT / DON MICKEY Circ & cond for cement job. Pump cement. Bump plug, check floats. Install packoff & test to 5000 psi. Install test plug. Test plug stuck in well head. Attempt to pull loose will not come. Pull pack off. 08/05/00 (D16) MW: 11.0 VISC: 68 PV/YP: 26/44 APIWL: 3.8 TD/TVD:l1315/6332 ( 0) DRILL CEMENT & FLOAT EQUIPMENT SUPV:FRED HERBERT / DON MICKEY NU BOP's and riser. Install pack off & test to 500 psi. Test BOP's to 250/5000 psi. 08/06/00 (D17) MW: 11.0 VISC: 54 PV/YP: 26/34 APIWL: 3.6 TD/TVD:l1666/6488 (351) DRILLING AHEAD @ SUPV:FRED HERBERT / DON MICKEY Tag cement stringers @ 11185'. Circ & cond mud. Circ out thick mud. Drill cement, plugs, float equipment and 20' new hole to 11335'. Displace well with 11.0 ppg LSND mud. Perform FIT to 16.0 EMW. Drilling 6.125" hole from 11335' to 11400'. POOH to shoe & change shaker screens loosing mud. Drilling 6.125" hole from 11400' to 11593' Perform PWD baseline test. Drilling 6.125" hole from 11593' to 11666' RECEIVED SEP 27 000 ,A!ask~ Oil & G~s Co~s. C~.~~ Date: 09/21/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 08/07/00 (D18) MW: 11.0 VISC: 52 PV/YP: 26/29 APIWL: 4.0 TD/TVD:12044/6660 ( 378) RIG UP SWS SUPV:FRED HERBERT / DON MICKEY Drill 6.125" hole from 11666' to 12044'. Wiper trip to 7" shoe (pump out) hole slick. RIH from 7" shoe to TD, hole slick. Pump sweep and circ hole clean. Pump out to shoe, hole slick. Flow check, pump dry job. 08/08/00 (D19) TD/TVD:12044/6660 ( SUPV:DON MICKEY MW: 11.0 VISC: 56 PV/YP: 26/30 APIWL: 4.0 0) RIH W/ WET CONNECTOR FOR DP CONVEYED LOGGING Held PJSM. RIH, log stopped @ 3070', made several attempts, unable to pass below 3070'. POOH. Held PJSM. RIH w/logging tools. Ran to 11213', unable to circ, work pipe & attempt to circ, no success. Pulled back to 9886' 08/09/00 (D20) MW: 11.0 VISC: 49 PV/YP: 17/29 APIWL: 4.2 TD/TVD:12044/6660 ( 0) CIRC. AND CONDITION HOLE FOR LINER SUPV:DON MICKEY Circulate @ 9886'. RIH from 9886' to 11968'. Break circ slowly. Held PJSM. RIH w/logging tools. Ran Platform Express/CMR from 12030' to 11320'. POOH. RIH for clean-out. Held kick drill. 08/10/00 (D21) MW: 11.0 VISC: 49 PV/YP: 18/31 APIWL: 4.2 TD/TVD:12044/6660 ( 0) CEMENTING 3 1/2" LINER SUPV:DON MICKEY RIH to TD. Break circ, pump sweep & circ hole clean, flow check. Pull out to run 3.5" liner, flow check @ 7" shoe, continue POOH. Held PJSM. Run 3.5" liner w/Baker liner assembly. 08/11/00 (D22) MW: 11.0 VISC: 47 PV/YP: 16/20 APIWL: 4.8 TD/TVD:12044/6660 ( 0) RUNNING COMPLETION SUPV:DON MICKEY RIH w/3.5" liner, tag bttm@ 12044'. Circ & condition mud for cement job. PJSM. Cement 3.5" liner. Bumped plug, floats held. Set packer. 08/12/00 (D23) MW: 8.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12044/6660 ( 0) INSTALL BPV SUPV:DON MICKEY PJSM. Run 3.5" completion. Displace well to seawater and circ clean. Pump diesel down 7"x3.5" annulus. Freeze protect. 08/13/00 (D24) MW: 14.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12044/6660 ( 0) RIG RELEASED SUPV:DON MICKEY N/D BOPE. Install tbg head adaptor. Test seals and flange to 5000 psi. Install tree and test to 5000 psi. Set BPV. Release rig @ 0600 hrs. 8/13/00. ~-~F%~=-~%~ ~.~--~ SEP 27 A~ask~ Oil & Gas Cons~ Commb~n PHILLIPS Alaska, Inc. ( KUPARUK RIVER UNIT --~" LL SERVICE REPORT 1D-30(4-1)) WELL JOB SCOPE 1 D-30 DRILLING SUPPORT-CAPITAL DATE 08/19/O0 DAY 2 DAILY WORK CORRELATION LOG/PERFORATE/SBHP OPERATION COMPLETE I SUCCESSFUL I KEY PERSON ..~ Yes O No J ~ Yes O No ! SWS-SPENCER Inihal Tbg I Fina~ Tbg I lnihal IA I Final IA Initial UA I~na~ uA I ~ ~L~5~ze 150PSII 1080PSII 0PSII 150PSI 450PSII 150PSII 3.500" JOB NUMBER 0815001944.4 UNIT NUMBER 2145 SUPERVISOR GOBER IMIrl II.J I I. Jl~J,,/Lll · 2.813" 11133 FT DAILY SUMMARY RUN CORRELATION GR/CCL LOG - PERFORATE 11800'-11805' RKB WITH 2.5" HSD BIG HOLE/4 SPF/180 DEG PHASING/ORIENTED 0 DEG AND 180 DEG FROM THE HIGH SIDE - SBHP--3640 PSI @ 11803' RKB AND 3608 PSI @ 11703' RKB - PRESSURES WERE NOT FULLY STABILIZED [Perf, Pressure Data] . TIME LOG ENTRY 07:30 CALLED DSO FOR ACCESS - SAFETY MEETING - MIRU 08:00 NO SLOP TRAILER ON PAD, CALLED DSO 08:30 RIG UP COMPLETE, ON STANDBY AWAITING SLOP TRAILER. 08:50 SLOP TRAILER HERE, PT TO 300 PSI 09:00 CONTINUE PT TO 3000 PSI 09:10 CALLED DSO - NO GAUGE ON IA 09:30 RIH - 2 WEIGHTS (2.125" X 72") AND PBMS 10:00 DSO INSTALLED AN IA GUAGE = 0 PSI 11:15 LOG CORRELATION GR/CCL PASS- TAGGED TD AT 11982 FT MD 12:00 LOG REPEAT SECTION OVER AREA OF INCONSISTENT DEPTH CORRECTION (11330 - 10980 FT). 13:15 TOOLS AT SURFACE - PREPARE FOR GUN RIH 14:00 5 FOOT GUN IS ARMED - RIH GUN = 2.5" HSD @ 4 SPF CHARGES = 35B UP RDX PHASING = 180 DEG ORIENTATION = 0/180 DEG SPECS: EXPL. LOAD = 10.5 GM PENE. = 5.8" ENT. HOLE = .62' 15:00 AT 11000, LOG DOWN COUNTING COLLARS 15:20 AT 11950, LOG TIE IN PASS 16:00 LOG DOWN COUNTING COLLARS 16:20 LOG INTO POSITION TO SHOOT. INTERVAL = 11800 - 11805 FT MD 16:20 RECONNECT TRI-PLEX TO PRESSURE UP WELL TO SHOOT OVERBALANCED. ON PREVIOUS RIH, PRESSURE 11975 FT MD WAS 3185 PSI. ESTIMATE PRESSURE AT 11800 = 3150 PSI. RESERVOIR ESTIMATED BY CLIENT AT 3200 - 3500 PSI. WHP = 200 PSI. WILL PRESSURE UP TO 700 PSI. THIS SHOULD = 3650 PSI AT 11800 FT. 16:50 GOOD WEIGHT INDICATION OF DETONATION, AND SURFACE PRESSURE BEGAN TO RISE. 18:00 AT SURFACE- CONFIRMED ALL SHOTS FIRED - WHP 950 PSI 18:15 3RD TOOLSTRING - SAME AS 1ST TOOL STRING - IN LUBRICATOR- PRESSURE IS RISING FROM 240 PSI WHEN WELL WAS 1ST RE-OPENED. LOG A STATION IN THE LUBRICATOR AT 1.5 HOURS AFTER GUN SHOT. PRESSURE = 1047 PSI AND RISING RECEIVED SEP. 2 7 2000 Alaska Oil & Gas Co~s, Anchorage TIME 19:30 20:00 20:35 21:40 82:OO LOG ENTRY ~i'.,,IG AT 11000, LOG DOWN COU COLLARS AT 11803 FT MD, LOG STATION AT 3 HOURS AFTER SHOT GUN PRESSURE STARTED AT 3680 AND FELL TO 3640 IN 1/2 HOUR. STILL FALLING AT 11703 FT MD, LOG A STATION AT 3.75 HOURS AFTER PERF PRESSURE STARTED AT 3611 AND FELL TO 3608 AFTER 18 MINUTES. STILL FALLING BUT MUCH SLOWER. BACK IN LUBRICATOR - LOG A STATION - 5 HOURS AFTER PERF PRESSURE STARTED AT 957 PSI BUT IS RISING AGAIN. ENDED AT 1055 PSI AFTER 15 MINUTES. RIG DOWN COMPLETE - CALLED DSO - LEFT PAD 8EP 2 7 2000 Gas Cons. Commission Anchorage PHILLIPS Alaska, Inc. WELL JOB SCOPE 1 D-30 DRILLING SUPPORT-CAPITAL DATE 08/21/00 DAY DAILY WORK INITIAL C SAND FRAC KUPARUK RIVER UNIT LL SERVICE REPORT 1D-30(4-1)) OPERATION COMPLETE I SUCCESSFUL I KEY PERSON ('~ Yes O No / ~'~ Yes O No /DS-YOAKUM mmaJ ,[~§ Ir"~a[ "~ I ""'"= '"' I' "'°' '"' I """°' "'"' I' "'°' "'"' I' 1035PSI1 500PSll 250PSII 550PSll 500PSll 500PSII 3.500=" JOB NUMBER 0815001944.4 UNIT NUMBER SUPERVISOR GOBER .2.813 " 11133 FT DAILY SUMMARY PUMP BREAKDOWN AND SCOUR STAGES WITH 50# XL GEL AT 15 BPM - PUMP 75 BBL 50# XL GEL DATA FRAC - SD FOR ANALYSIS - 22 MIN CLOSURE TIME - DEC PAD TO 170 BBLS (300 BBL DESIGN) - SAW DECREASE IN NET PRESSURE DURING 6 PPA STAGE - SAW NET PRESSURE INC AT END OF 6 PPA STAGE - SCREENED OUT 130 BBLS INTO 6-12 RAMP - 6.1 PPA ON FORMATION - 11000 LBS 20/40 AND 131498 LBS 12/18 BEHIND PIPE - LEFT 27881 LBS IN WELLBORE - DID NOT GET ANY FLUSH IN WELL [Frac-Refrac] TIME LOG ENTRY 07:00 MIRU DS 09:00 TGSM - MUSTER AREA AT NORDIC 3 RIG CAMP - 16 PEOPLE ON LOCATION - TIGHT LOCATION - THROUGH TRAFFIC IS BLOCKED OFF ON THE PAD - WATCH FOR FOOT TRAFFIC IN THE AREA- DISCUSS JOB PLAN 09:15 PRIME PUMPS - CHECK PRY SKID - RELIEFS GOING OFF AT 3800-3900 PSI -WAIT ON FUELER TO FINISH FUELING PRIOR TO PT 10:00 ATTEMPT TO PT LINES - HAD UNION LEAK ABOVE MASTER ON TREESAVER - REPLACE O-RING - PT LINES AND EQUIPMENT TO 9500 PSI - ALL OK 10:25 PUMP 50# XL GEL BREAKDOWN AND SCOUR STAGES WITH 1 PPA AND 2 PPA STAGES - SAW GOOD BREAKB ON BREAKDOWN - PERFORM SDT- ISIP=1972- FRAC GRAD=0.74- NWB FRICTION=464 PSI 11:20 PUMP DATA FRAC - 75 BBLS 50# XL @ 5 BPM, 34 BBLS STRAIGHT SW @ 5 BPM, & 80 BBLS STRAIGHT SW @ 15 BPM - ISIP=2161 PSI - 0.77 FRAC GRADIENT - CLOSURE TIME=22 MIN - CLOSURE PRESSURE=1780 PSI - DEC PAD ON FRAC 170 BBLS 12:35 BEGIN FRAC - STARTED BUILDING NET PRESSURE AT END OF 6 PPA STAGE - PROBABLY WAS NOT TSO - SAW A DECREASE IN NET PRESSURE DURING 6 PPA STAGE - MAY POSSIBLY HAVE FRAC'D INTO A SAND 13:55 SCREENED OUT 130 BBLS INTO 6-12 PPA RAMP - 6 PPA ON FORMATION - 11000LBS 20/40 PROPPANT AND 131498 LBS 12/18 PROPPANT BEHIND PIPE - LEFT 27881 LBS IN WELLBORE - DID NOT GET ANY FLUSH AWAY 14:00 FLUSH LINES OUT AND BEGIN RD EQUIPMENT 16:00 RDMO DS 1:3RI LLI N 13 SERVICE=: WELL LOG TRANSMITTAL To.'- StateofAteaka-- Alaska Oil and Gas Conservation Comm. Arm:: Lori-~aylor 3001 Porcuphae Dr. Anehoeage; Ata~a: 99501 MWD Formation Evaluation Logs 1D-30, AK-MM-00108 1 LDWG formatted Disc with verification listing. APt/k..--~~,~65-00 Sperry-Sun Drilling Service Atm. J:ma-Galyin 5631 Silverado Way, Suite G. Aaeho~age,: Atasl~99518 RECEIVED O~:--SEP 19:1000 Alaska Oil:& Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company 8/31/00 Scbhanberger NO. 470 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log DeScription Date BL Sepia Print 1L-28 (REDO) PRODUCTION PROFILE 000821 I 1 2C-08 ~_,~1, (.. MEM INJECTION PROFI' ~= 000824 I 1 2F-07 PRODUCTION PROFI' F 000823 I 1 2W,02 t.tl C_ INJECTION PROFILE 000824 I 1 3C-06 PRODUCTION PROFILE/DEFT 000822 I 1 3Q-13 I,.~! (_ INJECTION PROFILE 000825 I 1 1D-30 20339 CMR TOTAL POROSITY 000808 2 .... , _ _,/_-- _~ .-. /, -~ ,.,.-..~.~- _ SEP 0 2000 SIGN~/~~ DATE: I Alaska 0it & Gas uu;~. ~ummisston Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317, Thank you. 24-Aug-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 NOT Definitive, IFR surveys are Definitive Re: Distribution of Survey Data for Well 1D-30 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 12,044.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) AUG ;3 0 2:000 Alaska 0il & Gas Cons. Commission Anchorage North Slope AlaSka Alaska State Plane 4 Kuparuk 1D 1D-30 MWD Job No. AKMMO0104, ¢~ 0 0 · I O C~ ORI$1NAL SURVEY REPORT 24 August, 2000 Your Ref: API-500292296500 Surface Coordinates: 5959279.00 N, 560670.91 E (70° 17' 57.5081" N, 210° 29' 28.8722" E) Kelly Bushing: 105.30ft above Mean Sea Level RECEIVED AU6 5 0 ~000 Alaska Oil & Gas Cons. Commission Anchorage ORILL. IN(~i~' BOlutVIC::B~ A Halliburton Company Survey Ref: svy9281 Sperry-Sun Drilling Services Survey Report for 1D-30 MWD Your Reft AP1-500292296500 Job No. AKMMO0104, North Slope Alaska MeaSured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (fi) (ft) (tt) (fi) Ct) 0.00 0.000 0.000 -105.30 0.00 294.74 0.220 179.380 189,44 294.74 386.34 0.340 134.120 281.04 386.34 475.48 1.170 114.210 370.17 475.47 566.03 3.120 94.700 460.65 565.95 747.72 6.110 92.470 641.73 747.03 839.43 8.720 90.330 732.67 837.97 932.63 11.680 86.040 824.39 929.69 1027.51 14.100 86.100 916.87 1022.17 1122.80 16.560 87.560 1008.76 1114.06 1216.41 19.210 89.420 1097.84 1203.14 1311.50 23.290 90.150 1186.45 1291.75 1404.73 23.580 91.180 1271.99 1377.29 1501.10 23.910 91.490 1360.20 1465.50 1592.10 24.070 92.300 1443.34 1548.64 1684.19 25.140 95.490 1527.07 1632.37 1778.22 27.530 102.980 1611.36 1716.66 1871.69 30.660 105.140 1693.03 1798.33 1964.91 32.240 104.350 1'772.55 1877.85 2057.10 33.670 107.310 1849.91 1955.21 2152.45 36.070 109.470 1928.14 2033.44 2249.97 38.480 113.200 2005.74 2111.04 2344.11 38.840 112.900 2079.25 2184.55 2439.94 42.740 115.750 2151.80 2257.10 2529.81 44.560 118.800 2216.83 2322.13 0.00 N 0.00 E 5959279.00 N 560670.91 E 0.57 S 0.01 E 5959278.43 N 560670.92 E 0.93 S 0.20E 5959278.07N 560671.12 E 1.49 S 1.22 E 5959277.52 N 560672.14 E 2.07S 4.52 E 5959276.97 N 560675.45 E 2.89 S 19.11E 5959276.26 N 560690.04 E 3.14 S 30.94 E 5959276.11N 560701.88 E 2.53 S 47.42 E 5959276.85 N 560718.35 E 1.08 S 68.54 E 5959278.47 N 560739.45 E 0.29 N 93.69 E 5959280.04 N 560764.59 E 1.01 N 122.42 E 5959281.00 N 560793.31 E 1.12 N 156.88 E 5959281.39 N 560827.76 E 0.69N 193.95 E 5959281.25 N 560864.83 E 0.22S 232.75 E 5959280.66 N 560903.63 E 1.44 S 269.73 E 5959279.74 N 560940.61 E 4.07 S 307.96 E 5959277.42 N 560978.87 E 10.86 S 349.04 E 5959270.96 N 561019.99 E 21.94 S 393.11 E 5959260.24 N 561064.14 E 34.31 S 440.14 E 5959248.25 N 561111.27 E 48.01 S. 488.37 E 5959234.94 N 561159.60 E 65.24 S 540.08 E 5959218.13 N 561211.44 E 86.76 S 595.05 E 5959197.05 N 561266.58 E 109.79 S 649.16 E 5959174.47 N 561320.87 E 135.62 S 706.16 E 5959149.10 N 561378.07 E 164.07 S 761.27 E 5959121.10 N 561433.40 E Dogleg Rate (°/100ft) 0.07 0.26 0.96 2.27 1.65 2.86 3.28 2.55 2.61 2.90 4.30 0.54 0.37 0.40 1.85 4.35 3.53 1.75 2.34 2.83 3.39 0.43 4.51 3.10 RECEIVED AUG 3 0 000 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 0.00 0.32 0.69 1.85 4.90 17.41 27.32 40.59 57.20 77.20 100.52 128.90 159.76 192.30 223.53 256.58 294.33 336.97 382.78 430.33 482.74 54O.28 597.95 659.58 721.13 Continued,.. 24 Augus~ 2000-13:31 -2- Alaska Oil & Gas Cons. Commission Z~nnhoraae DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 1D-30 MWD Your Ref: API-500292296500 Job No. AKMMO0104, North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 2628,48 47.970 120.190 2285.03 2390.33 2718,96 51.680 122.650 2343.40 2448.70 2812.05 55.290 123,330 2398.78 2504.08 2904.79 58,380 123.760 2449.51 2554.81 2997.04 61.880 124.200 2495.45 2600.75 3091.65 64.250 126,590 2538.30 2643.60 3188.24 62,590 127,930 2581.52 2686.82 3280.79 61.550 128.130 2624.87 2730.17 3375.07 62,970 126.360 2668.76 2774.06 3470.61 63.010 128.100 2712.15 2817.45 3564.30 62.490 127,890 2755.05 2860.35 3659.93 64.300 127,110 2797.87 2903,17 3754.32 63,560 126,360 2839.35 2944.65 3847.54 62.650 125,080 2881.52 2986.82 3940.87 62.230 126,400 2924.71 3030.01 4034.95 61.930 127.060 2968.76 3074.06 4129.1t 64,650 125,530 3011.08 3116.38 4225.33 64,110 126.170 3052,69 3157.99 4318.32 64,050 126,130 3093.33 3198.63 4411.73 64.200 126,030 3134.10 3239,40 4504.89 64.230 126,970 3174.62 3279.92 4598.97 63.470 127,370 3216.09 3321.39 4691.68 63.300 126.390 3257.62 3362.92 4785.76 63.440 126.270 3299.79 3405.09 4876.41 62.820 126.230 3340.76 3446.06 199.18 S 823.30 E 235.24 S 882.25 E 275.98 $ 944.99 E 318.88 $ 1009.68 E 363.59 S 1076.00 E 412.45 S 1144,74E 464.74 S 1213.49 E 515.11S 1277.90 E 565.60 S 1344.32E 617.10 S 1412.09 E 668.37 S 1477.73 E 720.42 S 1545.56 E 771.13 S 1613.51 E 819.67 S 1681.00 E 868.00 $ 1748.16 E 917.71S 1814.78 E 967.48 S 1882.58 E 1018.29 S 1952.90 E 1067.63S 2020.43 E 1117.13 S 2088.36 E 1167.02 S 2155.79 E 1218.04 S 2223.08 E 1267.79 S 2289.38 E 1317.61 S 2357.13 E 1365.42 S 2422.34 E Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°ll00ft) 5959086,49 N 561495.71 E 3.60 5959050.91 N 561554.95 E 4.60 5959010.68 N 561618.01 E 3.92 5958968.31 N 561683.04 E 3.35 5958924.15 N 561749.71 E 3.82 5958875.85 N 561818.83 E 3.37 5958824.12 N 561887.99 E 2.12 5958774.27 N 561952.80 E 1.14 5958724,32 N 562019.63 E 2.24 5958673.38 N 562087.80 E 1.62 5958622.64 N 562153.85 E 0.59 5958571.15 N 562222.09 E 2.03 5958520.99 N 562290.44 E 1.06 5958473.01N 562358.31E 1.57 5958425.23 N 562425.85 E 1.33 5958376.06 N 562492.87 E 0.70 5958326.84 N 562561.06 E 3.23 5958276.60 N 562631.78 E 0.82 5958227.82 N 562699.70 E 0.08 5958178.88 N 562768.02 E 0.19 5958129.53 N 562835.84 E 0.91 5958079,06 N 562903.54 E 0.89 5958029.86 N 562970.23 E 0.96 5957980.59 N 563038.38 E 0.19 5957933.31N 563103.97 E 0.69 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 792.16 861.18 935.96 1013.58 1093.56 1177.88 1264.14 1345.74 1429.07 1514.08 1597.20 1682.57 1767.28 1850.39 1933.10 2o16.16 2100.21 2186.94 2270.53 2354.54 2438.36 2522.71 2605.51 2689.56 2770.38 24Augush 2000-13:31 -3- RECEIVED 30 _ 000 Alaska 0il & Gas Cons, Commi~.~inn Continued... DriliQuest 2. 00. 02 Sperry-Sun Drilling Services Survey Report for 1D-30 MWD Your Reft AP1~00292296500 Job No, AKMMO0104, North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (fi) 4970.71 62.410 127.220 3384.14 3489.44 5067.58 62.120 124.810 3429.22 3534.52 5161.32 61.690 126.410 3473.37 3578.67 5252.30 61.550 127.840 3516.62 3621.92 5253.45 61.430 120.710 3517.17 3622.47 5254.20 61.540 127.930 3517.52 3622.82 5348.48 61.250 134.310 3562.70 3668.00 5349.34 61.190 122.710 3563.11 3668.41 5372.65 60.880 127.100 3574.41 3679.71 5442.65 63.400 134.350 3607.15 3712.45 5443,06 63.380 123.750 3607.33 3712.63 5537.23 63.300 134.480 3649.69 3754.99 5538.47 63.170 133.400 3650.24 3755.54. 5629.95 62.690 126.620 3691.91 3797.21 5630.47 62.940 134.410 3692.15 3797.45 5631.05 62.660 127.410 3692.42 3797.72 5725,50 64.630 129.850 3734.35 3839.65 5726.01 64.710 134.930 3734.57 3839.87 5819.07 64.050 129.680 3774.83 3880.13 5912.18 63.570 126.530 3815.93 3921.23 6005.40 62.890 129.710 3857.93 3963.23 6099.47 65.240 122.350 3899.11 4004.41 6193.00 64.670 122.660 3938.71 4044.01 6286.60 64.190 125.670 3979.11 4084.41 6378.80 63.790 130.190 4019.56 4124.86 1415.49 S 2489.46 E 1465.90 S 2558.80 E 1514.05 S 2626.03E 1562.36 $ 2689.85 E 1562.93 S 2690.68 E 1563.30 S 2691.23 E 1617.69 S 2753.54 E 1618.16 S 2754.13 E 1629.82 S 2770.85 E 1670.19 S 2817.67E 1670.42 S 2817.95 E 1723.40 S 2883.12 E 1724.17 S 2883.92 E 1776.51 $ 2946.25 E 1776.81 S 2946.60 E 1777.14 S 2946.99 E 1829.98 S 3013.08E 1830.29 S 3013.43 E 1886.75 S 3075.45 E 1938.31 S 3141.18 E 1989.67 S 3206.65 E 2039.34 S 3275.02E 2084.87 S 3346.48 E 2132.27 S 3416.34 E 2183.19 S 3481.67 E Global Coordinates Dogleg Northings Eastings Rate (fl) (fl) (°llOOfl) 5957883.79 N 563171.47 E 1.03 5957833.94 N 563241.22 E 2.22 5957786.34N 563308.82 E 1.57 5957738.56 N 563373.03 E 1.39 5957737.99 N 563373.87 E 544.83 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 2854.04 2939.73 3022.40 3102.35 3103.36 5957737.63 N 563374.41 E 845.89 3104.02 5957683.75 N 563437.16 E 5.95 3186.15 5957683.29 N 563437.75 E 1181.77 3186.90 5957671.76 N 563454.56 E 16.53 3207.29 5957631.77 N 563501.70 E 9.84 3268.72 5957631.54 N 563501.99 E 2310.86 3269.09 5957579.09 N 563567.57 E 10.18 3352.78 5957578.33 N 563568.37 E 78.47 3353.87 5957526.51 N 563631.12 E 6.62 3434.86 5957526.21 N 563631.48 E 1333.24 3435.32 5957525.87 N 563631.87 E 1074.38 3435.84 5957473.58 N 563698.38 E 3.12 3520.22 5957473.27 N 563698.72 E 900.40 3520.67 5957417.32 N 563761.19 E 5.14 3603.73 5957366.30 N 563827.33 E 3.08 3687.09 5957315.47 N 563893.21 E 3.13 5957266.36 N 563961.97 E 7.46 5957221.41 N 564033.79 E 0.68 5957174.58 N 564104.02E 2.95 5957124.20 N 564169.76 E 4.43 3770.12 3854.60 3939.29 4023.71 4106.38 24 August, 2000 - 13:31 -4- RECEIVED 0 ?000 Alaska Oil & Gas Cons. Commission Continued... DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 1D-30 MWD Your Reft API.500292296500 Job No. AKMMO0104, North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 6471.74 64.500 132.070 4060.10 4165.40 6569.30 64.080 128,040 4102.43 4207.73 6569.94 64.090 127.830 4102.71 4208.01 6663.87 63.440 121,510 4144.27 4249.57 6759.02 62,910 128.810 4187.25 4292.55 6833.11 65,010 131,840 4219.78 4325.08 6977.29 65.000 127.820 4280,72 4386.02 7074.11 64.310 122.210 4322.20 4427.50 7167.51 63.890 120,950 4362.99 4468.29 7262.21 63.530 121.260 4404.94 4510.24 7354.76 63.260 122.790 4446.39 4551.69 7448.80 64,060 121.490 4488.11 4593.41 7545.25 63.620 121.380 4530.64 4635.94 7637.52 63.190 123.130 4571.95 4677.25 7731.52 63.820 125.310 4613.89 4719.19 7826.00 63,570 124.690 4655.76 4761.06 7921.32 63.430 124.570 4698.29 4803.59 8016.25 62.960 124.860 4741.10 4846.40 8107.01 64.070 122,500 4781.58 4886.88 8208.22 63.800 122.910 ~ 4826.05 4931.35 8296.79 63,560 123,730 4865.32 4970.62 8390.55 63.100 125.700 4907.40 5012.70 8485.21 62,650 124.420 4950.56 5055.86 8577.82 63.220 124,810 4992.70 5098.00 8671.56 64,000 128.950 5034.38 5139.68 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 2238.20 S 3544.66 E 5957069.70 N 564233.19 2294.75 S 3611.92 E 5957013.70 N 564300.89 2295.11 S 3612.38 E 5957013.35 N 564301.35 2343.01S 3681.61 E 5956966.01 N 564370.97 2391.85 S 3750.97 E 5956917.74 N 564440.71 2434.93 S 3801.70 E 5956875.07 N 564491.78 2518.61S 3902.03 E 5956792.21 N 564592.77 2568.80 S 3973.65 E 5956742.61 N 564664.78 2612.80 S 4045.22 E 5956699.19 N 564736.70 2656.66 S 4117.92 E 5956655.92 N 564809.74 4188.07E 5956612.62 N 564880.24 4259.43 E 5956568.37 N 564951.96 4333.30 E 5956523.82 N 565026.18 4403.07 E 5956480.36 N 565096.30 4472.62E 5956433.62N 565166.22 2700.54 S 2745.37 S 2790.52 S 2834.55 S 2881.86 S 4542.00 E 5956385.61'N 565235.98 4612.19 E 5956337.70 N 565306.56 4681.84 E 5956290.02 N 565376.59 4749.44E 5956245.53 N 565444.54 4825.94 E 5956197.03 N 565521.43 2930.44 2978.91 3027.17 3072.20 3121.33 S 4892.28 E 5956153.97 N 565588.11 S 4961.14 E 5956106.82 N 565657.35 S ~5030.10 E 5956058.99 N 565726.69 S 5097.97 E 5956012.69 N 565794.93 S 5165.11E 5955962.85 N 565862.47 3164.94 3212.64 3261.04 3307.89 3358.27 Dogleg Rate (°/100ft) 1.97 3.75 29.55 6.07 6.87 4.64 2.53 5.28 1.29 0.48 1,51 1.50 0.47 1.76 2.18 0.65 0.19 0.57 2.63 0.45 E 0.87 E 1.94 E 1.29 E 0.72 E 4.04 RECEIVED AUG 30 2000 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 4189.42 4276.86 4277.43 4361.63 4446.45 4512.64 4642.68 4730.12 4814.04 4898.81 4981.49 5065.70 5152.16 5234.61 5318.73 5403.42 5488.72 5573.45 5654.67 5745.55 5824.92 5908.70 5992.94 6075.41 6159.27 Continued... 24 August, 2000 - 13:31 -5- Alaska 0it & fi~,~ ¢0,~s. Com~issJor. /mchora. qe DrillQuest 2. 00. 02 Sperry-Sun Drilling Services Survey Report for 1D-30 MWD Your Reft AP1-500292296500 Job No. AKMMO0104, North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 8766.18 63.690 127.730 5076.09 5181.39 8863.80 63.450 126.200 5119.55 5224.85 8958.92 64.160 124.320 5161.54 5266.84 9052.84 63.930 126.060 5202.64 5307.94 9144.85 63.540 126.900 5243.36 5348.66 9238.00 63.550 125.350 5284.86 5390.16 9330.05 63.310 124.490 5326.04 5431.34 9423.26 63.170 125.020 5368.00 5473.30 9510.02 62.950 123.530 5407.31 5512.61 9608.29 62.790 123.460 5452.12 5557.42 9703.31 62.990 125.920 5495.43 5600.73 9797.41 62.840 126.010 5538.28 5643.58 9895.98 62.160 126.620 5583.79 5689.09 9989.38 62.940 129.650 5626.85 5732.15 10085.59 62.160 129.040 5671.20 5776.50 10173.87 62.500 129.220 5712.20 5817.50 10269.63 62.440 129.410 5756.46 5861.76 10364.19 63.160 131.720 5799.69 5904.99 10455.51 64.370 124.880 5840.09 5945.39 10550.83 63.920 125.680 5881.66 5986.96 10643.50 63.550 125.760 5922.67 6027.97 10734.72 63.400 124.020 5963.41 6068.71 10833.53 63.140 122.530 6007.86 6113.16 10928.49 62.720 121.720 6051.07 6156.37 11020.98 63.240 123.450 6093.09 6198.39 24 August, 2000 - 13:31 3410.96 S 5231.73 E 3463.52 S 5301.57 E 3512.79 S 5371.26 E 3561.45 S 5440.27 E 3610.51 S 5506.61 E 3659.67S 5573.97 E 3706.80 S 5641,48 E 3754.24 S 5709.86 E 3797.80 S 5773.77E 3846.06 $ 5846.70 E 3894.20 S 5916.24 E 3943.40 S 5984.05 E 3995,18 S 6054.50 E 4046.36 S 6119.67 E 4100.49 S 6185.70 E 4149.83 S 6246.35 E 4203.63 S 6312.05 E 4258.32 S 6375.93 E 4309.03S 6440.17 E 4358.57 S 6510.19 E 4407.09 S 6577.66 E 4453.77 S 6644.61E 4502.19 S 6718.39 E 4547.15 S 6789.99 E 4591.53 S 6859.41 E -6- Alaska State Plane 4 Kuparuk 1D 5955910.71 N 565929.50 5955858.72 N 565999.76 5955810.02N 566069.84 5955761.93 N 566139.23 5955713.41N 566205.96 Dogleg Rate (°/lOOft) 5955664.80 N 566273.71 5955618.22 N 566341.59 5955571.34 N 566410.34 5955528.30 N 566474.59 5955480.63 N 566547.91 Vertical Section Comment 5955433.06 N 566617.82 5955384.41 N 566686.02 5955333.21N 566756.88 5955282.57 N 566822.46 5955228.98 N 566888.92 E 1.20 6243.99 E 1.42 6331.31 E 1.92 6418.65 E 1.68 6501.08 E 0.92 6583.53 5955180.13 N 566949.96 5955126.87 N 567016.08 5955072.70 N 567080.39 5955022.52 N 567145.04 5954973.55 N 567215.46 E 1.49 6666.88 E 0.88 6749.21 E 0.53 6832.43 E 1.55 6909.77 E 0.17 6997.22 5954925.58 N 567283.31 5954879.44 N 567350.62 5954831.63 N 567424.78 5954787.25 N 567496.74 5954743.44 N 567566.51 E 2.31 7081.79 E 0.18 7165.54 E 0.88 7252.92 E 3.00 7335.61 E 0.99 7420.66 E O.43 7498.57 E 0.19 7583.16 E 2.30 7666.76 E 6.85 7748.41 E 0.89 7834.18 E 0.41 7917.26 E 1.71 7998.87 E 1.37 8087.10 E 0.88 8171.59 E 1.76 8253.94 RECEIVED ? 30 .000 Alaska Oil & ~,m,~ ¢o~$. C~mmisslon At~chorage Continued... DrillQuest ZOO.02 Sperry-Sun Drilling Services sUrvey Report for 1D-30 MWD Your Ref: API-500292296500 Job No. AKMMO0104, North Slope Alaska Alaska State Plane 4 Kuparuk 1D Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11046.65 63.210 124.480 6104.66 6209.96 4604.33 S 6878.42 E 5954730.79 N 567585.62 E 11115.46 63.070 124.350 6135.75 6241.05 4639.02 S 6929.06 E 5954696.51 N 567636.53 E 11210.63 62.670 125.360 6179.15 6284.45 4687.43 S 6998.57 E 5954648.67 N 567706.42 E 11260.40 62.630 124.100 6202.01 6307.31 4712.61S 7034.90 E 5954623.79 N 567742.95 E 11400.43 63.250 121.950 6265.72 6371.02 4780.56 S 7139.44E 5954556.69 N 567848.03 E 11463.39 63.020 122.710 6294.17 6399.47 4810.60 S 7186.90 E 5954527.04 N 567895.72 E 11558.18 62.940 124.610 6337.24 6442.54 4857.40 S 7257.18 E 5954480.81 N 567966.37 E 11658.83 63.460 126.950 6382.62 6487.92 4909.92 S 7330.06 E 5954428.88 N 568039.66 E 11754.07 62.710 127.820 6425.74 6531.04 4961.48 S 7397.53 E 5954377.87 N 568107.55 E 11754.13 62.930 126.590 6425.76 6531.06 4961.52 S 7397.58 E 5954377.84 N 568107.59 E 11850.22 62.770 126.690 6469.61 6574.91 5012.54 S 7466.18 E 5954327.37 N 568176.60 E 11946.22 63.140 127.930 6513.26 6618.56 5064.37S 7534.19 E 5954276.10 N 568245.01 E 11975.95 62.710 127.240 6526.79 6632.09 5080.51 S 7555.16 E 5954260.13 N 568266.12 E 12044.00 62.710 127.240 6558.00 6663.30 5117.11 S 7603.31 E 5954223.93 N 568314.55 E Dogleg Rate (°/100ft) 3.58 0.26 1.03 2.25 1.44 1.14 1.79 2.14 1.13 1860.12 Vertical Section Comment 8276.86 8338.25 8422.94 8467.14 8591.80 8647.93 8732.36 8822.16 8906.97 8907.02 0.19 8992.45 1.21 9077.84 2.52 9104.27 0.00 9164.66 Projected Survey All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 124.340° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12044.00ft., The Bottom Hole Displacement is 9164.89ft., in the Direction of 123.941 ° (True). * Grid Coordinate Scale Factors have been applied to all local coordinates. RECEIVED AUG Anchorage Continued... DrillQuest 2. 00. 02 24 August, 2000 - 13:31 - 7- Sperry-Sun Drilling Services Survey Report for 1D-30 MWD Your Reft AP1.500292296500 Job No. AKMMO0104, North Slope Alaska Alaska State Plane 4 Kuparuk 1D Comments Measured Depth (ft) 12044.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6663.30 5117.11 S 7603.31 E Comment Projected Survey Survey tool program From To Measured Vertical Measured Depth Depth Depth (fi) (fi) (fi) 0.00 0.00 12044.00 Vertical Depth (ft) 6663.30 Survey Tool Description MWD Magnetic 24 August, 2000 - 13:31 -8- RECEIVED AU(; 30 ~000 Alaska Oil & G~.~ Co,qs. Commission Anchoru~e DrillQuest 2.00.02 North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1D-30 Job No. AKMMO0104, ORIGINAL SURVEY REPORT 21 August, 2000 Your Ref: API-500292296500 Surface Coordinates: 5959279.00 N, 560670.91 E (70° 17' 57.5081" N, 210° 29' 28.8722" E) Kelly Bushing: 105.30ft above Mean Sea Level ;l=~r",r',v-;un. PRII-LINI3 A Halliburton Company RECEIVED AUG 2 3 2000 Alaska 0ii & Gas Cons. Commission Anchoraqe Survey Reh svy9280 Sperry-Sun Drilling Services Survey Report for 1D-30 Your Ref: API.500292296500 Job No. AKMMO0104, North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Local Coordinates Depth Depth Northings Eastings (fi) (ft) (ft) (ft) 0,00 0.000 0.000 -105.30 294.74 0.220 179.250 189.44 386.34 0.340 134.020 281.04 475.48 1.170 114.120 370.17 566.03 3.120 94.490 460.65 0.00 0.00 N 0.00 294.74 0.57 $ 0.01 386.34 0.93 $ 0.21 475.47 1.49 S 1.23 565.95 2.06 $ 4.53 747.72 6.110 92.540 641.73 747.03 839.43 8.720 90.240 732.67 837.97 932.63 11.680 86,070 824.39 929.69 1027.51 14.100 86.320 916.87 1022.17 1122.80 16.560 87.320 1008.76 1114.06 1216.41 19.210 89.210 1097.84 1203.14 1311.50 23.290 90.010 1186.45 1291,75 1404.73 23.580 90.940 1271.99 1377.29 1501.10 23.910 91.230 1360.20 1465.50 1592.10 24.070 92.100 1443.34 1548.64 1684.19 25.140 95.760 1527.07 1632.37 1778.22 27.530 102.280 1611.35 1716.65 1871.69 30.660 104.500 1693.02 1798.32 1964.91 32.240 103.990 1772.54 1877.84 2057.10 33.670 106.150 1849.90 1955.20 2152.45 36.070 108,550 1928.13 2033.43 2249.97 38.480 112.100 2005.73 2111.03 2344.11 38.840 113.710 2079.25 2184.55 2439.94 42.740 116.640 2151.79 2257.09 2529.81 44.560 119.130 2216.82 2322.12 Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) E 5959279.00 N 560670.91 E 5959278.43 N 560670.92 E 5959278.07N 560671.12 E 5959277.52N 560672.15 E 5959276.98 N 560675.45 2.87 S 19.12 E 3.12 S 30.95 E 2.50 S 47.43 E 1.10 S 68.55 E 0.28 N 93.70 E 5959276.28 N 560690.05 5959276.13 N 560701.88 5959276.88 N 560718.35 5959278.45 N 560739.46 5959280.04 N 560764.59 1.12 N 122.43 1.33 N 156.88 1.02N 193.96 0.28 N 232.76 0.79 S 269.74 E 5959281.10 N 560793.31 E 5959281.59 N 560827.76 E 5959281.58 N 560864.84 E 5959281.16 N 560903.64 E 5959280.39 N 560940.62 3.44 S 307.97 10.07 S 349.09 20.64 S 393.29 32.60 S 440.43 45.65 S 488.84 540.85 596.19 650.36 706.97 761.78 E 5959278.04 N 560978.87 E 5959271.75 N 561020.04 E 5959261.54 N 561064.31 E 5959249.96 N 561111.55 E 5959237.30 N 561160.06 61.94 S 82.49 S 105.38 S 132.06 $ 161 .O9 S E 5959221.43 N 561212.19 E 5959201.33 N 561267.69 E 5959178.88 N 561322.04 E 5959152.66 N 561378.85 E 5959124.08 N 561433.89 0.07 0.26 0.96 2.27 1.65 2.86 3.27 2.55 2.60 2.90 4.30 0.50 0.36 0.43 2,02 3.99 3.54 1.72 2.01 E 2.90 E 3.31 E 1.13 E 4.53 E 2.79 RECEIVED AUG 2 ;1000 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 0.00 0.33 0.69 1.85 4.90 17.41 27.31 40.57 57.22 77.21 100.46 128.79 159.58 192.03 223.17 256.24 293.93 336.38 382.05 429.39 481.52 538.81 596.45 658.24 719.87 Continued... 21 August, 2000 - 15:00 -2- Alaska Oil & Gas Cons. Commission DrillQuestZO0.02 Sperry-Sun Drilling Services Survey Report for 1D-30 Your Ref: API-500292296500 Job No. AKMMO0104, North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (fi) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 2628.48 47.970 121.030 2285.03 2390.33 2718.96 51.680 123.010 2343.39 2448.69 2812,05 55.290 123.850 2398.77 2504.07 2904.79 58.380 124.830 2449.50 2554.80 2997.04 61.880 126.240 2495.44 2600.74 3091.65 64.250 129.010 2538.30 2643.60 3188.24 62.590 129.200 2581.52 2686.82 3280.79 61.560 129.510 2624.86 2730.16 3375.07 62.970 128.070 2668.74 2774.04 3470.61 63.010 128.340 2712.13 2817.43 3564.30 62.490 128.780 2755.02 2860.32 3659.93 64.300 127.640 2797.85 2903.15 3754.32 63.560 127.770 2839.33 2944.63 3847.54 62.650 126.790 2881.50 2986.80 3940.87 62.230 127.130 2924.68 3029.98 4034.95 61.930 127.590 2968.73 3074.03 4129.11 64.650 126.510 3011.05 3116.35 4225.33 64.110 126.610 3052.66 3157.96 4318.32 64.050 127.170 3093.31 3198.61 4411.73 64.200 126,920 3134.07 3239.37 4504.89 64.230 127.420 3174.60 3279.90 4598.97 63.470 126.810 3216.06 3321.36 4691,68 63.300 126.900 3257.59 3362.89 4785.76 63.440 126.250 3299.76 3405.06 4876.41 62.820 126,580 3340.73 3446.03 196.84 S 823.44 E 233.51S 882.02 E 274.73 S 944.44 E 318.53 S 1008.53 E 365.03 $ 1073.60 E 416.53 S 1140.38 E 471.01 S 1207.41 E 522.86 S 1270.64 E 575.13 S 1335.68 E 627.78 S 1402.57 E 679.69 S 1467.70 E 732.57 S 1534.88 E 784.43 S 1601.96 E 834.79 $ 1668.11 E 884.53 S 1734.22 E 934.98 S 1800.30 E 985.64 S 1867.43 E 1037.32 S 1937.12 E 1087.53 S 2004.01 E 1138.16 S 2071.09 E 1188.84 S 2137.93 E 1239.80 S 2205.27 E 1289.51S 2271.59 E 1339.63 S 2339.13 E 1387.63 $ 2404.21 E 5959088.83 N 561495.83 5959052.64N 561554.70 5959011.92 N 561617.45 5958968.65 N 561681.88 5958922.68 N 561747.32 Dogleg Rate (°/lOOft) 3.73 4.43 3.95 3.45 4.02 5958871.73 N 561814.50 5958817.80 N 561881.96 5958766.46 N 561945.60 5958714.72 N 562011.06 5958662.63 N 562078.37 3.62 1.73 1.15 2.02 0.26 5958611.24 N 562143.91 5958558.91 N 562211.51 5958507.61N 562279.00 5958457.79 N 562345.55 5958408.58 N 562412.05 0.69 2.17 0.79 1.35 0.55 5958358.68 N 562478.52 5958308.56 N 562546.05 5958257.45 N 562616.15 5958207.79 N 562683.44 5958157.71N 562750.92 0.54 3.06 0.57 0.55 0.29 5958107.57 N 562818.16 5958057.16 N 562885.91 5958007.99 N 562952.62 5957958.43 N 563020.56 5957910.96 N 563086.01 E 0.48 E 1.00 E 0.20 E 0.64 E 0.76 RECEIVED AUG 2,5 2000 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 790.95 86o.01 934.81 1012.43 1092.39 1176.58 1262.66 1344.12 1427.31 1512.24 1595.30 1680.61 1765.25 1848.27 193o.92 2o13.94 2097.95 2184.64 2268.19 2352.15 2435.93 2520.28 2603.o8 2687.12 2767.93 Continued... 21 August, 2000 - 15:00 -3- Alaska 0ii & Gas Cons. Commissior, Ancho~e DrillQuest 2. 00.02 Sperry-Sun DrNling Services Survey Report for 1D-30 Your Ref: API-500292296500 Job No, AKMMO0104, North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (~) (~) (~) 4970.71 62.410 126.920 3384.11 3489.41 5067.58 62.120 127.820 3429.19 3534.49 5161.32 61.690 127.650 3473.34 3578.64 5254.27 61.400 127.400 3517.62 3622.92 5349.34 61.190 127.510 3563.29 3668.59 5443.06 63.380 130.170 3606.88 3712.18 5537.23 63.300 130.350 3649.13 3754.43 5629.95 62.690 131.050 3691.23 3796.53 5725.50 64.630 130.590 3733.62 3838.92 5819.07 64.050 131.430 3774.14 3879.44 5912.18 63.570 128.850 3815.24 3920.54 6005.40 62.890 129.400 3857.23 3962.53 6099.47 65.240 129.760 3898.37 4003.67 6193.00 64.670 129.190 3937.96 4043.26 6286.60 64.190 128.800 3978.36 4083.66 6378.80 63.790 129.220 4018.80 4124.10 6471.74 64.500 126.710 4059.33 4164.63 6569.94 64.090 126.950 4101.92 4207.22 6663.87 63.440 128.020 4143.45 4248.75 6759.02 62.910 127.200 4186.39 4291.69 6833.11 65.010 126.700 4218.91 4324.21 6977.29 65.000 125.900 4279.83 4385.13 7074,11 64.310 123.460 4321.28 4426.58 7167.51 63.890 122.490 4362.08 4467,38 7262.21 63.530 122.380 4404,02 4509.32 Local Coordinates Northings Eastings (ft) (fi) 1437.73 S 2471.30 E 1489.77 S 2539.44 E 1540.38 S 2604.83 E 1590.15 S 2669.65 E 1640.86 $ 2735.84 E 1692.90 S 2800.44 E 1747.29 S 2864.66 E 1801.16 S 2927.29 E 1857.13 $ 2992.09 E 1912.47S 3055.74 E 1966.33 S 3119.60 E 2018.84 $ 3184.17 E 2072.74 S 3249.36 E 2126.61S 3314.77 E 2179.74 $ 3380.39 E 2231.90 S 3444.77 E 2283.34S 3510.71 E 2336.38 S 3581.53 E 2387.65 S 3648.39 E 2439.47 S 3715.65 E 2479.48 S 3768.85 E 2556.84 S 3874.16 E 2606.63 S 3946.11E 2652.36 S 4016.59 E 2697.90 S 4088.25 E Global Coordinates Northings Eastings (fi) (ft) 5957861.41 N 563153.50 E 5957809.93 N 563222.05 E 5957759.85 N 563287.85 E 5957710.60 N 563353.05 E 5957660.43 N 563419.65 E 5957608.92 N 563484.66 E 5957555.06 N 563549.31E 5957501.71 N 563612.37 E 5957446.27 N 563677.61E 5957391.44N 563741.69 E 5957338.11 N 563805.98 E 5957286.12 N 563870.97 E 5957232.75 N 563936.59 E 5957179.42 N 564002.42 E 5957126.83 N 564068.46 E 5957075.19 N 564133.26 E 5957024,29 N 564199.60 E 5956971.83 N 564270.84 E 5956921.11 N 564338.10 E 5956869.84 N 564405.78 E 5956830.26 N 564459.29 E 5956753.76 N 564565.22 E 5956704.56 N 564637.55 E 5956659.41N 564708.40 E 5956614.45 N 564780.41E Dogleg Rate (o/looft) 0.54 0.88 0.49 0.39 0.24 3.43 0.19 0.94 2.08 1.02 2.54 0.90 2.52 0.82 0.64 0.60 2.55 0.47 1.23 0.95 2.90 0.50 2.39 1.04 0.39 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 2851.59 2937.21 3019.75 3101.35 3184.61 3267.31 3351.02 3433.12 3518.20 3601.97 3685.08 3768.02 3852.25 3936.65 4020.80 4103.39 4186.85 4275.25 4359.37 4444.14 4510.64 4641.24 4728.73 4812.72 4897.58 RECEIVED AUG 2 3 2000 Continued... DrillQuest 2.00.02 21 August, 2000 - 15:00 - 4 - Alaska 0il & G~s Cons, Cammi;si0r, Sperry-Sun Drilling Services Survey Report for 1D-30 Your Ref: API.500292296500 Job NO. AKMMO0104, North Slope Alaska Measured Depth (fi) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth~ Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 7354.76 63.260 124.080 4445.47 4550.77 7448.80 64.060 122.410 4487.20 4592.50 7545.25 63.620 122.380 4529.72 4635.02 7637,52 63.190 123.750 4571.03 4676.33 7731.52 63.820 125.710 4612,97 4718.27 7826.00 63.570 125,120 4654,84 4760,14 7921,32 63.430 125,610 4697,37 4802.67 .8016.25 62,950 126.430 4740,19 4845,49 8107.01 64,070 124,990 4780,67 4885,97 8208,22 63.800 123.720 4825,14 4930,44 8296,79 63,550 124.420 4864,42 4969,72 8390.55 63.100 125,620 4906,52 5011,82 8485,21 62,650 123.720 4949,68 5054,98 8577.82 63.220 124,530 4991,81 5097,11 8671,56 64.000 126.990 5033,48 5138,78 8766.18 63,690 126.610 5075.19 5180,49 8863.80 63,450 126.600 5118,64 5223,94 8958,92 64.170 125.440 5160,63 5265,93 9052,84 63,930 125.860 5201,72 5307,02 9144.85 63.530 126.720 5242,45 5347,75 9238.00 63.550 125.780 5283.96 5389.26 9330.05 63.310 126.120 '5325.13 5430.43 9423,26 63,170 125,900 5367,10 5472,40 9517.81 62.950 124.820 5409.93 5515,23 9608.29 62.790 125.090 5451.19 5556,49 2743,24 S 4157,46 E 2789,44S 4227,95 E 2835,82 S 4301,04 E 2880,83 S 4370,19 E 2928,76 $ 4439,32E 2977,84 S 4508,35 E 3027,21 S 4577,91 E 3077,03 S 4646.44 E 3124,44 $ 4712,39 E 3175,75 $ 4787,45 E 5956569,67N 564849,99 5956524,05 N 564920.83 5956478,27 N 564994,29 5956433,82 N 565063.79 5956386.46 N 565133.30 5956337.94 N 565202.72 5956289.13 N 565272.67 5956239,87 N 565341.59 5956193,00 N 565407,92 5956142,31N 565483,38 3220,22 S 4853,21 E 5956098,38 N 565549,49 3268,29 S 4921,82 E 5956050,86 N 565618.48 3316.22 $ 4991,10 E 5956003,50 N 565688,14 3362,48 $ 5059,37 E 5955957,79 N 565756.77 3411,55 S 5127,50 E 5955909.28 N 565825.29 3462,43 S 5195,50 E 3514,56 S 5265,68 E 3564,75 S 5334,71E 3613,97 S 5403,34 E 3662,80 $ 5469,84 E 3712,11 S 5537.09 E 3760,44 $ 5603,74 E 3809,37 S 5671.06 E 3858,15 S 5739,80 E 3904,29 $ 5805,80 E 5955858.96 N 565893.70 5955807,40 N 565964.29 5955757,78 N 566033.72 5955709,12 N 566102,73 5955660,83 N 566169.62 5955612,07 N 566237.26 5955564,28 N 566304.29 5955515.90 N 566372.00 5955467,68 N 566441,12 5955422,08 N 566507.48 Dogleg Rate (°/lOOft) 1.67 1.80 0,46 1.41 1.98 0.62 0.48 0,92 1.88 1,16 0.76 1.24 1,85 0,99 2.49 0.49 0.25 1.33 0.48 0.94 E 0.90 E 0,42 E 0.26 E 1.04 E 0.32 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 4980.31 5064,56 5151,08 5233,57 5317,69 5402.37 5487.66 5572.35 5653.55 5744.47 5823,85 5907,62 5991.86 6O74.33 6158.27 6243.12 6330.47 6415.78 6500.21 6582.67 6666,01 6748,31 6831,50 6915.77 6996.29 RECEIVED AU(; 2 000 Continued.,. DrillQuestZO0.02 21 August, 2000 - 15:00 - 5 - Alaska Oil & Gas Cons. Com~'~ssion Sperry-Sun Drilling Services Survey Report for 1D-30 Your Reft API-500292296500 Job No, AKMMO0104, North Slope Alaska Measured Depth (ft) Incl. Azim, Sub-Sea Depth (ft) Vertical Depth (ft) 9703.31 62.990 127.000 5494.50 5599.80 9797.41 62.840 126.030 5537.34 5642.64 9895.98 62.160 125.870 5582.86 5688.16 9989.38 62.940 128.630 5625.92 5731.22 10085.59 62.160 127.590 5670.27 5775.57 10173.81 62.500 128.090 5711.24 5816.54 10269.63 62.440 128.250 5755.53 5860.83 10364.19 63.160 128.980 5798.75 5904.05 10455.51 64.370 126.340 5839.12 5944.42 10550.83 63.920 125.950 5880.69 5985.99 10643.50 63.550 127.240 5921.70 6027.00 10734.72 63.400 123.860 5962.45 6067.75 10833.53 63.140 124,820 6006.89 6112.19 10928.49 62.720 123.330 6050.11 6155.41 11020.98 63.240 124.310 6092.13 6197.43 11115.46 63.080 125.400 6134.79 6240.09 11210.63 62.670 125.880 6178.18 6283.48 11260.40 62.630 124.880 6201.04 6306.34 11400.43 63.250 123.060 6264,75 6370.05 11463.39 63.020 122.970 6293.20 6398.50 11558.18 62.940 124.860 6336.27 6441.57 11658.83 63.470 127.230 6381.65 6486.95 11754.13 62.930 125.770 6424.62 6529.92 11850.22 62.770 127.470 6468.47 6573.77 11946.22 63.140 128.310 6512.12 6617.42 Local Coordinates Northings Eastings (ft) (ft) 3954.05 S 5874.18 E 4003.91 $ 5941.51E 4055.24 S 6012.29 E 4105.40 S 6078.26 E 4158.10 $ 6145.43 E 4206.03S 6207.13 E 4258.54 S 6273.93 E 4311.03S 6339.65 E 4361.06 $ 6404.49 E 4411.65 $ 6473.76 E 4461.19 S 6540.48 E 4508.64 S 6606.87 E 4558.42 S, 6679.74 E 4605.79 S 6749.77E 4651.65 S 6818.22 E 4699.83 S 6887.40 E 4749.19 S 6956.23 E 4774.78 S 6992.28 E 4844.45 S 7095.69 E 4875.05 S 7142.79 E 4922.16 S 7212.86 E 4975.03S 7285.49 E 5025.63S 7353.87 E 5076.62 S 7422.49 E 5129.14 S 7489.97 E Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°ll00ff) 5955372.88 N 566576.26 E 1.80 5955323.57 N 566643.98 E 0.93 5955272.82 N 566715.17 E 0.70 5955223.19 N 566781.53 E 2.75 5955171.05 N 566849.12 E 1.26 5955123,62N 566911.20 E 5955071.66 N 566978.42E 5955019.71N 567044.54 E 5954970.20 N 567109.78 E 5954920,18 N 567179.45 E 5954871.18 N 567246.56 E 5954824.28 N 567313.33 E 5954775.09 N 567386.59 E 5954728.29 N 567457.00 E 5954682.99 N 567525.81E 5954635.37 N 567595.36 E 5954586.58 N 567664.59 E 5954561.28 N 567700.84 E 5954492.46 N 567804.80 E 5954462.24 N 567852.14 E 5954415.70 N 567922.58 E 5954363.43 N 567995.63 E 5954313.39 N 568064.40 E 5954262.95 N 568133.43 E 5954210.99 N 568201.32 E 0.63 0.16 1.03 2.91 0.60 1.31 3.32 0.91 1.47 1.10 1.04 0.62 1.79 1.24 0.39 1.78 2.17 1,48 1.58 0.87 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 7080.83 7164.55 7251.95 7334.71 7419.90 7497.89 7582.67 7666.54 7748.30 7834.04 7917.07 7998.66 8086.90 8171.46 8253.85 8338.14 8422.82 8467.02 8591.71 8647.86 8732.30 8822.09 8907.09 8992.52 9077.86 RECEIVED AUG 2,5 ?_000 Continued,,, 21 August, 2000 - 15:00 -6- Alaska 0il & Gas Cons, DrillQuest 2.00,02 Sperry-Sun Drilling Services Survey Report for 1D-30 Your Ref: API-500292296500 Job No. AKMMO0104, North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (~t) (fi) (~t) (~t) (ft) 11975.95 63.710 128.420 6525.42 6630.72 5145.64 S 7510.81 E 12044.00 63.710 128.420 6555.56 6660.86 5183.55 $ 7558.61 E Global Coordinates Dogleg Northings Eastings Rate (fi) (ft) (°/lOOft) 5954194.66 N 568222.30 E 5954157.13 N 568270.40 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 124.340° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12044.00ft., The Bottom Hole Displacement is 9165.25ft., in the Direction of 124.442° (True). * Grid Coordinate Scale Factors have been applied to all local coordinates. 1.95 0.00 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 9104.38 9165.24 Projected Survey R C VED Continued... 21 August, 2000 - 15:00 -7- Anchorage DrillQuest ZOO.02 SPerry-Sun Drilling Services Survey Report for 1D-30 Your Ref: API-500292296500 Job No. AKMMO0104, North Slope Alaska Alaska State Plane 4 Kuparuk 1D Comments Measured Depth (fi) 12o44.00 Station Coordinates TVD Northings Eastings (fi) (ft) (ft) 6660.86 5183.55 S 7558.61 E Comment Projected Survey Survey tool program From To MeasUred Vertical Measured Vertical Depth Depth Depth Depth (fi) (ft) (ft) (ft) o.oo o.0o 12044.00 6660.86 Survey Tool Description AK-6 BP_IFR-AK RECEIVED AUG2~ ~ ~ 21 August, 2000 - 15:00 -8- Alaska Oil & Gas Cons. Commission Anchorage DrillQuest 2. 00. 02 "' STATE OF ALASKA (¢ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Vadance _ Perforate _ Other_X Annular Injection 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development ___X Exploratory _ Stratigraphic __ Service _ 4. Location of well at surface 387' FNL, 419' FEL, Sec. 23, T11 N, R10E, UM (ASP: 560671,5959279) At top of productive interval 107' FNL, 1607' FWL, Sec. 30, T11N, R11 E, UM (ASP: 568021, 5954345) At effective depth At total depth 298' FNL, 1855' FWL, Sec. 30, T11N, R11 E, UM (ASP: 568271,5954157) 6. Datum elevation (DF or KB feet) RKB 30' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 D-30 9. Permit number / approval number 200-104 10. APl number 50-029-22965-00 11. Field / Pool Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total depth: measured 12044 feet Plugs (measured) true vertical 6661 feet Effective depth: measured 11975 feet Junk (measured) true vertical 6630' feet Casing Length Size Cemented Conductor 105' 20" 16.5 cu yards ASl, type III Surface 6843' 9.625" 710 sx AS III Lite, 460 sx LiteCRETE Production 11275' 7" 18o sx Class G Liner 888' 3.5" 212 sx Class G ORIGINAL Measured Depth 135' 6873' 11305' 12041' Truevertical Depth 135' 4341' 6327' 6660' Perforation depth: measured 11800'-11805' true vertical 6551'-6553' Tubing (size, grade, and measured depth 3.5", 9.3#, L-80 @ 11179' Packers & SSSV (type & measured depth) Baker ZXP pkr @ 11161', No SSSV RECEIVED 13. Attachments Description summary of proposal m Detailed operations program m BOP sketch__ Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets mX 14. Estimated date for commencing operation September 1,2000 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __X Service __ Gas __ Suspended 17. I hereby certihj that the foregoing is true and correct to the best of my knowledge. Signed,~T.~W~,~ ~""~,.,.,l..~%-',,,,,~.__ ~ Title: Drilling =.-.~:.'~cc.':.-.; FOR COMMISSION USE ONLY Questions? Call Tom Brockway 263-4135 Date ~ / Z. ¥~ ~ Prepared b~/ Sharon AIIsup-Drake Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity __ BOP Test _ Location clearance J ~'(~)(~ "2 ~ r~ Mechanical Integrity Test __ Subsequent form required 10-;~ / e rt order of the Commission ORIGINAL SIGNED BY Approved {~Jltl~issioner Date (;~/"~('~/~)~¢ Approved by - D Taylor Seamount Returned -~ '""'-- - OO~ / ~"'~)1~ ~ SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 · - - I I - ' Casing Detail 9-5/8" surface casing WELL: 1D-30 Phillips Alaska Inc DATE: 7/26/00 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Nabors 16E RKB = 34.40' TOPS 9-5/8" Landing Joint (RKB) 34.40 9-5/8" FMC GEN V FLUTED MANDREL HANGER 1.90 34.40 jts 3-175 9-5/8", 40#, L-80 BTC-MOD (173 jts) 6755.71 36.30 Gemeco Float Collar 1.43 6792.01 its 1-2 9-5/8", 40#, L-80 BTC-MOD (2 jts) 78.33 6793.44 Gemeco Float Shoe 1.70 6871.77 BTTM OF SHOE @ 6873.47 Shoe @ 6873' 6873.47 TD of 12-1/4" hole = 6883'MD 4340' TVD 13 Weatherford short spiral ridgid centralizers on Jts # 1 - 13 1 Weatherford bowspring on casing collars every 3rd Jt starting with Jt No. 16 to surface. 53 total 8 joints of casing will be left in pipeshed. ,bG 2 8 Anchorage £emorks: String Weights with Blocks: 330k Up, i 60k Dn, 70k Blocks. Ron 775 joints of cosing. Drifted cosing with 8.67g" plostic robbit. Used Best-o-Life 2000 threod compound on oll connections. Phillips Alaska Drilling Cementing Details Well Name: 1D-30 Report Date: 07/29/2000 Report Number: 9 Rig Name: Nat)om 16E AFC No.: AK0095 Field: KRU Centrallzere ' State type used, intervals covered and spacing COmments: . i:. ':' :' ' ::: . Ran I short rigid centrilizer on Joints 1-13. Ran I bow spring centrilizer every third joint to surface. Note; unable to run rigid · ~ centrilizere on joints I & 3 due to float equuipment ran bow springs instead. Mud i . : Weight: PV(prior cond): PV(affer cond): I YP(prior cond): YP(affer cond): CommentS: . :. 9.6 54 16J 48 17 :' · Gels before: Gels after: Total Volume Circulated: i: i i i " 22/38 4/5 1692bble. Wash :: ii: :: 0 ii;: i :: Type: Volume: Weight: .. . . Comments:.~ : : ~::: ARCO B47 20 8.4 ..: ..:: I Mixwtrtemp: No. of Sacks:I Weight: Yield: Additives: 'G' wi 30% D053, 0.696% D046,1.5% D079,1.5% S001, 50% D124, 9% D044 : : Additives: : ' : : 'G' wi 0.650% D065, 0.100% D046, 0.300% D079. b,~ia~mi~ :?~ ~; ~-i::~ ::::~:: ::~ (: :i: ~i ?~, Rate(before ta, at shoe): Rate(tail around shoe): Str. Wt. Up: Reciprocation length: Reciprocation speed: Str. Wt. Down: 20 20 fpm 160k Theoretical Displacement: Actua Displacement Str. Wt. in mud: 515 517 Calculated top of cement: CP: Bumped plug: Floats held: Surface Date:7/29/00 No Yes Time:00:26 hre Remarks:Casing went to bottom good. Had to wash thru Bridge @ 3000'. Circ & Cond mud @ 8 bpm with no losses. Recip. casing until dropped top plug. Had full returns thru entire job. Got 54 bbls 10.7 cement back to surface. Company: Rig Contractor: I Approved By: Cement Dowell NABORS I Fred Herbert CASING TEST and FORMATION INTEGRITY TEST Well Name: 1D-30 Date: 7/29/00 Reason(s) for test: Supervisor: Fred Herbert [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9.625", 40#, L-80, BTC Casing Setting Depth: 6,873' TMD Hole Depth: 4,341' TVD Mud Weight: 8.5 ppg Length of Open Hole Section: 6,903' TMD 4,353' TVD 30' EMW = Leak-off Press. + Mud Weight. -_ 1,200 psi 0.052 x TVD 0.052 x 4,353' EMW for open hole section = 13.8 ppg + 8.5 ppg Pump output = 0.0846 bps Fluid Pumped = 6.4 bbl 3.200 psi 3,100 psi 3,000 psi 2,900 psi 2,800 psi 2,700 psi 2,60O psi 2,500 psi 2,400 psi 2,300 psi 2.200 psi 2,100 pa 2,00O psi 1,g00 psi I Il--e-- LEAK-OFF TEST J~",a'-CASING TEST ~---H -~-- LOT SHUT IN TIME ~H-~- CASING TEST SHUT IN TIME 1,800 psi · 1,700 psi 1,600 psi 1,500 psi 1,1130 psi 700psi I I~rJ~' I I I I I I I I ;I 500 psi 300 pd 100pdl- I ~ I I I I I I I I I II STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE j ..................... ~'~ii~;; ......... iJ'~;~i' ..... ! ........................................... ,,. j .................... .2.~!.k.~ ......... .0..,,.?.L ..... i 4 stks 25 .$i J .............................. ~-, [ ......... .j. j ..................... .~.?.!.k.~ ........ .S..0. p..~! ..... j .- 8 stks 100 psi j .................... .L2. ~.t.k.~ ....... .2.Z.s..~5! .... j .................... .L4_~.tk.~ ...... ~.s..o...p~! .... J 16 stks 450 psi J ................................................... j ~ 16 stks .... .s.~.o...p~!...~ j ................... ~.~..s.!.k_s. ...... Z~.s..~.s.! .... j .................... .2..4.?.!~.s. ....... .e..2_s...p.s.! .... j ................... .~..s_.s..~ ...... ~.o..o_p.s.! .... ! 28 stks J 1,000 ,si J ............................... t ....... ' , 30 stks , 1,050 Ds~ , ................................. ,~ ........... [ ...... J i · ~ 32 stks ~ 1,100 ps~ I ................................ ; .............. '-'- L ................... .3..4..s..tk..s....:...!,~..S..0..p..s:_ I ' ~ ................... .3..6..s..t.k..s. ..... .t,.2.0..o..£.s.L. j ................... .3. .8. ?_.t.k. ?. ..... .?.o..o...p.?.L J 40 stks1,000 Esi j 50 stks900 jE. si I. : 76 stks 900 psi 1 ~ SHUT IN TIME SHUT IN PRESSURE ! i'"i:i;~'~i~-"T ............... i .... 1.0 rain 850~si ! ....... Ei!'"l ....4...o_.mj.n_.. .... ~..op.~.~!...i ....s...o_mj .n. ........................ ~.o..o...~L.i .... .o....o..?.!.n. ...................... ~.o..o.~!...i 70 rain 800~}~i ! '--;-; .......... 't' ......................... '" ...... 80rain ~ ' 800n$! ~ ..... -' .......... q ............................ '~ ...... 4 · ! · OOmm ~ 800p~ , . L!.O...9...m. Ln. ..................... ~.o_.o...~!...! CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE .................... i~'~i'~:~ ......... Yi~'i' .... i 4stks 50.si l ................ a. ............... J ......... ,- ....... 8 stks 100 ~si .................... i~'~'ti~ ...... 'i~'~i'"I .................... ~..S...s!..k.s. ...... ..~.o..o..R?.i...,i ...2..O...s.t.k..s.... 450 Esi l .................... .2..8..?.t .k~ ...... ..8.s..o..R.s:.__~ 32 stks 1,025 p. si J ................ ..... .................... ..... ................... .4..4..?!..k~ ..... .!:.S..S.O..P.~[.. ................... .4..S...s!..k.s. ..... .!,?..o..o.R~L. .................... .5..2...~.t.k~ ..... .!,.~..O..O.R~L J 56 stks | 2,100 p. si ................. ................. [..~.s...s.t~.s... L ..2., 7..o.9' p.?.i.., ................. L..Z~.?.Lk~..j...2.:.~..o.o..p.~L j 74stks j 3,000 psi j SHUT IN TIME J SHUT IN PRESSURE ._..9...°...m..i.n....L .................. ..~:.°.g.9.E~.L 1.0 min ! 3,000 p,,~,,,,, .... ~'.i5'~'i~'''r .................. ~i;b'6'~'i' 3.0 min[ 3,000 p_sJ ""~,:iS'~,'iB'"~ ............... _..5...o_m.j.n...., .................. &.o..o..o.p..s.L, ._...~...o...mj.n....L ................ '...a.-'P.9.9.p.~i... ....?:.o...m.J.n....' ............... ~...3.., p.9.9.p..s.[.. 8.0 min[ 3,000 p. si _I..O.-.o..BLn._' ............... .~...3., .o..o..o.P_S. LJ 15 0 min ! 3,000 ~si ! ..... ::" ......... F ........................... " ..... 20 0 min : ; 3,000 p. si ..... Z.' ......... ~ ............... 4 ................ ...2..~...o...m. Ln...' ............... ,..~,.o..o..o.p.~i.j _.s..o:.o_m.L....[ ............... j..~,.o..o.o..p.~i..j NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 1D-30 Reason(s) for test: Date: 8/12/00 Supervisor: Don Mickey r-! Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 40# x 7" 26# Annulus Casing Setting Depth: 6,883' TMD Hole Depth: 4,340' TVD E.$'~ Mud Weight: 7.6 ppg Length of Open Hole Section: 10,505' TMD 5,967' TVD 3,622' EMW = Leak-off Press. + Mud Weight = 650 psi 0.052 x TVD o.o52 x 5,967' EMW for open hole section = 9.7 ppg + 7.6 ppg Pump output = 0.0197 bps Fluid Pumped = 10.0 bbl t,0(X) psi IA& ~°¢~!~~~~~~i~.~i~i.~¢®~:~i!~!:~~~~ ]_j_J_J LEAK-OFF TEST IIIIl~G~~!i::~iiill I I I I I I I I I I 11111 I ~P~L~~cASiNGTEST III I I I i'i~T"T~'j~*i>>*i~'"'j¥'~i*'~]'~'T*j=j-i i i i i i i i i i i t i i i iI L~-.~"-'-LOTSHUTINTIME 7~""J J J I+CASlNGTESTSHUTINTIMEJ J JJJIIIIJ I IIIJ I lllJIIIl~ J ~o ps, ~~1 TIME LINE I I I I I I Pr'l I I I I-I I I I Iq I I I. I ~ I I I I T I I I I I I I I "Jl I'llli Iii I[ I Iii . II I1 11111111 I '11111 1111 1111 I STROKES LEAK-OFF DATA MINUTES FOR .... ' ........... ! .... ~'~i'~;"' ...... ~'~;~i' .... 1 ·, ................ ~ ....................... ~. ........ ................. L...s..t?.!~ ...... ~.o..o.,.._s.i...j J 102 stks 200 psi J '"5~b"~'~i"-! ................ ~':~'~':~'i;iE~'- ii:iiiiiiiiZi i 255 stks 500-1E.si ...................................l 306 stks ~b' ~'~1," , · , j 357 stks 650ps~ i ................ .1. ............... ~ ......... .~. ...... j J 408 stks 650osi J , ................ "1- ........................ '-"- ...... 't j J 459 stks 650~si ,- ............... -I ......................... -~ ...... i = 510 stks 650 ps~ , ! i , i i I I I I i ........ '::; ..... ' .... = .... ~'":""' '"=' '[ ....... .............. ~L[,..~.__~.~.. ,x ............. , "'~2,~ ?":;~'$'~,2'~ 'C:.5~:~ ~~---i ................ +;~7~5~-~ ................. CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE I t t J SHUT IN TIME SHUT IN PRESSURE 3.0 min ................................. . ................. .. ~ .................................................. 0.0 min 650 psi 4.0 min ................ ..I, ............... J, .......... ~. ...... ,/ I. ................ t_ ............... .j ................. .I ....t:.o...m.!.n. ....................... .s..s..o.~.s.] ....... ..s:.o_.m..Ln. ................... ~ .................. ....2.:g...m.i.n., ....................... .s..2..s.~?.i ....... .?:.o_.m..Ln' ................... j .................. ....3.:.o...m.].n. ...................... .s..o..o...p?..i ....... Z:.O...m..i.n. .................... l ................... 4.0 min 500~..si 8.0 min ' b..5.:.o...m.i.n. ........................ .5_0..o..~.s. i .... 9.0 min 6.0 min 500 psi ---~-~:~-~ .................. 1 .................. ........... 7.0 m,n: .... ?, ............... J, ............. 500 Ds,:'"i, '"i'~:~'~i~"i ............... i .......... ' ....... ................ 8.0 mln' +,' ............... f,' ......... 500DSI'" ....... ' ~I ...... ~)~:~ ~t~ ~ ............... I .................. ............ .---4 ................ ~ ......... ~ ...... 4 ......;' .......... I- ............... 4 .................. · I I · I ' 9.0m~n = = 500ps~., 25.0 mtn ; , i--- ............. -t- ............... ,~ ................. 'J ........................................ ' i i · i L .1..0....0_ .m_!.n. _ ~_ ............... !....5..0..0.p_ .s. !....= ~'6:~ ; SHUT IN TIME SHUT IN PRESSURE 1.0 rain 2.0 min NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: Date: Reason (s) for test: Supervisor: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9.625", 40#, L-80, BTC Casing Setting Depth: 6,873' TMD Hole Depth: 4,341' TVD Mud Weight: 9.8 PP9 Length of Open Hole Section: 11,093' TMD 6,230' TVD 4,220' EMW = Leak-off Press. + Mud Weight -- 600 psi 0.052 x TVD 0.052 x 6,230' EMW for open hole section = 11.7 ppg + 9.8 ppg Pump output = 0.0846 bps Fluid Pumped = 5.9 bbl 3,2(10 psi 3,100 psi 3.000 psi 2.900 psi 2,800 psi 2, 700 psi 2,(:00 psi ; 2.500 psi : 2,400 psi i 2,200 psi 2,100 psi 2,000 psi 1/;~0 psi 1,800 psi 1,700 psi 1,600 psi 1,5C]0 psi 1,400 psi 1,300 pa 1,200 psi 1,100 psi 1,000 psi ~ psi 800 psi 700 psi 6(]0 psi E,q~O psi 400 p~ 300 psi 200 psi 100 psi 0 psi - LEAK, OFF TEST ~CASING TEST -~ LOT SHUT IN TIME ~ CASING TEST SHUT IN TIME I TIMELINE .,~ STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ..................... .o..s.!~.s....l ..... P..e.sJ. .... ..................... .~..s..~...l .... .s..o..e.~.~ ..... ~ 4stks i 100usi : ................ '[- ............... f .......... " ...... '1 , , · , -i 6stks , 125ps, , , , : 8stks ; 175psm ................... .1..O.~!.k. ?...i ....2..2..5J~.sj...i .................... .t .2. ?. !.k_s. ..... .2..s..o.£.s.! .... .................... .'m_4.~!.k.~ ...... &o2.p. sj...! ................ ~..!.s..s.!.k.~ ...... ~.s..['~.L..i ................... !.~.?_!.k.?. ...... &7..S...p.?! .... ................... .2..o..s.!_k.?. ..... .4..o..o..esj .... 22 stks 450~si j .............................................. .................... .2. .4. .s. !.k. ?. ..... .5..O..O..p?.:...i .................... .2..S..s.!.k.?. ...... .s..s..o..e?L.j 28 stks 600 psi i ................ 3' ............... 1' ................. '1 ................ j....~..o.~.t.k.~..i....s..o..o...P~i...i . . . j 32 stks i -6--0-9 e-s-l--,l 34 stks 525 psi I 45 stks 500 ;)si ! ...... - .................... ------------4 .......... '- ...... ................... .s..s.?.!.k. ~ ...... .s..o..o...p~L., ................... _s..s..s.!~.s. ....... .s..o..o..e~i .... ................... Z.O.~!.k..s. ...... AO..O..P...s..~ .... I I ................. I I CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ..................... .o..:.Lh,. ......... .o..~.~. .... , .... .... ........ I. ........ ... .... .I.......... ....... ................. L ............... J ................. I SHUT IN TIME JHUT IN PRESSURE .... L..o_.m.!n. ............................... 2.0 min I ................................................ SHUT IN TIME SHUT IN PRESSURE 3.0 min 0.0 min 500 Esi 4.0 min I ................ ~- ............... & ..... ........... a i. ................ L ................................. .~ _J=o_~Ln. .................... L_.4..7..s..p. sj ....... _5...o_m. !n. ...................................... , ....4.:.o.._m.!.n' ....................... .4. .5. .0. £.s. .~ .... ....5.:.o...m.!.n.... . .... .4..5..0..~s..i .... 6.0 min 450 psi i .......... . .... .,.a. ............... &.... ...... -- ...Z:g_..m.i.n.._ i.L ................. ,...4..s_.oj~! .... ....8.:.o...m.i.n._L .................. ...4..S..O._p.s.,_~ .... ...9.:.o...m.!.n.../ .................... .4..s..o.~..?L. ,...1..o....o...m. Ln.. ,:- ................... .4..5..o..p.s.! .... ,..Z:.O...m.j.n. ..................................... .j ....~:.o...m..i.n. .................................... 9.0 min _Lo:.o...m. Ln...~ ................ .. _t .s:.°. _n"..i.n...L ............... J .................. ' ....2..o.._o.._m_Ln...L ............... ' ...2..s:.o_m. Ln...[ ................ { ................. ,: 30.0 m{n { , NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ALASIIA OIL AND GAS CONSERVATION COPlMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 James Trantham Drilling Engineering Supervisor Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510,0360 Re: Kupamk River Unit 1D-30 Phillips Alaska, Inc. Permit No: 200-104 SUr Loc: 387'FNL, 419'FEL, Sec. 23, T11N, R10E, UM Btmhole Loc. ' 336'FNL, 1920'FWL, Sec. 30, T1 IN, R11E, UM Dear Mr. Trantham: Enclosed is the .approved application for permit to drill the.above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given. by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~~Dahiel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~ / 5'7" day of July, 2000 # dlf/Enclosures Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. GENERAL DRILL AND COMPLETE PROCEDURE EBA PRODUCER ECE VED KRU 1D-30 JUL '/9 2000 A/a~a O~ ~ ~as Co~ Uomm~ssion General Procedure: .A~orage 1. Excavate cellar, install cellar box, set and cement 20" conductor to +/- 150' RKB. Weld landing ring on conductor. 2. Move in / rig up Nabors Rig 16E Install diveAer & function test same. 3. Spud and directionally drill 12-1/4" hole to 9-5~8" su~ace casing point (+/6869 MD') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Run and cement 9-5~8" 40.0~ L-80 BTCM casing to sudace using ligh~eight permafrost cement lead slur~ to assure cement returns to the sudace. Adequate excess cement will be pumped to ensure cement reaches the sudace during the first stage cement job. Displace cement with mud. 5. Nipple down diveAer and install wellhead. Nipple up BOPE and test to 5000 psi. Record results. 6. Shut in BOP's and pressure test casing to 3000 psi for 30 minutes per AOGCC regulations. Record results. 7. Drill out cement and '20' of new hole. Pedorm formation integri~ test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 ~C 25.030 (0.5 ppg less than the FIT or LOT EMW). 8. Directionally drill 8-1/2" hOle to mid-point of the HRZ (11069' MD) according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. Pedorm second LOT at to evaluate long string option. If LOT is adequate to long string, drill to well total depth (12133' MD), run 7" 26.0~ L-80 BTCM casing to sudace and cement, and continue with step ~17. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 ~C 25.030 9. If LOT is inadequate to long string, drill to 7" intermediate casing point (11317' MD). 10. Run 7" 26.0~ L-80 BTCM casing to sudace and cement. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 ~C 25.030 11. Nipple up BOPE and test to 5000 psi. Record results. 12. Shut in BOP's and pressure test casing to 3000 psi for 30 minutes per AOGCC regulations. Record results. 13. Drill out cement and 20' of new hole. Pedorm formation integri~ test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 ~C 25.030 (0.5 ppg less than the FIT or LOT EMW). 14. Drill 6-1/8" hole to well total depth (+/- 12133' MD) according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH 15. Run open hole e-line or drill pipe conveyed logs as needed. 16. Run and cement 3-1/2" 9.3~ L-80 EUE8RD liner and Baker SAB-3 packer assembly. Set packer +/- 150' above intermediate casing shoe to provide appropriate liner lap. 17.. RIH with clean out BHA. Scrape casing. Displace well to completion brine. 18. Run and land 3-1/2" tubing with gas lift completion. 19. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. TAB, 07/7/00, vl 20. Freeze protect well. Set BPV. Re~ease rig and turn we~l over to production. TAB, 07/7/00, vl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la.~'ypeofwork: .... Drill ~lRedrill D I lbi'Type~f'well. Exploratory E] StratigraphicT~stJ-'J DevelopmentOil'r~l' ' Re-entry D Deepen D Service D Development Gas EJ single Zone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 35 feet 3.. Address 6. Property Designation C:~C> ,~,~,~"5 Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ~ ADL 28248 ALK 591 ,~ J'~, h Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 25.0251) 387' FNL, 419' FEL, Sec. 23, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 126' FNL, 1637' FWL, Sec. 30, T11N, R11 E, UM 1D-30 #U-630610 At total depth 9. Approximate spud date Amount 336' FNL, 1920' FWL, Sec. 30, T11N, R11 E, UM July 22, 2000 $200,000 12. Distance to nearest properly line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 126 @ Target feetI 1 D-38 119.8' @ 760' fee~ 2560 12133' MD / 6721 ' TVD , 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth: 450 MD Maximum hole angle 63° Maximum surface~ ~'t.~ p~lo~ At total depth (TVD) psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Couplin~ ' Length MD TVD MD TVD (include sta~e data) 20' i6' 62.5# R-3 Weld 85' 35' 35' 120' 120' 230 sx ASI 12.25" 9.625" 40# L-80 BTCM 6834' 35' 35' 6869' 4347' 780 ex AS III & 710 ax Class G 8.5" 7" 26# L-80 BTCM 12098' 35' 35' 12133' 6721' 250 ex Class G · · 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs(measured) true vertical feet ' Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production Liner dUL 14 2000 Perforation depth: measured Alaska 0il & Gas Cons. Commissi0r~ Anchorage true vertical . .. , 20. Attachments Filing fee r~ PropertyPlat r~ BoP Sketch [] Diverter Sketch [] Drilling program r'~ Drilling Vid program r~J Time vs depth plot DEe.action analysis r"! Seabed report D 2o AAC 2S.0S0 requirement~ I"i 21. I hereby c~r~ify that the foregoing i true ~nd correct to the bast of my knowledge Questions? Call Tom Brockway 263-,41~ " Signe~~ /l~r~~~ Title: D~llin~Eng,ne.~n~$up~tv. or "Date J. Tr,~n~ham · ' pnannrea hV ,cjhanSn AIl.~tm-r3r~ak~ Commission Use __ Permit Number APl number I Approv_.al date.,..~. oover letter / co ,-/ Z¥- - .5'- conditionsof approval Samples required ! I Yes ,~' No r-~ Yes .~r No Mud log required I--1 Ye. .o ..- ¥-- I--1 .o Required working pressure for BOPE D 2M: E] 3M; r"] 5~ D 1OM: r'l E] Other: Approved by Jr') Tnv~n~ ~=mn,~r~t .. commissioner the commission Da. te Form 10-401 Rev. 12/1/85 · Submit in triplicate DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS KRU 1 D-30 Drilling Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 8.5-10.2 16-26 25-50 100-200' 10-20 15-40 7-15 9.5-10 6-8% Drill out to TD 4-7 15-30 60-120 2-4 4-8 8-15 8.0-8.5 4-7% Drilling Fluid System - Nabors 16E 3 - Derrick Shale Shakers Desander Desilter Mud Cleaner Centrifuge Degasser Pit Level Indicator (w/visual and audible alarms) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 180-250 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Three possibilities exist for the possible maximum anticipated surface pressure (MASP) seen by the surface casing string along the 1D-30 well path. 1) MASP can be calculated using an expected leak-off of 13.7 ppg EMW (0.71 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2608 psi. The leak off EMW was chosen based on an open hole LOT on the closest offset well, 1D-11, taken to 13.7 ppg at 4414' TVD (0.71 psi/ft). MASP = (4347 ft)(0.71 -0.11) = 2608 psi ,JUL 1 4 2000 Gas Cons. Commission 2) If the well is drilled out of surface casing to TD as planned and surface shoe LOT is higher than expected, the MASP can be calculated based on a reservoir pressure of 3500 psi at 6543' TVD (0.54 psi/ft) and a gas gradient of 0.11 psi/ft. In this case, MASP would occur at 2813 psi. MASP = (6543 ft)(0.54 - 0.11) - 2813 psi 3) Some prior EBA and GSA wells in this area have experienced gas charged sands in the D-shale as a result of historic Gas Storage Area injection. The risk of encountering any gas charging in the 1D-30 target area is considered extremely Iow due to the fact that the target is located significantly down dip from any injector. This risk assessment is further supported by the fact that charged gas sands were not present in either of the closest offset wells, 1D-11 and 1 D-12, both drilled in late 1999. Therefore, as a result of MASP falling within a range of 2600 - 2800 psi, Phillips Alaska, Inc. will test the BOP equipment to 5000 psi prior to drilling out of surface casing. In the event that the well must be topset above the Kuparuk, the maximum anticipated pressure for the intermediate casing string can be calculated using the lesser of either the formation breakdown pressure or the pressure exerted by the reservoir at the surface. Formation breakdown is calculated using an expected leak-off of 14.3 ppg EMW (0.74 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a sudace pressure of 4012 psi. The leak off EMW was chosen based on an open hole LOT on the closest offset well, 1D-11, taken to 14.3 ppg at 6369' TVD (0.74 psi/ft). MASP = (6369 ft)(0.74 - 0.11) -- 4012 psi MASP exerted by the formation would remain at 2813 psi as calculated previously. Therefore, based on the 2800 - 4000 psi range of MASP, Phillips Alaska, Inc. will test the BOP equipment to 5000 psi prior to drilling out of intermediate casing. Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of the 1D-30 target location are expected to be 3500 psi (0.54 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.8 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 6543'. Well Proximity Risks: The nearest existing well to 1D-30 is 1D-38. As designed, the minimum distance between the two wells would be 119.8' at 760' MD. Drilling Area Risks: Risks in the 1D-30 drilling area include surface interval hydrates, lost circulation, and.potential borehole instability in and below the permafrost zone as well as through the intermediate shales. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of pipe, controlled drilling rates, and rheological properties which safely appropriate gas breakout. Lost circulation will be addressed with lost circulation material (LCM), reduced circulating rates, and reduced mud weights as needed. Shale instability will be controlled primarily with the planned fluid densities. Additional risk exists with unpredictable charging of the D-shale sands during historic gas injection. These gas pressure risks are mitigated with mid-HRZ LOT's and a top set option above the D- shale based upon those results. ,JUL 1 4 2000 Alaska 0il & Gas Cons. Commission Anch~r~e Annular Pumoina Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1D-30 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. At the end of drilling operations, a request for 1D-30 to be permitted for annular pumping of fluids occurring as a result of future drilling operations on 1D pad, per regulation 20 AAC 25.080, will be submitted. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 40 L-80 3 BTC 3,090 psi NA 5,750 psi 4,888 psi 7" 26 L-80 3 LTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi 3Y2"* 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi *ifneeded Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY July 10, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: Surface Location: Target Location: Bottom Hole Location: KRU 1D-30 387' FNL, 419' FEL, Sec 23, T11N, R10E, UM 126' FNL, 1637' FWL, Sec. 30, T11N, R11E, UM 336' FNL, 1920' FWL, Sec. 30, T11 N, R11 E, UM Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 1D Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of 1D pad. The well is designated as a conventional producer and is planned for a 9-5/8" surface casing string and a 7" production string to penetrate the Kuparuk sands. The well will be drilled and completed using Nabors 16E. Completion plans call for running a 3-1/2" gas lift production tubing string. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.O50. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. JUL 12 20CO Alaska Oil & Gas Cons. Commission Anchorage PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 8) 9) 10) 11) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. A description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f). Aisc note that Phillips does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. Please note that because of the large volume of regional information available in this area, Phillips considers this well to be a development well, and as such, no mudlogging operations such as type Icg generation and sample catching are planned. The following are the Phillips designated contacts for reporting responsibilities to the Commission: A) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs Bill Raatz, Geologist (20 AAC 25.071 ) 263-4952 Please note that the anticipated spud date for this well is July 22, 2000 If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or James Trantham at (907) 265-6434. Tohp°e?a~¢o nA~ BDrr~l~i nk;a~¢' ~"' ~"~'E n g i nee, ~ Attachments: cc: KRU 1D-30 Well File Randy Thomas ATO-1038 Tom Brockway ATO-1040 RECEIVED JUL 1 2" ¢ Alaska 0il & Gas Cons. Comrniss"en Anchorage KRU 1D-30 Produ( Proposed Completion Schematic Long String Base Case :LIP¢ PHII LIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY 16" 62.5# H-40 @ +/- 120' MD Depths are based on Nabors 16E RKB Surface csg. 9-5/8" 40.0# L-80 BTCM (+/- 6869' MD / 4347' TVD) Future Perforations Production csg. 7" 26.0# L-80 BTCM (+/- 12133' MD/6721' TVD) 3-1/2" FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Camco 'DS' nipple w/2.875" No-Go Profile. 3-1/2" x 6' L-80 pup installed above. 3-1/2" x 6' L-80 flow coupling installed below, EUE8RD set at +/- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple 3-1/2" x 1-1/2" Camco 'MMG' Mandrels w/DV's and RK latch's (Max. OD 5.968", ID 2.92"), 6' L-80 handling pups installed above and below on GLM. Spaced out w/ 3-1/2" 9.3# L-80 EUE8RD tubing as follows: GLM # TVD-RKB MD-RKB To Be Determined RECEIVED JUL Alaska 0il & Gas Cons. Commission Anchorage 3-1/2" x 1-1/2" Camco 'MMG' Mandrel w/shear valve and latch (Max. OD 5.968", ID 2.92"), pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling pups installed above and below. 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Camco 'W' nipple w/2.813" Selective Profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 7" x 3-1/2" Baker 'SAB-3' permanent packer w/KBH-22 seal assembly, 3-1/ 2" x 6' L-80 EUE8RD handling pup on top 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" x 10' L-80 EUE8RD pup joint 3-1/2" Camco 'D' nipple w/2.75" No-Go Profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below 3-1/2" x 10' L-80 EUE8RD pup joint 3-1/2" Baker shear out sub. Tubing tail +/- 80' above top of proposed perforations TAB, 7/9/00, vl KRU 1D-30 Produ( . Proposed Completion Schematic Topset Contingency Case PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 16" 62.5# H-40 @ +/- 120' MD Depths are based on Nabors 16E RKB Surface csg. 9-5/8" 40.0# L-80 BTCM (+/- 6869' MD / 4347' TVD) 3-1/2" FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Camco 'DS' nipple w/2.875" No-Go Profile. 3-1/2" x 6' L-80 pup installed above. 3-1/2" x 6' L-80 flow coupling installed below, EUESRD set at +/- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple 3-1/2" x 1-1/2" Camco 'MMG' Mandrels w/DV's and RK latch's (Max. OD 5.968", ID 2.92"), 6' L-80 handling pups installed above and below on GLM. Spaced out w/ 3-1/2" 9.3# L-80 EUE8RD tubing as follows: GLM # 'I'VD-RKB MD-RKB To Be Determined Intermediate csg. 7" 26.0# L-80 BTCM (+/- 11317' MD/6353' TVD) Future Perforations Production Liner 3-1/2" 9.3# L-80 EUE8RD (+/- 11317' MD / 6353' TVD) 3-1/2" x 1-1/2" Camco 'MMG' Mandrel w/shear valve and latch (Max. OD 5.968", ID 2.92"), pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling pups installed above and below. I jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Camco 'W' nipple w/2.813" Selective Profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 5.125" x 3" Baker Iocator 4.0" x 3.0" Baker 80-40 casing seal assembly w/12' stroke, 3-1/2" L-80 EUE8RD box up Liner Assembly (run on drillpipe), set @ +/- 11617' MD Baker 7"x 3-1/2" 'SLZXP' Liner Top Isolation Packer Baker 7" x 3-1/2" 'HMC' Hydraulic Liner Hanger Baker 17' Seal Bore Extension 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" x 10' L-80 EUE8RD pup joint 3-1/2" Camco 'D' nipple w/2.75" No-Go Profile. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below 3-1/2" 9.3# L-80 EUE8RD liner run to TD RECEIVED JUL 12 £0,; Aiaa(a 0ii & Gas Cons. Co~ Anchorage TAB, 7/9/00, vl 500 - 1000 - 1500 -~- 2000 ,,.1=- 2500 .=l,=,. n 3000 3500 4000 4500 I 5OOO 5500 6000 6500 7000 PHILLIPS Alaska, Inc. ICreotd Structure: Pad 1D Well : 30 by FOR: BROOKWAY I Dote plotted: 6-Jul-2000 Plot Reference is 30 Version 12. I Field : Kuparuk River Unit Location: North Slope, Alaska I Coord;notes ore in feet reference slot i~...xO.I True Vertical Deptrence est. Nobors 16E.I I SURFACE LOCATION: SFC. 23, 'r~N, R~0E ~ 8OO 0 8OO ~:~00 1800 ~400 3OOO 36OO 42OO 48OO 54OO 6OOO 88OO 72OO ?8OO I I I I I I I I I I I I I I I I I I I I I I I I I I I I I RKB ELEVATION: 106' KOP 0.75 3.00 Begin 5 Deg/100' Build g.00 15.00 DLS: 3.00 deg per 100 fL 21.00 EOC KOP Begin 3 Beg/lO0' Build ED~egin~' Build & Turn Bose of Permafrost EOC Begin Build & Turn 25.35 Bose of Permafrost 29.99 35.01 DLS: 3,00 deg per 100 ft 40.27 45.68 51.20 56.79 EOC Top West Sok 8890'(T0 TARGET) 124.34 AZIMUTH ***Plane of Proposal*** Base West Sak 9-5/8 Casing C80(KIO) Top West Sok C50 TARGET LOCATION: 126' FNL, 1657' FWL SEC. 30, T11N, R11E C40(K-5) TANGENT ANGLE 63.2 DEG RECEIVED' JUL 12. 20C) Alaska Oil & Gas Cons. Commission, Base West Sak 9-5/8 Casing C80(KlO) C50 C40(K-5) C20(HRZ midpoint) Bose HRZ Target-Top C4 C30(K-2) C20(HRZ Top Kuporuk D Target - Top C4 T° o.%2 Top C1 Top B Shale TD-Cas~ng Pt C30(K-2) K-1 Top Kuporuk D C3 C2 I i i i i i I i i i i i i i i i i i i ii i iI i i [ I i i i I i i i i i i 0 500 1000 1500 2000 2500 ;5000 5500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 go00 9500 VerticalSection (feeT)-> Azimuth 124..54 with reference 0.00 N, 0.00 E from slot #50 6OO 600 /,~ 1200 1800 0 (- 2400 ~ 3000 ~ I V 3600 4200 4800 5400 TD LOCATION: 336' FNL, 1920' FWL SEC. 30, T11N, R11E up C1 - Top B Shale TD-Caslng Pt ICreoted by rixse FOE: BROE, I~fAY Dote plotted: 6-Jul-2~ I Plot Reference ls Coordlnot~ ore ~n feet r~erence slot ~50. I True Vert;col ~t~er~ce Norm 16E.I ~ I PHILLIPS Alaska, Inc. Sfrucfure .' Pod 1D Well: 50 Field: Kuperuk River Unif Looeflon: Norlh Slope, Aleske RECEIVED JUL 12 20,:) Alaska Oi~ & Gas Cons. C0m~ Point KOP Begin 5 Deg/lO0' Build EOC Begin Build & Turn Bose of Permofrost EOC Top West Sek Bose West Sok 9-5/8 Cosing Pt C80(K10) C50 C40(K-5) C50(K-2) C20(HRZ midpoint) Bose HRZ K-1 Top Kuporuk D Terget - Top C4 Top C5 Top C2 Top C 1 Top B Shole TD-C(~sing Pt MD 450.00 600.00 1300.00 1600.00 1668.37 3126.95 5373.95 6425.09 6868.62 7518.80 9576.78 9955.59 1O722.89 11068.85 11517.22 11516.81 11707.55 11758.57 11851.72 11880.50 11911.55 11966.99 12153.32 PROFILE COMMENT DATA Inc Dir TVD North 0.00 0.00 450.00 0.00 2.25 90.00 599.96 0.00 25.25 go.o0 1278.89 0.00 25.25 go.o0 1554.52 0.00 24.67 95.65 1617.00 -0.91 65.20 126.65 2659.76 -429.69 65.20 126.63 5673.00 - 1 626.24 65.20 126.65 4147.00 -2186.00 65.20 126.65 4547.00 -2422.18 65.20 126.65 4550.00 -2661 .g 1 65.20 126.65 5478.00 -5757.80 65.20 126.65 5759.00 -4066.02 65.20 126.65 6085.00 -4474.62 65.20 126.65 6241.00 -4658.85 65.20 126.65 6555.00 -4791.11 65.20 126.65 6445.00 -4897.59 65.20 126.65 6529.00 -4998.95 65.20 126.65 6545.00 -5015.49 65.20 126.65 6585.00 -5065.08 6,3.20 126.65 6607.00 -5091.06 65.20 126.65 6621.00 -5107'60 63.20 126.65 6646.00 -5157.12 65.20 126.65 6721.00 -5225.69 Eost 0.00 2.94 156.57 274.99 502.75 1171.51 2781 .O5 3554.01 3851.71 4174.18 5648.52 6062.95 6612.55 6860.56 7058.27 7181.24 7517.85 7540.09 7406.81 7441.76 7464.00 7503.71 7622.85 V. Sect 0.00 2.43 129.27 227.05 250.46 1209.69 5213.68 4151.16 4546.72 4948.22 6785.65 7299.84 7984.1 6 8292.70 8514.21 8692.22 8862.51 8890.00 8973.07 9016.58 9044.27 9093.71 9242.05 Deg/lO0 0.00 1.50 3.00 0.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 PHILLIPS Alaska, Inc. Struoture: Pad 1 D Well: 30 Field: Kuparuk River Unit Looafion: North Slops, Alaska RECEIVED JUL 1 2 20~.~) Alaska Oil & Gas Cons. Commission 160 East (feet) -> 120 80 40 0 40 80 120 160 200 240 280 520 360 400 440 480 520 560 600 640 680 720 t I I I I I I I I I I I I I I I I I I I I I I I I I I t I I I I I I I I I 120 15OO 1700 4O ~ o (D (- 40 0 (~1 8o I 120 160 2OO 240 1900 2100 1500 / / / 700 ~ 2500 .~5..00__ 900 1100 1300 ~®_ ~ ...... _ _ _ ,500 0 1100 1300 1500-------- .-.- --. 1700 e~o 2°°_, 11oo ~5o_o. 9oo e 15~ 17OO ~ 500 1500 1100 31100 X 1300 1700 ~o~ e ~ ~oo oo ~ 1100 "- ~ ~ 1500 ---....,...,. ~ .,.,.. --. ~ 1500 1900 2700 500 .... 1700 '"-.. ~ '"'"'- ........,~ 2500 2500 '-- '..~1700 ~ 1900 2100 280 , , , , , , , , , ~o ~o ,0 o ,0 ~o ~o ,'~o ~& ~;,o ~o ~3o~o ,oo East (feet) -> i i I i i ! i 440 480 520 560 x ,,.2100 ~ i i i i I i 600 640 680 160 120 4O o 0 40 --i- 8O ~-~ 120 160 2OO 240 280 72O I v~ o~te~ ~y ,rx~ FOR: BROCI~AY Dote plotted: 6-Jul-2000 Plot R~f~e~ i. 30 V~n ~2. [ C~rdinates ore in fe~ refere~ slot ~. [ Tr~ Vertical ~pt~~~e e~, ~m 16[[ I PHILLIPS Alaska, Inc. Struature: Pad 10 Well: 50 Field: Kuparuk River Unit Looation: North Slope, Alaska RECEIVED JUL 12 2-0~~ ~ Alaska Oil & Gas Cons. Co~mis~n ~u-~orage ~'- 500 600 I 700 v East (feet) -> lOOO 11oo 400 500 600 700 800 goo lOOO 1 lOO 12oo 1500 1400 1500 1600 1700 18oo 1 goo 2000 21 aa 2200 2500 2400 ' ""- ~.90'0 ~ ~ 1700 "-. ~3oo~ ~ ....... 200 ~ ~ ~ '~ "' 3700 ~ ~.2100. .... ~'~ ------~ iOn. '., ~ ~uu °...2500 500 "'"' -.- ~ ~500 2900 \ \ 2700' ~. -., 2300 x 2900 400 \ x 31 O0 \ ~ 3300 \ ',. 2100 ~. 5500 \ \ x, 03900 4100 2500 \ \ '~ %2700 \ 2500 \ 2500 \ 2700 %' \ 11 O0 \ 3500 \ 2300 ~ %,,,2900 \ 2900 ZSO0 \ Z500 X 2700 \ .~ 800 \ \ \ 4100 \ \ 4300 F, DO 3500 \ \ \ \ 4500 ,~ !900 900 \ \ \ \ \ 4700 ',. 31 O0 \ \ \ ~900 ~ \ 510~0.~ \ 31 aa \ 'x 2500 \ \ \ 400 500 600 700 800 900 1000 1100 1200 1500 1400 1500 16D0 1700 1 BDO 1gDO 2000 2100 2200 2300 2400 East (feet) -> o lOO 200 50o 400 500 7oo 800 900 lOOO 11oo Cre. ted ~y r~x.e FOR: BItOCI~AY[ Dote plotiad: 6-Jul-2000 I Plot Refe, renc~ ie ~0 Ve~ion ~2. Tr ~ C~ t~p~ in PHILLIPS Alaska, Inc. Sfruofure: Pad 1D Well: 50 Field: Kuparuk River Unit Location: Norih Slope, Alaska RECEIVED JUL 1 2 206) Alaska Oil & Gas Cms. ComBission Anchorage East (feet) -> 600 800 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 800 / I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1000 4 \ 4700~ ~n~-"'X-...~ %. ~. '",. ~o_o.~~ 5900 ~ ~ 550o ' ~.~.. o~ \ 14oo \ \,, 3100 ~ ~,2900 '~ "...:',3700 2000 \ ~ \\\ $300 \ % 4100 2200 900 k 2400 N % 4~00 2600 X ~ 4500 2800 k 3500 ....o ,ioo'~ ~;o ' ' ' lOOO 12oo 14oo 2400 16oo 18oo 2000 2200 I V 2600 \ 3500 \ ~ 2800 ~ 4700 i i i i i i i i i i i i i i i i I i i i i 2400 2600 2800 3000 3200 3400 5600 3800 4000 4200 4400 4600 4800 5000 5200 5400 . East (feet) -> ICreoted by ,;xse FOR: BRO(~I~AYI Dote plotted: 6-Jul-2000 Pict Reference is ~0 Vemion ~2. C~ordinote~ ore in feet reference elot True Verticol Depths~rence e~t,Nobom ~ I PHILLIPS Alaska, Inc. Structure: Pad 1D Well: 50 Field: Kuparuk River Unit Location: North Slope, Alaska :iVED JUL 1 2 20C) Alaska Oil & Gas Cons, Oommission Anchorage 2000 2400 2800 5200 5600 t'- 4000 -4-- 0 ~ 4400 I v 4800 5200 5600 6000 6400 East (feet) -> 1600 2000 2400 2800 5200 .3600 4000 4400 4800 5200 5600 6000 6400 66130 7200 7600 8000 8400 8800 9200 9600 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ~ <~ 3100 ~ ~'~--~ 6300 \ %, \ % ~4100 ~00 ~, 3300 - \ % 4500 \ 'x 3500 -,, \\ \ \ ~ ~. 4500 3100 \ \ K 3500 %3500 ~ ,~ 4700 3500X \ \ \ 3700 \ '~ 4900 \~'~, ~, 5500X 3700 X x 5100 % 5900 X 570a . ~ 6~00 ~ ~ ~ k 6500 3900 ~ ~ 5500 , ~ 4500 ~ x ~ ~5900 ~ ~ 4100 'X N, 4500 % ~6100 ~ 4700 X N k k ~ ~6500 ~ 4900 ~ 4500 x 4700 ~ ~%6500 ~5100~ X k ~V900 ~00 ~ 5500 X4500 X~ 5100 5500 k N%5500 ~ 4700 i i i i i i i i i i i i i i i i i i i i I i i i i i i i i i i i i i i i i i i i i 1500 2000 2400 2800 3200 3600 4000 4400 4800 5200 5500 5000 5400 5800 7200 7~ 80~ 8400 8~0 9200 9500 East (feet) 2400 2800 32OO 3600 0 c ..-I- 4000 ~ .-I- 4400 ~ v 4800 5200 5600 6000 6400 PHILLIPS Alaska, Structure : Pad 1D Well : ;5 Field : Kuparuk River Unit Location : North Slope, Alaskal / ~500 ~2500 340 TRUE NORTH 350 0 10 2O RECEIVED JUL 12 AJaska Oil & Gas Cons. Commission Anchorage 3O 4O 5O 6O 29 7O 28O 8O 27O -t- 9O 26O 100 25O 1100 500 50o 70021 180 170 160 150 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well PHILLIPS Alaska, Inc. Pad 1D 30 slot #30 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 30 Version¢~2 Our ref : prop2089 License : Date printed : 6-Jul-2000 Date created : 23-Feb-1997 Last revised : 6-Jul-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 57.510,w149 30 31.123 Slot Grid coordinates are N 5959279.174, E 560671.083 Slot local coordinates are 387.00 S 419.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED Gas Cons, Commission PHILLIPS Alaska, Inc. Pad 1D,30 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref: 30 Version #2 Last revised : 6-Jul-2000 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 450.00 0.00 0.00 450.00 0.00 N 0.00 E 0.00 500.00 0.75 90.00 500.00 0.00 N 0.33 E 1.50 600.00 2.25 90.00 599.96 0.00 N 2.94 E 1,50 625.00 3.00 90.00 624.94 0.00 N 4.09 E 3.00 0.00 0.00 KOP 0.27 2.43 Begin 3 Deg/lO0' Build 3.38 725.00 6.00 90.00 724.62 0.00 N 11.93 E 3.00 825.00 9.00 90.00 823.75 0.00 N 24.99 E 3.00 925.00 12.00 90.00 922.06 0.00 N 43.21 E 3.00 1025.00 15.00 90.00 1019.29 0.00 N 66.55 E 3.00 1125.00 18.00 90.00 1115.16 0,00 N 94.95 E 3.00 9.85 20.63 35.67 54.95 78.39 1225.00 21.00 90.00 1209.41 0.00 N 128.32 E 3.00 1300.00 23.25 90.00 1278.89 0.00 N 156.57 E 3.00 1500.00 23.25 90.00 1462.64 0.00 N 235.52 E 0.00 1600.00 23.25 90.00 1554.52 0.00 N 274.99 E 0.00 1668.37 24.67 93.65 1617.00 0.91 S 302.73 E 3.00 105.95 129.27 EOC 194.46 227.05 Begin Build & Turn 250.46 Base of Permafrost 1700.00 25.35 95.21 1645.67 1.94 S 316.06 E 3.00 1800.00 27.61 99.64 1735.18 7.77 S 360.23 E 3.00 1900.00 29.99 103.44 1822.81 17.46 S 407.40 E 3.00 2000.00 32.46 106.72 1908.33 31.00 S 457.42 E 3.00 2100.00 35.01 109.58 1991.49 48.33 S 510.16 E 3,00 262.05 301.81 346.22 395.16 448.48 2200.00 37.61 112.09 2072.07 69.42 S 565.47 E 3.00 506.05 2300.00 40.27 114.32 2149.84 94.21 S 623.22 E 3.00 567.71 2400.00 42.96 116.31 2224.60 122.63 S 683.22 E 3.00 633.29 2500.00 45.68 118.12 2296.14 154.60 S 745.33 E 3.00 702.61 2600.00 48J43 119.76 2364.27 190.03 S 809.37 E 3.00 775.48 2700.00 51.20 121.27 2428.79 228.83 S 875.17 E 3.00 851.69 2800.00 53.99 122.66 2489.53 270.90 S 942.54 E 3.00 931.05 2900.00 56.79 123.96 2546.32 316.10 S 1011.31 E 3.00 1013.33 3000.00 59.61 125.18 2599.02 364.33 S 1081.27 E 3.00 1098.31 3100.00 62.43 126.33 2647.46 415.45 S 1152.25 E 3.00 1185.75 RECEIVED JUL 12 2¢¢) Alaska Of~ & Gas Cons. Commission 3126.93 63.20 126.63 2659.76 429.69 S 1171.51 E 3.00 1209.69 EOC 3500.00 63.20 126.63 2827.99 628.35 S 1438.75 E 0.00 1542.41 4000.00 63.20 126.63 3053.46 894.61 S 1796.90 E 0.00 1988.34 4500.00 63.20 126.63 3278.92 1160,86 S 2155.05 E 0.00 2434.26 5000.00 63.20 126.63 3504.39 1427.12 S 2513.21 E 0.00 2880.19 5373.93 63.20 126.63 3673.00 1626.24 S 2781.05 E 0.00 3213.68 Top West Sak 5500.00 63.20 126.63 3729.85 1693.38 S 2871.36 E 0.00 3326.11 6000.00 63.20 126.63 3955.31 1959.63 S 3229.51 E 0.00 3772.04 6425.09 63.20 126.63 4147.00 2186.00 S 3534.01 E 0.00 4151.16 Base West Sak 6500.00 63.20 126.63 4180.78 2225.89 S 3587.67 E 0.00 4217.97 6868.62 63.20 126.63 4347.00 2422.18 S 3851.71 E 0.00 4546.72 9-5/8" Casing Pt 7000.00 63.20 126.63 4406.24 2492.14 S 3945.82 E 0.00 4663.89 7318.80 63.20 126.63 4550.00 2661.91 S 4174.18 E 0.00 4948.22 C80(K10) 7500.00 63.20 126.63 4631.71 2758.40 S 4303.97 E 0.00 5109.82 8000.00 63,20 126.63 4857.17 3024.65 S 4662.13 E 0.00 5555.74 8500.00 63.20 126.63 5082.63 3290.91 S 5020.28 E 0.00 6001.67 9000.00 63.20 126.63 5308.10 3557.16 S 5378.43 E 0.00 6447.59 9376.78 63.20 126.63 5478.00 3757.80 S 5648.32 E 0.00 6783.63 C50 9500.00 63.20 126.63 5533.56 3823.42 S 5736.59 E 0.00 6893.52 9955.59 63.20 126.63 5739.00 4066.02 S 6062.93 E 0.00 7299.84 C40(K-5) All data is in feet unless otherwise stated. Coordinates from slot #30 and TVD from Nabors 16E (106.00 Ft above mean sea level). Bottom hole distance is 9242.06 on azimuth 124.43 degrees from wellhead. Total Dogleg for wellpath is 69.06 degrees. Vertical section is from wellhead on azimuth 124.34 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ PHILLIPS Alaska, Inc. Pad 1D.30 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 10000.00 63.20 126.63 5759.03 4089.68 S 6094.74 E 10500.00 63.20 126.63 5984.49 4355.93 S 6452.89 E 10722.89 63.20 126.63 6085.00 4474.62 S 6612.55 E 11000.00 63.20 126.63 6209.96 4622.19 S 6811.05 E 11068.85 63.20 126.63 6241.00 4658.85 S 6860.36 E 11317.22 63.20 126.63 6353.00 4791.11 S 7038.27 E 11500.00 63.20 126.63 6435.42 4888.44 S 7169.20 E 11516.81 63.20 126.63 6443.00 4897.39 S 7181.24 E 11707.53 63.20 126.63 6529.00 4998.95 S 7317.85 E 11738.57 63.20 126.63 6543.00 5015.49 S 7340.09 E 11831.72 63.20 126.63 6585.00 5065.08 S 7406.8! E 11880.50 63.20 126.63 6607.00 5091.06 S 7441.76 E 11911.55 63.20 126.63. 6621.00 5107.60 S 7464.00 E 11966.99 63.20 126.63 6646.00 5137.12 S 7503.71 E 12000.00 63.20 126.63 6660.88 5154.70 S 7527.35 E 12133.32 63.20 126.63 6721.00 5225.69 S 7622.85 E PROPOSAL LISTING Page 2 Your ref : 30 Version/K2 Last revised : 6-Jul-2000 Dogleg Vert Deg/lOOft Sect 0.00 7339.45 0.00 7785.37 0.00 7984.16 C30(K-2) 0.00 8231.30 0.00 8292.70 C20(HRZ midpoint) 0.00 8514.21 Base HRZ 0.00 8677.22 0.00 8692.22 K-1 0.00 8862.31 Top Kuparuk D 0.00 8890.00 Target-Top C4 0.00 8973.07 Top C3 0.00 9016.58 Top C2 0.00 9044.27 Top C1 0.00 9093.71 Top B Shale 0.00 9123.15 0.00 9242.05 TD-Casing Pt JUL 12 Oil & Gas Cons.,Commission ,Anchorage All data is in feet unless otherwise stated. Coordinates from slot#30 and TVD from Nabors 16E (106.00 Ft above mean sea level). Bottom hole distance is 9242.06 on azimuth 124.43 degrees from wellhead. Total Dogleg for wellpath is 69.06 degrees. Vertical section is from wellhead on azimuth 124.34 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ PHILLIPS Alaska, Inc. Pad 1D,30 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 30 Version/K2 Last revised : 6-Jul-2000 Comments in wellpath MD TVD Rectangular Coords. Comment 450 600 1300 1600 1668 3126 5373 6425 6868 7318 9376 9955 10722 11068 11317 11516 11707 11738 11831 11880 11911 11966 12133 O0 450.00 0.00 N 0.00 E KOP O0 599.96 0.00 N 2.94 E Begin 3 Deg/lO0' Build O0 1278.89 0.00 N 156.57 EEOC O0 1554.52 0.00 N 274.99 E Begin Build & Turn 37 1617.00 0.91S 302.73 E Base of Permafrost 93 2659.76 429.69 S 1171,51 EEOC 93 3673.00 1626.24 S 2781.05 E Top West Sak 09 4147.00 2186.00 S 3534.01 E Base West Sak 62 4347.00 2422.18 S 3851.71 E 9-5/8" Casing Pt 80 4550.00 2661.91S 4174.18 E C80(K10) 78 5478.00 3757.80 S 5648.32 E C50 59 5739.00 4066.02 S 6062.93 E C40(K-5) 89 6085.00 4474.62 S 6612,55 E C30(K-2) 85 6241.00 4658.85 S 6860.36 E C20(HRZ midpoint) 22 6353.00 4791.11 S 7038.27 E Base HRZ 81 6443.00 4897.39 S 7181.24 E K-1 .53 6529.00 4998.95 S 7317.85 E Top Kuparuk D .57 6543.00 5015.49 S 7340.09 E Target-Top C4 .72 6585.00 5065.08 S 7406.81E Top C3 .50 6607.00 5091.06 S 7441.76 E Top C2 .55 6621.00 5107.60 S 7464.00 E Top C1 .99 6646.00 5137.12 S 7503.71E Top B Shale .32 6721.00 5225.69 S 7622.85 E TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 6868.62 4347.00 2422.18S 385t..71E 9-5/8" Casing 0.00 0.00 O.OON O.OOE 12133.32 6721.00 5225.69S 762~.85E 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised Target-Top C4 568051.000,5954324.000,0.0000 6543.00 5015.49S 7340.09E 31-Mar-2000 PHILLIPS Alaska, Inc. Pad 1D.30 Kuparuk River Unit. North Slope, Alaska PROPOSAL Your Last revi Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 450.00 0.00 0.00 450.00 O.OON O.OOE 0.00 500.00 0.75 90.00 500.00 O.OON 0.33E 1.50 600.00 2.25 90.00 599.96 O.OON 2.94E 1.50 625.00 3.00 90.00 624.94 O.OON 4.09E 3.00 JUL LISTING Page 1 ref : 30 Version J~o,-,- .... sed 6-Jul- 2000m~d)~B k)l, & Gas Corl$. COF~F)liSB~OFI G.ID CO0 DS 725.00 6.00 90.00 724.62 O.OON 11.93E 3.00 825.00 9.00 90.00 823.75 O.OON 24.99E 3.00 925.00 12.00 90.00 922.06 O.OON 43.21E 3.00 1025.00 15.00 90.00 1019.29 O.OON 66.55E 3.00 1125.00 18.00 90.00 1115.16 O.OON 94.95E 3.00 1225.00 21.00 90.00 1209.41 O.OON 128.32E 3.00 1300.00 23.25 90.00 1278.89 O.OON 156.57E 3.00 1500.00 23.25 90.00 1462.64 O.OON 235.52E 0.00 1600.00 23.25 90.00 1554.52 O.OON 274.99E 0.00 1668.37 24.67 93.65 1617.00 0.91S 302.73E 3.00 1700.00 25.35 95.21 1645.67 1.94S 316.06E 3.00 1800.00 27.61 99.64 1735.18 7.77S 360.23E 3.00 1900.00 29.99 103.44 1822.81 17.46S 407.40E 3.00 2000.00 32.46 106.72 1908.33 31.00S 457.42E 3.00 2100.00 35.01 109.58 1991.49 48.33S 510.16E 3.00 2200.00 37.61 112.09 2072.07 69.42S 565.47E 3.00 2300.00 40.27 114.32 2149.84 94.21S 623.22E 3.00 2400.00 42.96 116.31 2224.60 122.63S 683.22E 3.00 2500.00 45.68 118.12 2296.14 154.60S 745.33E 3.00 2600.00 48.43 119.76 2364.27 190.03S 809.37E 3.00 2700.00 51.20 121.27 2428.79 228.83S 875.17E 3.00 2800.00 53.99 122.66 2489.53 270.90S 942.54E 3.00 2900.00 56.79 123.96 2546.32 316.10S 1011.31E 3.00 3000.00 59.61 125.18 2599.02 364.33S 1081.27E 3.00 3100.00 62.43 126.33 2647.46 415.45S 1152.25E 3.00 3126.93 63.20 126.63 2659.76 429.69S 1171.51E 3.00 3500.00 63.20 126.63 2827.99 628.35S 1438.75E 0.00 4000.00 63.20 126.63 3053.46 894.61S 1796.90E 0.00 4500.00 63.20 126.63 3278.92 1160.86S 2155.05E 0.00 5000.00 63.20 126.63 3504.39 1427.12S 2513.21E 0.00 5373.93 63.20 126.63 3673.00 1626.24S 2781.05E 0.00 5500.00 63.20 126.63 3729.85 1693.38S 2871.36E 0.00 6000.00 63.20 126.63 3955.31 1959.63S 3229.51E 0.00 6425.09 63.20 126.63 4147.00 2186.00S 3534.01E 0.00 6500.00 63.20 126.63 4180.78 2225.89S 3587.67E 0.00 6868.62 63.20 126.63 4347.00 2422.18S 3851.71E 0.00 7000.00 63.20 126.63 4406.24 2492.14S 3945.82E 0.00 7318.80 63.20 126.63 4550.00 2661.91S 4174.18E 0.00 7500.00 63.20 126.63 4631.71 2758.40S 4303.97E 0.00 8000.00 63.20 126.63 4857.17 3024.65S 4662.13E 0.00 8500.00 63.20 126.63 5082.63 3290.91S 5020.28E 0.00 9000.00 63.20 126.63 5308.10 3557.16S 5378.43E 0.00 9376.78 63.20 126.63 5478.00 3757.80S 5648.32E 0.00 9500.00 63.20 126.63 5533.56 3823.42S 5736.59E 0.00 9955.59 63.20 126.63 5739.00 4066.02S 6062.93E 0.00 Easting Northing 0.00 560671.08 5959279.17 0.00 560671.08 5959279.17 0.27 560671.41 5959279.18 2.43 560674.03 5959279.20 3.38 560675.17 5959279.21 9.85 560683.02 5959279.27 20.63 560696.07 5959279.38 35.67 560714.29 5959279.53 54.95 560737.62 5959279.71 78.39 560766.02 5959279.95 105.95 560799.39 5959280.22 129.27 560827.63 5959280.45 194.46 560906.57 5959281.09 227.05 560946.04 5959281.41 250.46 560973.78 5959280.73 262.05 560987.12 5959279.80 301.81 561031.33 5959274.33 346.22 561078.57 5959265.02 395.16 561128.69 5959251.90 448.48 561181.57 5959235.00 506.05 561237.05 5959214.36 567.71 561294.98 5959190.04 633.29 561355.21 5959162.11 702.61 561417.58 5959130.65 775.48 561481.90 5959095.74 851.69 561548.00 5959057.48 931.05 561615.71 5959015.98 1013.33 561684.83 5958971.33 1098.31 561755.18 5958923.68 1185.75 561826.56 5958873.15 1209.69 561845.94 5958859.06 1542.41 562114.75 5958662.60 1988.34 562475.02 5958399.29 2434.26 562835.29 5958135.98 2880.19 563195.57 5957872.67 3213.68 563465.00 5957675.75 3326.11 563555.84 5957609,36 3772.04' 563916.11 5957346.05 4151.16 564222.41 5957122.1'9 4217.97 564276.38 5957082.74 4546.72 564541.99. 5956888.61 4663.89 564636.65 5956819.43 4948.22 564866.36 5956651.54 5109.82 564996.92 5956556.12 5555.74 565357.20 5956292.81 6001.67 565717.47 5956029.50 6447.59 566077.74,5955766.19 6783.63 566349.23 5955567.77 6893.52 566438.01 5955502.88 7299.84 566766.28 5955262.96 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot#30 and TVD from Nabors 16E (106.00 Ft above mean sea level). Bottom hole distance is 9242.06 on azimuth 124.43 degrees from wellhead. Total Dogleg for wellpath is 69.06 degrees. Vertical section is from wellhead on azimuth 124.34 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ PHILLIPS Alaska, Inc. Pad 1D,30 Kuparuk River Unit,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G Depth Degrees Degrees Depth C 0 0 R D I N 10000.00 63.20 126.63 5759.03 4089.68S 10500.00 63.20 126.63 5984.49 4355.93S 10722.89 63.20 126.63 6085.00 4474.62S 11000.00 63.20 126.63 6209.96 4622.19S 11068.85 63.20 126.63 6241.00 4658.85S 11317.22 63.20 126.63 6353.00 4791.11S 11500.00 63.20 126.63 6435.42 4888.44S 11516.81 63.20 126.63 6443.00 4897.39S 11707.53 63.20 126.63 6529.00 4998.95S 11738.57 63.20 126.63 6543.00 5015.49S 11831.72 63.20 126.63 6585.00 5065.08S 11880.50 63.20 126.63 6607.00 5091.06S 11911.55 63.20 126.63 6621.00 5107.60S 11966.99 63.20 126.63 6646.00 5137.12S 12000.00 63.20 126.63 6660.88 5154.70S 12133.32 63.20 126.63 6721.00 5225.69S PROPOSAL LISTING Page 2 Your ref: 30 Version#2 Last revised : 6-Jul-2000 U LA R Dogleg Vert G R I D C 0 0 R D S A T E S Deg/lOOft Sect Easting Northing 6094.74E 0.00 7339.45 566798.28 5955239.57 6452.89E 0.00 7785.37 567158.55 5954976.26 6612.55E 0.00 7984.16 567319.16 5954858.88 6811.05E 0.00 8231.30 567518.83 5954712.95 6860.36E 0.00 8292.70 567568.43 5954676.69 7038.27E 0.00 8514.21 567747.40 5954545.89 7169.20E 0.00 8677.22 567879.10 5954449.64 7181.24E 0.00 8692.22 567891.21 5954440.79 7317.85E 0.00 8862.31 568028.63 5954340.35 7340.09E 0.00 8890.00 568051.00 5954324.00 7406.81E 0.00 8973.07 568118.11 5954274.95 7441.76E 0.00 9016.58 568153.27 5954249.26 7464.00E 0.00 9044.27 568175.64 5954232.91 7503.71E 0.00 9093.71 568215.58 5954203.71 7527.35E 0.00 9123.15 568239.37 5954186.33 7622.85E 0.00 9242.05 568335.43 5954116.12 RECEIVED JUL 12 Atasks 0~t & Gas C~s. ~mmJ~n ~chor~e All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot#30 and TVD from Nabors 16E (106.00 Ft above mean sea level). Bottom hole distance is 9242.06 on azimuth 124.43 degrees from wellhead. Total Dogleg for wellpath is 69.06 degrees. Vertical section is from wellhead on azimuth 124.34 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ PHILLIPS Alaska. Inc. Pad 1D.30 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 30 Version#2 Last revised : 6-Jul-2000 Comments in wellpath MD TVD Rectangular Coords. Comment 450.00 450.00 O.OON O.OOE KOP 600.00 599.96 O.OON 2.94E Begin 3 Deg/lO0' Build 1300.00 1278.89 O.OON 156.57E EOC 1600.00 1554.52 O.OON 274.99E Begin Build & Turn 1668.37 1617.00 0.91S 302.73E Base of Permafrost 3126.93 2659.76 429.69S 1171.51E EOC 5373.93 3673.00 1626.24S 2781.05E Top West Sak 6425.09 4147.00 2186.00S 3534.01E Base West Sak 6868.62 4347.00 2422.18S 3851.71E 9-5/8" Casing Pt 7318.80 4550.00 2661.91S 4174.18E C80(K10) 9376.78 5478.00 3757.80S 5648.32E C50 9955.59 5739.00 4066.02S 6062.93E C40(K-5) 10722.89 6085.00 4474.62S 6612.55E C30(K-2) 11068.85 6241.00 4658.85S 6860.36E C20(HRZ midpoint) 11317.22 6353.00 4791.11S 7038.27E Base HRZ 11516.81 6443.00 4897.39S 7181.24E K-1 11707.53 6529.00 4998.95S 7317.85E Top Kuparuk D 11738.57 6543.00 5015.49S 7340.09E Target-Top C4 11831.72 6585.00 5065.08S 7406.81E Top C3 11880.50 6607.00 5091.06S 7441.76E Top C2 11911.55 6621.00 5107.60S 7464.00E Top C1 11966.99 6646.00 5137.12S 7503.71E Top B Shale 12133.32 6721.00 5225.69S 7622.85E TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 6868.62 4347.00 2422.18S 385t.71E 9-5/8" Casing 0.00 0.00 O.OON O.OOE 12133.32 6721.00 5225.69S 7622.85E 7" Casing Targets associated with this wellpath ................... Target name Geographic Location T.V.D. Rectangular Coordinates Revised Target-Top C4 568051.000,5954324.000,0.0000 6543.00 5015.49S 7340.09E 31-Mar-2000 RECEIVED JUL 12 Oi~ & Gas Cons, Commission Anchor~e JUL Alaska ~ ~ Gas Cons. ¢ommi~ion PHILLIPS Alaska, Inc, A~qollOfSt~8 Pad 1D,30 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 30 VersionS2 Last revised : 6-Jul-2000 Measured Inclin, Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi, 0.00 0.00 0.00 0,00 0.00 N 0.00 E 0.00 0.00 0.00 0,00 N/A 450,00 0.00 0,00 450,00 0,00 N 0,00 E 0.00 1.17 1.17 0.68 N/A 500.00 0.75 90,00 500,00 0,00 N 0.33 E 0.27 1,31 1,31 0,75 N/A 600,00 2,25 90,00 599,96 0,00 N 2.94 E 2,43 1,57 1,57 0,90 N/A 625,00 3.00 90,00 624,94 0,00 N 4,09 E 3.38 1.64 1,63 0.94 90,00 725,00 6,00 90,00 724,62 0,00 N 11,93 E 9,85 1,98 1,90 1,09 90,00 825.00 9,00 90.00 823,75 0,00 N 24,99 E 20.63 2,45 2.18 1.24 90,00 925.00 12.00 90.00 922.06 0.00 N 43,21E 35.67 3,12 2,47 1,40 90,00 1025.00 15,00 90.00 1019,29 0.00 N 66,55 E 54,95 4,05 2.79 1.56 90,00 1125,00 18,00 90,00 1115,16 0,00 N 94,95 E 78,39 5,27 3,14 1,73 90,00 1225,00 21.00 90.00 1209,41 0,00 N 128,32 E 105.95 6,82 3,51 1,92 90,00' 1300,00 23,25 90,00 1278,89 0,00 N 156,57 E 129,27 8,19 3,81 2,07 90,00 1500,00 23,25 90,00 1462,64 0,00 N 235,52 E 194,46 11,94 4,63 2,50 90,00 1600,00 23,25 90,00 1554,52 0,00 N 274,99 E 227,05 13,85 5,05 2,72 90,00 1668.37 24.67 93,65 1617,00 0,91 S 302.73 E 250,46 15.32 5.35 2.88 90,50 1700,00 25,35 95,21 1645,67 1.94 S 316,06 E 262,05 16,00 5,49 2,95 90,74 1800,00 27.61 99,64 1735,18 7,77 S 360,23 E 301,81 18,39 5,95 3.21 91,96 1900,00 29.99 103,44 1822,81 17,46 S 407.40 E 346.22 21,04 6.42 3.49 93,49 2000,00 32,46 106,72 1908,33 31,00 S 457,42 E 395,16 23,96 6,91 3.81 95.21 2100,00 35,01 109,58 1991,49 48,33 S 510,16 E 448,48 27,18 7,42 4,16 97,01 2200,00 37,61 112.09 2072,07 69,42 S 565,47 E 506,05 30,70 7,94 4,55 98,84 2300,00 40,27 114,32 2149,84 94,21 S 623,22 E 567,71 34,52 8,47 4,98 100,66 2400,00 42,96 116,31 2224,60 122,63 S 683,22 E 633,29 38,65 9,01 5,46 102,44 2500,00 45,68 118,12 2296,14 154,60 S 745,33 E 702,61 43,09 9,55 5,98 104,15 2600,00 48.43 119,76 2364,27 190,03 S 809,37 E 775,48 47,84 10,09 6,56 105,78 2700.00 51,20 121,27 2428,79 228,83 S 875,17 E 851,69 52,89 10,62 7,19 107,34 2800,00 53,99 122,66 2489,53 270,90 S 942,54 E 931,05 58,22 11,15 · 7,87 108,82 2900,00 56,79 123.96 2546,32 316,10 S 1011.31 E 1013.33 63.82 11.66 ~'8,60 110,22 3000,00 59,61 125,18 2599,02 364,33 S 1081,27 E 1098,31 69,68 12,16 9,37 111,54 3100,00 62,43 126,33 2647,46 415,45 S 1152,25 E 1185,75 75,76 12,63 10.20 112,78 3126.93 63,20 126,63 2659,76 429.69 S 1171,51E 1209,69 77.42 12,75 10,43 113.09 3500,00 63.20 126,63 2827,99 628,35 S 1438,75 E 1542.41 100,62 14,47 13,59 116,32 4000,00 63,20 126,63 3053,46 894,61 S 1796,90 E 1988,34 132,08 16,74 17.88 118,83 4500.00 63.20 126,63 3278,92 1160,86 S 2155,05 E 2434.26 163.75 19,00 22,19 120,36 5000,00 63,20 126.63 3504,39 1427,12 S 2513,21E 2880.19 195.51 21.26 26,51 121,40 5373,93 63,20 126.63 3673,00 1626,24 S 2781,05 E 3213,68 219,31 22,94 29,74 121,95 5500,00 63,20 126,63 3729,85 1693,38 S 2871.36 E 3326,11 227,34 23,51 30,83 122.14 6000,00 63,20 126,63 3955,31 1959.63 S 3229,51E 3772.04 259.20 25,78 35,16 122,69 6425,09 63,20 126,63 4147,00 2186,00 S 3534,01E 4151,16 286,31 27,70 38,85 123,06 6500,00 63,20 126,63 4180,78 2225,89 S 3587,67 E 4217,97 291,09 28,04 39,50 123,13 6868,62 63,20 126,63 4347,00 2422,18 S 3851.71 E 4546.72 314,61 29,71 42.69 123.38 7000,00 63.20 126,63 4406,24 2492,14 S 3945,82 E 4663,89 323,00 30,31 43,83 123,48. 7318,80 63,20 126,63 4550,00 2661,91 S 4174,18 E 4948,22 343,35 31.76 46,60 123,66 7500.00 63,20 126.63 4631,71 2758.40 S 4303,97 E 5109,82 354:92 32,58 48,17 123,76 8000,00 63,20 126,63 4857,17 3024,65 S 4662,13 E 5555,74 386,84 34,85 52,51 124.00 8500,00 63,20 126,63 5082,63 3290,91 S 5020,28 E 6001,67 418,78 37,12 56,85 124,20 9000.00 63,20 126.63 5308,10 3557,16 S 5378,43 E 6447.59 450,72 39,40 61,19 124,37 9376,78 63,20 126,63 5478,00 3757,80 S 5648.32 E 6783,63 474,79 41,11 64,46 124.49 9500,00 63,20 126,63 5533,56 3823,42 S 5736,59 E 6893,52 482,67 41,67 65,52 124,52 9955,59 63,20 126,63 5739,00 4066,02 S 6062,93 E 7299,84 511,78 43,75 69.48 124,64 All data is in feet unless otherwise stated, Coordinates from slot #30 and TVD from Nabors 16E (106,00 Ft above mean sea level), Bottom hole distance is 9242.06 on azimuth 124,43 degrees from wellhead. Vertical section is from wellhead on azimuth 124,34 degrees. Calculation uses the minimum curvature method, Presented by Baker Hughes INTEQ PHILLIPS Alaska, Inc. Pad 1D,30 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G Depth Degrees Degrees Depth C 0 0 R D I N ULAR ATES PROPOSAL LISTING Page 2 Your ref : 30 Version#2 Last revised : 6-Jul-2000 Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 10000.00 63.20 126.63 5759.03 4089.68 S 6094.74 E 7339.45 514.62 43.95 69.87 124.65 10500.00 63.20 126.63 5984.49 4355.93 S 6452.89 E 7785.37 546.57 46.23 74.21 124.77 10722.89 63.20 126.63 6085.00 4474.62 S 6612.55 E 7984.16 560.82 47.24 76.14 124.82 11000.00 63.20 126.63 6209.96 4622.19 S 6811.05 E 8231.30 578.53 48.50 78.55 124.87 11068.85 63.20 126.63 6241.00 4658.85 S 6860.36 E 8292.70 582.93 48.82 79.14 124.89 11317.22 63.20 126.63 6353.00 4791.11 S 7038.27 E 8514.21 598.80 49.95 81.30 124.93 11500.00 63.20 126.63 6435.42 4888.44 S 7169.20 E 8677.22 610.48 50.78 82.89 124.97 11516.81 63.20 126.63 6443.00 4897.39 S 7181.24 E 8692.22 611.56 50.86 83.03 124.97 11707.53 63.20 126.63 6529.00 4998.95 S 7317.85 E 8862.31 623.75 51.73 84.69 125.00 11738.57 63.20 126.63 6543.00 5015.49 S 7340.09 E 8890.00 625.73 51.87 84.96 125.01 11831.72 63.20 126.63 6585.00 5065.08 S 7406.81 E 8973.07 631.69 52.30 85.77 125.02 11880.50 63.20 126.63 6607.00 5091.06 S 7441.76 E 9016.58 634.81 52.52 86.19 125.03 11911.55 63.20 126.63 6621.00 5107.60 S 7464.00 E 9044.27 636.79 52.66 86.46 125.03 11966.99 63.20 126.63 6646.00 5137.12 S 7503.71E 9093.71 640.33 52.91 86.94 125.04 12000.00 63.20 126.63 6660.88 5154.70 S 7527.35 E 9123.15 642.44 53.06 87.23 125.05 12133.32 63.20 126.63 6721.00 5225.69 S 7622.85 E 9242.05 650.97 53.67 88.39 125.07 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 12133 ARCO (H.A. Mag) User specified 650.97 53:67 88.39 1. Ellipse dimensions are half axis. ~ 2. Casing dimensions are not included. 3. E11 ipses are cal cul ated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. RECE, \. ED JUL 12 £0C) Alaska Oii& Gas Cons, Commission Anchorage All data is in feet unless otherwise stated. Coordinates from slot#30 and TVD from Nabors 16E (106.00 Ft above mean sea level). Bottom hole distance is 9242.06 on azimuth 124.43 degrees from wellhead. Vertical section is from wellhead on azimuth 124.34 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ PHILLIPS Alaska. Inc. Pad 1D,30 Kuparuk River Unit,North Slope. Alaska PROPOSAL LISTING Page 3 Your ref : 30 Version#2 Last revised: 6-Jul-2000 Comments i n wel 1 path MD TVD Rectangul ar Coords. Con~nent ....... ....... ........................................................... 600.00 599.96 0.00 N 2.94 E Begin 3 Deg/lO0' Build 1300.00 1278.89 0.00 N 156.57 EEOC 1600.00 1554.52 0.00 N 274.99 E Begin Build & Turn 1668.37 1617.00 0.91 S 302.73 E Base of Permafrost 3126.93 2659.76 429.69 S 1171.51 E EOC 5373.93 3673.00 1626.24 S 2781.05 E Top West Sak 6425.09 4147.00 2186.00 S 3534.01 E Base West Sak 6868.62 4347.00 2422.18 S 3851.71 E 9-5/8" Casing Pt 7318.80 4550.00 2661.91S 4174.18 E C80(K10) 9376.78 5478.00 3757.80 S 5648.32 E C50 9955.59 5739.00 4066.02 S 6062.93 E C40(K-5) 10722.89 6085.00 4474.62 S 6612.55 E C30(K-2) 11068.85 6241.00 4658.85 S 6860.36 E C20(HRZ midpoint) 11317.22 6353.00 4791.11 S 7038.27 E Base HRZ 11516.81 6443.00 4897.39 S 7181.24 E K-1 11707.53 6529.00 4998.95 S 7317.85 E Top Kuparuk D 11738.57 6543.00 5015.49 S 7340.09 E Target-Top C4 11831.72 6585.00 5065.08 S 7406.81 E Top C3 11880.50 6607.00 5091.06 S 7441.76 E Top C2 11911.55 6621.00 5107.60 S 7464.00 E Top Cl 11966.99 6646.00 5137.12 S 7503.71 E Top B Shale 12133.32 6721.00 5225.69 S 7622.85 E TD-Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 6868.62 4347.00 2422.18S 3851.71E 9-5/8" Casing 0.00 0.00 O.OON O.OOE 12133.32 6721.00 5225.69S 7622.85E 7" Casing Targets associated with this wellpath Target name Geographi c Location T.V.D. Rectangul ar Coordinates Revised PHILLIPS Alaska, Inc. Pad 1D 30 slot #30 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 30 Version #2 Our ref : prop2089 License : Date printed : 6-Jul-2000 Date created : 23-Feb-1997 Last revised : 5-Jul-2000 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is n70 17 57.510,w149 30 31.123 Slot Grid coordinates are N 5959279.174, E 560671.083 Slot local coordinates are 387.00 S 419.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <5155'- 5905'>,,l10A, Pad ID PMSS <0-4590'>,,l18,Pad ID 139 <PMSS 515 - 4838'>,,139,Pad 1D PGMS <0-8930'>,,5,Pad 1D PMSS <0-5126'>,,106,Pad 1D PMSS <381-6092'>,,105,Pad 1D PGMS <0-9783'>,,2,Pad iD PMSS <0-5015'>,,135,Pad 1D PMSS <1957-5265'>,,133,Pad 1D PMSS <467 - 5802'>,,132,Pad 1D PMSS <0 - 6472'>,,131,Pad iD PMSS <0-4778'>,,130, Pad iD PMSS <0-4414'>,,121,Pad iD MSS <3311-8200'>,,7,Pad 1D PMSS <0-11234'>,,Il,Pad ID PMSS <0-5462'>,,129, Pad ID PMSS <0-4515'>,,l19, Pad 1D PGMS <0-8070'>,,3,Pad 1D PMSS <0-4530'>,,120,Pad 1D PMSS <0 - 6716'>,,126, Pad 1U PMSS <0 - 7432'>,,127,Pad ID PMSS <0 - 6580'>,,128,Pad iD PMSS <0 - 5445'>,,122,Pad 1D GSS <0-173'>,,123, Pad 1D PMSS <287-6055'>,,123,Pad ID GSS <0-175'>,,l16, Pad iD PMSS <290-6245'>,,l16, Pad 1D PMSS <0-5047'>,,124,Pad ID PMSS <291 - 5795'>,,125, Pad ID PGMS <0-8365'>,,1,Pad 1D PMSS <0 - 7150'>,,108,Pad iD PMSS <0-4850'>,,109, Pad 1D PMSS<0-7045'>,,lll,Pad 1D PMSS <0-9250'>,,12,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance 17-May-2000 465.9 2-Jun-1998 332.0 18-May-2000 329.0 13-Nov-1997 229.9 2-Jun-1998 521.6 2-Jun-1998 549.1 4-Aug-1992 535.6 2-J6n-1998 142.2 2-Jun-1998 192.0 6-Aug-1998 187.5 23-Ju1-1998 184.2 2-Jun-1998 180.8 2-Jun-1998 272.9 6-Nov-1997 205.8 30-Dec-1999 239.5 2-Jun-1998 180.8 2-Jun-1998 295.4 13-Aug-1998 424.9 2-Jun-1998 284.4 1-Ju1-1998 199.5 6-Ju1-1998 193.5 17-Aug-1998 188.5 29-Aug-1998 261.8 4-Sep-1998 250.7 13-Sep-1998 250.0 8-Sep-1998 358.3 17-Sep-1998 358.3 2-Jun-1998 214.1 19-Aug-1998 206.4 10-Dec-1997 649.2 28-Oct-1998 493.8 2-Jun-1998 479.8 3-Sep-1998 452.1 21-Jan-2000 629.7 M.D. 100.0 440.0 160.0 475.0 100.0 320.0 450.0 2877.8 100.0 100.0 100 0 475 0 100 0 450 0 4040 0 220 0 420 0 0.0 100.0 100.0 100.0 100.0 100.0 160.0 260.0 100.0 100.0 300.0 100.0 487.5 100.0 100.0 100.0 600.0 Diverging from M.D. 100.0 440.0 160.0 2280.0 100.0 320.0 450.0 2877.8 100.0 100.0 100.0 475.0 100.0 450.0 4040.0 220.0 420.0 380.0 100.0 100.0 100.0 100.0 100.0 160.0 260.0 100.0 10500.0 300.0 100.0 487.5 100.0 100.0 100.0 600.0 PMSS <0-8702'>,,14,Pad 1D 6-0ct-1999 PMSS <556-7024'>,,9, Pad 1D 29-Apr-1998 PMSS <294 - 8250'>,,l12,Pad 1D 21-Sep-1998 PMSS <293 - 6866'>,,l13, Pad 1D 22-Sep-1998 PMSS <0 - 6270'>,,l14,Pad 1D 2-Sep-1998 PMSS <0-5142'>,,l15,Pad 1D 2-Jun-1998 PGMS <0-8850'> 28-May-81,,MP 1 17-II-ii,Pad 1D 23-Apr-1999 ?MSS <4674'-5639'>,,125A, Pad ID PMSS <0-5205'>,,117,Pad ID PMSS <256 - 5973'>,,l10, Pad 1D PMSS <0 - 7340'>,,10, Pad 1D PGMS <0 - 6400'>,,WS-8,Pad 1D PGMS <0-7502'>,,4,?ad 1D PMSS <377 - 6224'>,,134,Pad 1D ?MSS <0-1288'>,, 138PB1, Pad 1D PMSS <0-6543'>,,138, Pad ID 136 PMSS <519 - 5680'>,,136, Pad 1D 137 PMSS <0 - 5615'>,,137,Pad 1D PGMS <0-8610'>,,6, Pad 1D PMSS <0-7378'> Sperry,,102,Pad 1D L1 PMSS <4338-7400'> Sperry,,102L1,Pad 1D PMSS <0-???'>,,38,Pad 1D 24-Apr-2000 2-Jun-1998 24-Apr-2000 28-Apr-1998 27-Apr-2000 4-Aug-1992 3-Aug-1998 18-May-2000 18-May-2000 5-Jun-2000 2-Jun-2000 13-Nov-1997 26-Jun-2000 27-Jun-2000 5-Jul-2000 621.4 100.0 308.3 100.0 411.1 100.0 398.0 100.0 384.1 487.5 371 4 160.0 5584 2 7940.0 206 4 100.0 345 4 100.0 465 9 100.0 237 3 780.0 281 3 487.5 319 9 475.0 219 5 280.0 316 6 20.0 316 6 20.0 292 3 360.0 304 9 200.0 183.4 180.0 584.9 691.7 584.9 691.7 119.8 760.0 100 100 100 100 487 160 7940 100 360 100 2680 487 475 280 20 6400 4820 200 180 2533 4040 760 R ,Cb, VEQ JUL 1 2 200~ & G~s C~s. Comrnmmo AiaskaOil '"'"' ' 'n ~chorage LEAK OFF TEST PROCEDURE Kuparuk River Unit (KRU) Operations . After cementing casing and nippling up BOPE, RIH to top of cement and pressure test the casing to 2000 psi for 30 minutes and record on chart (AOGCC required casing integrity test). Record the information on the AAI LOT form (you can locate on the drilling web page). Plot Casing Pressure Test (volume vs. pressure and time holding pressure on casing). Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. 2. Drill 20' of new hole below the casing shoe. , Circulate the hole to establish a uniform mud density throughout the system (required for a good FIT or LOT). PU into the shoe. 4. Close the blowout preventer (ram or annular). 5. Pump down the drill stem at 1/4 to 1/2 bpm. , On the LOT form, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. Note: If 16.0 ppg EMW is reached, shut down and hold the pressure there. This becomes the data for a formation integrity test (FIT) instead of a LOT 7. At leak off pump 3 bbls of mud into formation prior to shutting down the pump. Shut down when the leak-off point is clearly seen and 3 bbls of mud has been pumped into the formation. Record initial shut-in pressure. With the pump shut down monitor, record and report the shut -in pressures for a minimum of 10 minutes or until the shut -in pressure stabilizes. Record time vs. pressure in 1-minute intervals and plot information. Bleed the pressure off and record the fluid volume recovered. Forward the data to the Drilling Engineer in Anchorage. The Drilling Engineer will forward the information to the Agencies. RECEIVED JUL 1 2 2000 AJaska Oit & Gas Cons. Commission Ar~chorage TAB, 7/7/00 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Diverter Schematic Nabors 16E Flowline 21 W' 2,000 psi WP DRILLING SPOOL w/16" Outlet 21W' HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) RECE .... ~V~D JUL 12 2OOO Alaska Oi~ & Gas Co~s. Commission Anch0r~e PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Nabors #16E 13-5/8" 5,000 PSI BOP COMPONENTS I I 3" 5,000 psi WP OCT MANUAL GATE n--J KILL LINE ~ 3" 5,000 psi WP Shaffer GATE VALVE ] w/hydraulic actuator ~ / J / DSA 13-5/8" 5,000 psi WP -"~L x 11" 3,000 psi WP '~ 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple I~£v] D^~E I eYI a< I APPI ~' DESCRIPTION I No s' 11. COORDINA ~S ~0~ ARE A.S.P. zONE 4, N.A.D. 27. ELEVATIONS ~0~ ARE BRITI~ PETROLEUM MEAN SEA LEAL. ALL DISbANdS SHO~ ARE ~UE. 2. ~O~APH/C COORDINA~S ARE NAD 2~ I 9ASIS ~ LO~TI~S ~D ELEVA UONS ARE D.S I-D M~UMEM~ PER LHD AND ASSOC/A ~ 4. C~DUCT~S ARE LO~D W/~IN P~AC~D SECTI~ ~, TO~/P ~I N~, RAN~ ~ EAST, U.~. ~. DA~S ~ SUR~' 6/~6/~ ~B. L~-19 Pp 7~-Z2, ond Pp ~-2. 6 AMD Pp~ ~7-~8. 6. DRILL SI ~ 1-D ~ID N~ IS ROTA ~D ~' ~I' ~" ~ST FROM A.S.P. Z~E 4 ~ID N~TH. ~ SEE DRAWING NSK-~.~-I FOR AS-BUILT LOCATIONS C~DUC~ORS I-~' CEA-DIDX-6~4D~B FOR CONDUCTUS ~, ~6, ~9, I~5,1~-~21, ~24,129, ~$~, I~$ ~ CEA-DIDX-61~4D15 F~ C~DUCT~S 9 · CEA-DIDX-61BADIS F~ CONDUCTORS ~2~-~28 ~ ~A-DIDX-6IB4DI6 F~ CONDUCTORS ~, ~I~-~14, I22, ~ ~2~; CEA-DIDX-61gADI8 F~ C~DUCTORS CEA-DIDX-6IBAD2~ F~ CONDUCTOR 141 ~A-D~DX-6~AD2$ F~ CONDUCTORS ~2, · I~6-14~ AND CEA-D~DX-61BAD26 FOR CONDUCTUS ~ AND 18-2~. DESCRIPTION DS- 1E West Sok-1 22 VICINITY MAP SCALE: I' = ! MILE No. 28 $2 34 48 42 Sec. 23, T. 11 N., R. 19 E. Y X L o titude 5,959,389.28 568,6?8.72 ?8' 17' 5Z895' 5,959,279.~ 56B, 678.91 78' IF. 57,588' 5,959,249.89 568,678.66 78' IF. 5F. 214' 5,959,218.83 568,67~.62 79' 12" 56,916' Longitude 749' Jg' Jl. I26' 149' 39' Jl. 128' 149' J~' 31.142' 149' 39' 31,159' 5,959,188.94 568,678.7J 79' IF' 56,622' 149' Jg' JI. I54' 5,959,159.94 568,67~.82 79' IF' 56.328' 149' 39' 31.159' 5,959, I28.85 568,678.87 78' 17' 56.8J1' 5,959,899.28 ' 568,678.81 78' 17' 55. 748' I49' 39' Jl. I64'~ : 149' 39' 31. I73' SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED lIND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA ,lIND THAT THIS PLIIT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JUNE 22, 2000. ARCO Alaska, Inc. LK6104D28 6/17/2000,,, LOUNSBURY & ASSOCIATES. INC. E,~N~.~.RS PLANNi~RS SURVEYORS AREA: 1D XXXX DSlD EBA CONDUCTORS 28 30 $2 34 36 38 40 42 ASBUlLT LOCATIONS CEA,D1DX-6104D28 js.[ J:iR.v: 2or2. 1 12 14 ~ 1~2 ~ le5 2 , DS-1E ~ m ~ 14 13 !i 112, ~ 23 , , 113 ~ 115 114~ ,,~, o VICINITY MAP ~ ~ 117 · I ~ ~ nS, 4 ~ SCALE: ~" = ~ MILE ~ 9~ , 119 I ~ 121 122~ ~. 123 ~ · i 28 ~.~ ~' 6 ~~55~1~:~5215e ~34e 52 ~O~oe~ :' ' 134~ lg I ( I ~2e' 'e e42 ii ,~7~ ~ ~: 139( ~. ~~ ' JUL ~12 2000 LEGEND si[ SH[[~ ~ 2 ~0. NO,IS ~ LOCiPrO. ~.~OE~O. 0 EXIST/NS CONDUCTORS ~ LOUNSBURy · "AS-~U~ r" CONDUCTOR ~OC~ no~ ~/J~ A AssOcIATES, ~C. ocano s , LK6104D28 6/17/2eee CEA-D1DX-61~4D28 1 oF 2 1 WELL PERMIT CHECKLIST COMPANY ?~1"//,_ ~ WELL NAME/.~--,.~ PROGRAM: exp FIELD&POOL L//~'..~~_~ INITCLASS. 0' "'~V'/' 7"(~)]~_.. GEOLAREA ADMINISTRATION . 2. 3. 4. 5. 6. . 8. 9. 10. 11. A~.~ DATE 12. '"~./Z.-~ 13. Permit fee attached. Lease number approl~ri;t;.~i Unique well name and-number ............ ./ ..... Well located in a defined pool .................. Well located proper distance from drilling unit boundary Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING dev v/' reddl serv wellbore sag ann. disposal para req .. ON/OFF SHORE N )N N 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ ~DATE 26. BOPE press rating appropriate; test to £T'"'~'C~.~ psig. ~ ~/'t~ 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. Y ~ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... O N 31. Data presented on potential overpressure zones ....... Y,,,,,N 32. Seismic analysis of shallow gas zones ........... '- · ~1_,~?' N II AP_PR DATE 33. Seabed condition survey (if off-shore) ............. /~ ~ Y N II ~,~/~ -"~. /~ .C;~ 34. Contact name/phone forweekly progress reports [explor~r~ only] Y N II ANNULAR DISPOSAL35. With proper cementing records, this plan APPR DATE (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ENGINEERING: UIC/Annular COMMISSION: BEW 1~-~/:~, WU ?..~O(,/3,qZ') ;-,,. _ Commentslinstrucfions: c:~soffiCe\wordian\diana\checklist (rev. 02/17/00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX,' No 'special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Sep 15 11:37:19 2000 Reel. Header Service name ............. LISTPE Date ..................... 00/09/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/09/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 3 AK-MM-00108 T. MCGUIRE F. HERBERT 1ST STRING 1D-30 500292296500 PHILLIPS ALASKA, INC. Sperry Sun 15-SEP-00 MWD RUN 4 AK-MM-00108 P. SMITH F. HERBERT 23 lin 10E 387 419 .00 105.30 70.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT 12.250 16.000 110.0 RECEIVED Oil& Gas Cons. Commissi~ Anchorage 2ND STRING 8.500 9.625 6873.0 3RD STRING 6.125 7.000 11305.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD)UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-2 ARE DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP) AND STABILIZED LITHO-DENSITY (SLD). DENSITY DATA ACQUISITION WAS DELAYED 48 HOURS WHILE DRILLING UP-HOLE SECTION. 4. MWD RUN 4 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP) AND STABILIZED LITHO-DENSITY (SLD). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER THE E-MAIL FROM D. SCHWARTZ OF PHILLIPS ALASKA, INC. ON 09/13/00 6. MWD RUNS 1-4 REPRESENT WELL 1D-30 WITH API%: 50-029-22960-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12044'MD, 6661'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). ~ESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVIT (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SS MATRIX, FIXED HOLE SIZE). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SS MATRIX, FIXED HOLE SIZE). SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SNNA = SMOOTHED AVERAGE OF'NEAR DETECTOR'S COUNT RATE. CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8.5" - 6" MUD WEIGHT: 9.1 - 11.8 PPG MUD SALINITY: 500 PPM CHLORIDES FORMATION WATER SALINITY: 13000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH NPHI 6779.5 11952.5 NCNT 6779.5 11952.5 FCNT 6779.5 11952.5 GR 6816.5 11989.0 RPX 6863.0 11996.0 RPS 6863.0 11996.0 RPM 6863.0 11996.0 RPD 6863.0 11996.0 FET 6863.0 11996.0 ROP 6883.5 12043.5 RHOB 8856.5 11967.5 DRHO 8856.5 11967.5 PEF 8856.5 11967.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 3 6779.5 11315.0 4 11315.0 12044.0 # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type.. Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Service Order Units Size Nsam Rep FT 4 1 68 MWD FT/H 4 1 68 MWD API 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD PU-S 4 1 68 MWD CNTS 4 1 68 MWD CNTS 4 1 68 MWD G/CM 4 1 68 MWD G/CM 4 1 68 MWD BARN 4 1 68 .0 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 6779.5 12043.5 ROP MWD FT/H 0 1904~4 GR MWD API 40 447.34 RPX MWD OHMM 0.15 1209.29 RPS MWD OHMM 0.13 183.63 RPM MWD OHMM 0.06 2000 RPD MWD OHMM 0.23 2000 FET MWD OHMM 0.19 91.66 NPHI MWD PU-S 23.43 81.76 FCNT MWD CNTS 100.1 1214 NCNT MWD CNTS 2252 29912.7 RHOB MWD G/CM 1.74 3.16 DRHO MWD G/CM -0.238 0.825 PEF MWD BARN 2.87 14.09 Mean Nsam 9411.5 10529 123.807 10295 137.237 10346 3.81049 10267 3.86713 10267 13.028 10267 15.2003 10267 2.52526 10267 40.7798 10267 654.985 10267 5086.76 10267 2.10545 6066 0.0489982 6066 5.7568 6074 First Reading 6779.5 6883.5 6816.5 6863 6863 6863 6863 6863 6779.5 6779.5 6779.5 8856.5 8856.5 8856.5 Last Reading 12043.5 12043.5 11989 11996 11996 11996 11996 11996 11952.5 11952.5 11952.5 11967.5 11967.5 11967.5 First Reading For Entire File .......... 6779.5 Last Reading For Entire File ........... 12043.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/15 Maximum Physical Record..65535 File Type ................ LO Next File Name .... ~ ...... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NCNT 6779.5 FCNT 6779.5 NPHI 6779.5 GR 6816.5 RPD 6863.0 FET 6863.0 RPM 6863.0 RPS 6863.0 RPX 6863.0 ROP 6883.5 PEF 8856.5 DRHO 8856.5 RHOB 8856,5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11209.5 11209.5 11209.5 11247.0 11256 5 11256 5 11256 5 11256 5 11256 5 11315 0 11220 0 11220.0 11220.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMARAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: 02-AUG-00 Insite 65.41 MEMORY 11315.0 62.2 65.0 TOOL NUMBER 1586NLP6 1586NLP6 1586NLP6 1586NLP6 8.500 6873.0 LSND HT MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 LOgging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 9.10 44.0 9.0 5OO 4.6 3.900 1.915 3.800 1.500 SS 2.65 60.0 129.2 62.0 60.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 i 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HOUR NPHI MWD030 PU-S FCNT MWD030 CNTS Min Max Mean Nsam 6779.5 11315 9047.25 9072 0 1904.4 132.978 8838 40 447.34 141.423 8862 0.15 45.9 3.43428 8788 0.13 63.37 3.60136 8788 0.06 1586.46 5.03311 8788 0.27 2000 8.68573 8788 0.19 80.5 1.46433 8788 23.43 81.76 40.9321 8861 429 1214 716.135 8861 First Reading 6779.5 6883.5 6816.5 6863 6863 6863 6863 6863 6779.5 6779.5 Last Reading 11315 11315 11247 11256.5 11256.5 11256.5 11256.5 11256.5 11209.5 11209.5 NCNT MWD030 CNTS 2252 3237 RHOB MWD030 G/CM 2 3 DRHO MWD030 G/CM -0.052 0.473 PEF MWD030 BARN 3.62 8.43 2613.18 2.01713 0.0423879 5.32748 8861 4728 4728 4728 6779.5 8856.5 8856.5 8856.5 11209.5 11220 11220 11220 First Reading For Entire File .......... 6779.5 Last Reading For Entire File ........... 11315 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11247.5 PEF 11250.0 NPHI 11250.0 FCNT 11250.0 NCNT 11250.0 RPM 11257.0 RPS 11257.0 RPD 11257.0 FET 11257.0 RPX 11257.0 RHOB 11299.0 DRHO 11299.0 ROP 11315.5 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): STOP DEPTH 11989 0 11967 5 11952 5 11952 5 11952 5 11996 0 11996 0 11996 0 11996 0 11996 0 11967.5 11967.5 12043.5 07-AUG-00 Insite 0.41 MEMORY 12044.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (R?M): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPT~ (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) :. MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF {IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 62.8 63.7 TOOL NUMBER 1595 1595 1595 1595 6.125 11305.0 LSND HT 11.00 54.0 9.5 5OO 3.8 1.800 .852 1.800 2.100 SS 2.65 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 t 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 62.0 138.6 62.0 62.0 NPHI MWD040 PU-S 4 1 68 FCNT MWD040 CNTS 4 1 68 NCNT MWD040 CNTS 4 1 68 RHOB MWD040 G/CM 4 1 68 DRHO MWD040 G/CM 4 1 68 PEF MWD040 BARN 4 1 68 32 36 40 44 48 52 9 10 11 12 13 14 Name Service Unit Min Max DEPT FT 11247.5 12043.5 ROP MWD040 FT/H 0 1683 GR MWD040 API 40.07 253.43 RPX MWD040 OHMM 1.55 1209.29 RPSMWD040 OHMM 0.53 183.63 RPM MWD040 OHMM 0.17 2000 RPD MWD040 OHMM 0.23 2000 FET MWD040 HOUR 0.65 91.66 NPHI MWD040 PU'S 23.94 62.49 FCNT MWD040 CNTS 100.1 609.2 NCNT MWD040 CNTS 14137.7 29912.7 RHOB MWD040 G/CM 1.74 3.16 DRHO MWD040 G/CM -0.238 0.825 PEF MWD040 BARN 2.87 15.35 First Last Mean Nsam Reading Reading 11645.5 1593 11247.5 12043.5 68.1741 1457 11315.5 12043.5 112.238 1484 11247.5 11989 6.04592 1479 11257 11996 5.44631 1479 11257 11996 60.5327 1479 11257 11996 53.909 1479 11257 11996 8.82913 1479 11257 11996 39.8201 1406 11250 11952.5 269.601 1406 11250 11952.5 20675.9 1406 11250 11952.5 2.41755 1338 11299 11967.5 0.0723565 1338 11299 11967.5 7.6924 1436 11250 11967.5 First Reading For Entire File .......... 11247.5 Last Reading For Entire File ........... 12043.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number. .......... 1.0.0 Date of Generation ....... 00/09/15 Maximum Physical Record..65535 File Type ................ LO' Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/09/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/09/15 Origin .................... STS' Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments .............. ...STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File