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204-089
TTT 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 – CRU DATE: 12/19/2023 Transmitted: North Slope, Colville River Unit data drophard driveVia CD2-45 50-103-20395-00 201212_CD2-45_Patch_15May2023 CD2-53 50-103-20494-00 204089_CD2-53_LDL_30Nov2022 204089_CD2-53_Patch_14Oct2022 CD3-107 50-103-20529-01 206189_CD3-107_Packer_16Apr2022 CD3-125 50-103-20632-00 210189_CD3-125_LDL_23Feb23 210189_CD3-125_POGLM_03Apr2023 CD3-127 50-103-20634-00 211005_CD3-127_Patch_23Apr2022 211005_CD3-127_PPROF_18Apr2022 CD3-303 50-103-20568-00 208013_CD3-303_CHC_21Feb2023 CD4-499 50-103-20810-00 219161_CD4-499_PPROF_28Sep2023 WD-02 50-103-20285-00 198258_WD-02_WFL_22May2022 WD-03 50-103-20835-00 221103_WD-03_IBC DSLT_12Feb2022 221103_WD-03_USIT_28Feb2022 2 of 2 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 T38298 T38299 T38300 T38301 T38302 T38303 T38304 T38305 T38306 2/29/2024 CD2-53 50-103-20494-00 204089_CD2-53_LDL_30Nov2022 204089_CD2-53_Patch_14Oct2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 10:46:16 -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 16985'feet None feet true vertical 7200'feet None feet Effective Depth measured 16985'feet 11206', 11240', 11276', 11463', 11781' feet true vertical 7200'feet 6670', 6689', 6708', 6811', 6986' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" 5-1/2" 3-1/2" L-80 L-80 L-80 11337' MD 11778' MD 11869' MD 6742' TVD 6984' TVD 7031' TVD Packers and SSSV (type, measured and true vertical depth) 11206' MD 11240' MD 11276' MD 11463' MD 11781' MD N/A 6670' TVD 6689' TVD 6708' TVD 6811' TVD 6986' 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: Alpine 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: 3394' 2371' Burst Collapse Production Liner 1200' Casing 7205'12394' 3357' 114'Conductor Surface Intermediate 16" 9-5/8" 77' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 204-089 50-103-20494-00-00 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: ADL0372097, ADL0380075 Colville River Field/ Alpine Oil Pool CRU CD2-53 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) 850 Gas-Mcf MD 1500 Size 114' 550 12501000 0 8250 200 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: PIIP Patch Packer Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: Baker FHL Retrvbl Packer Packer: Baker FHL Retrvbl Packer SSSV: None Dusty Freeborn dusty.freeborn@conocophillips.com (907) 659-7224Senior Well Integrity Specialist Open Hole w/ Frac: 12394-16985' feet Open Hole w/ Frac: 7205-7200' feet Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Meredith Guhl at 11:46 am, Jan 11, 2023 Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Eagle River, Alaska Date: 2023.01.11 11:21:43-09'00' Foxit PDF Editor Version: 12.0.1 Dusty Freeborn P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 11, 2023 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set across a known tubing leak in producer CRU CD2-53 (PTD 204-089). Please contact me at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN= Dusty Freeborn, E=dusty.freeborn@ conocophillips.com Reason: I am the author of this document Location: Eagle River, Alaska Date: 2023.01.11 11:21:03-09'00' Foxit PDF Editor Version: 12.0.1 Dusty Freeborn DTTMSTART JOBTYP SUMMARYOPS 7/1/2022 REPAIR WELL PULLED 3.5" PIIP PACKER, 16' SPACER PIPE & SNAP LATCH @ 11,278' RKB (PACKER MISSING HALF OF SLIP); RAN 2.12" MAGNET & RECOVERED BROKEN SLIP. IN PROGRESS. 7/2/2022 REPAIR WELL ATTEMPT TO CMIT AGAINST LOWER PACKER **FAILED**; PULLED 3.5" PIIP LOWER PACKER @ 11,273' RKB; OBTAIN SBHPS @ 11,500' RKB & 11,317' RKB (MAX PSI: 3325, MAX TEMP: 151*). READY FOR COIL. 9/28/2022 REPAIR WELL RIH W / MOTOR & MILL CLEANED OUT TO 12400' PUMPING GEL SWEEPS RECIP ACROSS PATCH SETTING AREA FROM 11200' TO 11900' RDMO ****READY FOR E-LINE**** 10/12/2022 REPAIR WELL DRIFT TBG w/ BAR BELL SET UP 2.79", 3' STEM & 2.74" G-RING. TOOLS SD IN GLM # 2 @ 10,495' RKB. UNABLE TO WORK PAST. JOB IN PROGRESS. 10/13/2022 REPAIR WELL DRIFTED TBG 2.79" x 6' 10" DUMMY LOWER PATCH PACKER TO 11,300' RKB. READY FOR ELINE. 10/14/2022 REPAIR WELL RIG UP ELINE, SET LOWER PARAGON II PACKER FOR PATCH AT 11278'. CCL TO MID ELEMENT = 9.75', CCL STOP DEPTH = 11268.25'. READY FOR SLICKLINE. 10/15/2022 REPAIR WELL SAT DOWN EARLY W/ PIIP TEST TOOL @ 5270' SLM. BAILED SAND FROM 5270' SLM W/ 2.50" BAILER, BROKE THROUGH SAND BRIDGE @ 5274' SLM W/ 2.00" D.D. BAILER - CLEAR DRIFT TO TAG PIIP @ 11267' SLM. RECOVERED 2 GAL/SAND WHILE DRIFTING W/ 2.50" D.D. BAILER FROM 3100' SLM TO 5370' SLM - CLEAR DRIFT TO PIIP @ 11267' SLM. LDFN. IN PROGRESS. 10/17/2022 REPAIR WELL TAG SAND BRIDGE @ 3178' SLM W/ 2.50" D.D. BAILER. BREAK THROUGH SAND BRIDGE @ 3185' SLM W/ 2.00" D.D. BAILER. RAN 2.50" D.D. BAILER TO 7500' SLM (RECOVERED ~10 GAL/SAND). LDFN. IN PROGRESS. 10/18/2022 REPAIR WELL RAN 2.50" D.D. BAILER TO 9000' SLM. SWIVELED OFF @ ROPE SOCKET FROM TOOLSTRING @ 9880' SLM. TAG SAND @ 5386' SLM W/ FISHING TOOLS - CANNOT PASS. BAIL 2.50" D.D. FROM 5399' SLM TO 5424' SLM (BAILER FULL/SAND). BREAK THROUGH SAND BRIDGE @ 5455' SLM W/ 2.00" D.D. BAILER. CLEAR DRIFT TO FISH @ 11224' SLM W/ 2.50" D.D. BAILER (2-3 CUPS OF SAND). LDFN. IN PROGRESS. 10/19/2022 REPAIR WELL TAG TOP OF TOOLSTRING @ 11,224' SLM; RECOVERED LOST TOOLSTRING @ SAME; RAN 2.5" x 10' DD BAILER, SAW A FEW BOBBLES FROM 5390' SLM TO 5420' SLM & TAGGED LOWER PACKER @ 11,275' RKB; ATTEMPT TO RUN 3.5" TTS TEST TOOL BUT SD @ 5472'; BAIL FROM 5473' SLM & BROKE THRU @ 5550'SLM W/ 2.5" x 10' DD BAILER. IN PROGRESS. 10/20/2022 REPAIR WELL DRIFT TBG W/ 2.5" x 10' DD BAILER W/ 2.73" MULE BALL BTM & TAG LOWER PACKER @ 11,275' RKB; ATTEMPT TO RUN 3.5" TTS TEST TOOL & SAT DOWN @ 5608' SLM. JOB SUSPENDED FOR PLAN FORWARD. 10/20/2022 REPAIR WELL MOVE UNIT FROM CD1 SPOT AND GET READY FOR JOB. CALL MADE TO LDFN. JOB IN PROGRESS. 10/30/2022 REPAIR WELL CLEARED TBG DOWN TO 3.5" PIIP PACKER @ 11,275' RKB, WHILE RIH PUMPED CRUDE AT 4.6 BPM PAST SWEDGE CENTALIZER ASSEMBLY; RAN 3.5" TTS TEST TOOL TO TEST PACKER @ SAME **PASSED**. JOB COMPLETE. 11/3/2022 REPAIR WELL CLEARED TBG DOWN TO 3.5" PIIP PACKER @ 11,274' RKB, WHILE RIH PUMPED CRUDE AT 5 BPM PAST SWEDGE CENTALIZER ASSEMBLY; SET 3.5" PIIP W/ SPACER PIPE & SNAP LATCH @ 11,248' RKB (OAL = 25.5'). IN PROGRESS. 11/4/2022 REPAIR SET 3.5" ISO SLEEVE (OAL = 22", 8" MID PKG TO MID PKG) @ 2291' RKB. JOB COMPLETE. 11/14/2022 ACQUIRE (AC EVAL) TIFL FAILED DUE TO IA FLUID INFLOW AND PRESSURE INCREASE 11/15/2022 ACQUIRE DATA PULLED ISO SLEEVE @ 2291' RKB. SET TTS TEST TOOL IN PATCH @ 11,250' RKB. PUMPED 126 BBLS CRUDE DOWN TBG PULLED OV f/ STA # 2 @ 10,495' RKB. BULL HEAD 305 BBLS CUDE DOWN IA. OBTAIN PASSING CMIT TO 2500 PSI. ATTEMPT TO SET NEW OV CAME BACK WITH VLV FLAT ON BOTTOM. JOB IN PROGRESS. 11/16/2022 ACQUIRE DATA RAN POCKET BRUSH w/ TATTLE TAIL PIN TO ENSURE POCKET IS OPEN, SET STANDARD 1" x .25" OV w/ BOTTOM LATCH TOP SUB. UNABLE TO GET HOLEFINDER PAST OV TEST TBG ABOVE OV GOOD TEST TO 2000 PSI. JOB IN PROGRESS. 11/17/2022 ACQUIRE DATA SET 3-1/2" HOLE-FINDER @ 10773' SLM & TEST TBG TO 2500 PSI - GOOD TEST. SET 3-1/2" HOLE- FINDER & FIND LEAK BETWEEN 11,208' SLM & 11177' SLM. RDMO. IN PROGRESS. 11/30/2022 REPAIR WELL PERFORM LDL TO DETERMINE SOURCE OF TXIA COMMUNICATION. LOG BASELINE PASS DOWN, LRS ONLINE DOWN THE TUBING, ESTABLISH LLR OF 1 BPM AT 2400 PSI. LOG UP AT 120 FPM FROM TTS TEST TOOL AT 11250' TO SURFACE. LEAK LOCATED BELOW LOGGED INTERVAL. XY CALIPER AND CCL CONFIRM PATCH HAS SHIFTED BELOW GLM AT 11260'. JOB COMPLETE. 12/4/2022 ACQUIRE PULLED 3.5" TTS TEST TOOL @ 11,260' SLM. IN PROGRESS. 12/5/2022 ACQUIRE DATA PULLED 3.5" PIIP PACKER & SPACER PIPE (OAL 26') @ 11,264' SLM; SET 3.5" TTS TEST TOOL IN LOWER PACKER @ 11,275' RKB, LRS PERFORMED CMIT TO 2500 PSI **PASSED**, PULLED 3.5" TTS TEST TOOL. IN PROGRESS. CD2-53 Tubing Patch Summary of Operations 12/9/2022 ACQUIRE DATA SET 3.5" PIIP PACKER W/ 30' SPACER PIPE @ 11,238' RKB; SET 3.5" TEST TOOL @ 11,238' RKB, ATTEMPT TO MIT-T **FAILED**, PULL 3.5" TEST TOOL; RAN 3.5" COLLAR STOP & GOT PASSING MIT-T @ 11,169' RKB. IN PROGRESS. 12/10/2022 ACQUIRE DATA SET 3.5" TTS TEST TOOL @ 11,238' RKB; PERFORM CMIT TO 2500 PSI **PASSED**; PULLED 3.5" TTS TEST TOOL @ 11,238' RKB. IN PROGRESS. 12/11/2022 ACQUIRE DATA SET 3.5" PIIP PACKER W/ SPACER PIPE & SNAP LATCH (OAL = 36.19') @ 11,200' RKB; SET 3.5" COLLET ISO SLEEVE (OAL = 22") @ 2291' RKB. JOB COMPLETE. 12/16/2022 ACQUIRE (AC EVAL) RE-TIFL POST REPAIR (PASSED) Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG: CTMD 12,390.0 CD2-53 11/23/2021 praffer Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Patch CD2-53 12/11/2022 boehmbh Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL OA x FORM COMMUNICATION 5/20/2016 pproven NOTE: Welded sleeve onto surface csg from bottom of starter head to 21.5' w/ X65 12" x 500 wall pipe 3/1/2012 ninam NOTE: TREE: FMC 4-1/16 5K - TREE CAP CONNECTION: 7" OTIS 7/18/2004 WV5.3 Conversio n General Notes: Last 3 entries Com Date Last Mod By TREE: FMC 4-1/16 5K TREE CAP CONNECTION: 7"" OTIS 7/18/2004 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 15.05 37.0 114.0 114.0 62.40 H-40 WELDED SURFACE 9 5/8 8.92 36.7 3,393.7 2,370.7 36.00 J-55 BTC PRODUCTION 7 6.28 34.4 12,394.3 7,205.3 26.00 L-80 BTCM OPEN HOLE 6 1/8 12,394.0 16,985.0 7,200.3 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 30.3 Set Depth 11,337.1 Set Depth 6,741.7 String Ma 3 1/2 Tubing Description Tubing Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-m 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) 30.3 30.3 0.00 HANGER 11.000 FMC 11'' x 3 1/2'' TC-1A-EMS Tubing Hanger FMC P120198 -0002, CPAI MM 1061993 9 2.992 2,291.6 1,794.6 59.83 NIPPLE 4.508 Camco 3 1/2'' x 2.813'' DS PROFILE BP 6I Nipple Camco DS 2.812 5,293.0 3,501.2 55.53 GAS LIFT 4.750 Camco 3 1/2'' x 1'' KBG-2-9 GLM (IBTM BXP) SN:18439-03 Camco KBG-2-9 2.818 10,495.2 6,281.8 56.49 GAS LIFT 4.750 Camco 3 1/2'' x 1'' KBG-2-9 GLM (IBTM BXP) SN:18439-17 Camco KBG-2-9 2.818 11,260.3 6,699.9 57.03 GAS LIFT 4.750 Camco 3 1/2'' x 1'' KBG-2-9 GLM, SN:18439-18 Camco KBG-2-9 2.818 11,307.1 6,725.3 57.03 LOCATOR 4.500 Baker GBH-22 Locator Sub ( Spaced out 7') Baker PN: H45301 0065, Control # 1061596 6 2.992 11,307.6 6,725.6 57.03 SEAL ASSY 3.980 Baker 80-40 20' Seal Assembly ( Total Length - 29.50') Baker 2.980 Top (ftKB) 32.8 Set Depth 11,778.1 Set Depth 6,984.1 String Ma 5 1/2 Tubing Description Tubing Production Wt (lb/ft) 17.00 Grade L-80 Top Connection Hyd 513 ID (in) 4.81 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) 32.8 32.8 0.00 HANGER 11.000 FMC Casing hanger 11" x 5 -1/2" UH-1A-EMS FMC PN: P100016 7005 4.900 11,313.9 6,729.0 56.99 XO Reducing 5.500 5-1/2" 17# L-80 Hyd 513 Box XO 5" Hyd 521 Box locator Coupling 4.400 11,325.9 6,735.6 56.92 SBE 5.000 Baker 80-40 20' SBE 5" Hyd 521 Pin XO 4-1/2" Hyd 521Box Baker PN: H02 -47472- 03 4.000 11,345.0 6,746.0 56.81 XO Reducing 4.500 4-1/2" 12.6# L-80 Hyd 521 Pin XO 3- 1/2" 9.3# EUE-8rd Pin 2.900 11,384.1 6,767.5 56.58 GAS LIFT 4.851 Camco 3-1/2" x 1" KBG-2-9 GLM w/ DV installed, BK Latch SN:17950-04 Camco KBG-2-9 2.818 11,432.2 6,794.0 56.44 LOCATOR 4.500 Baker GBH-22 Locator Sub Baker 80-40 2.990 11,433.2 6,794.6 56.44 SEAL ASSY 3.990 Baker 80-40 20' Seal Assembly (Spaced out 7.14' from full located) Baker 80-40 2.990 11,440.3 6,798.5 56.42 PBR 5.000 Baker 80-40 20' PBR Baker PN: H683-19 -0143, control #: 1053894 09, ser02 2.990 11,463.4 6,811.3 56.37 PACKER 5.960 Baker 7" x 3-1/2" FHL Retrievable Packer Baker PN: H781-20 -3595 2.980 11,506.3 6,835.1 56.41 NIPPLE 3.500 HES 2.813" X Nipple HES 2.813 CD2-53, 1/10/2023 1:16:27 PM Vertical schematic (actual) OPEN HOLE; 12,394.0-16,985.0 OPEN HOLE FRAC; 12,394.0 PRODUCTION; 34.4-12,394.3 NIPPLE; 11,822.4 NIPPLE; 11,506.3 PACKER; 11,463.4 GAS LIFT; 11,384.1 Casing Prdctn - Pup; 11,316.0 PACKER - PATCH - LWR; 11,275.6 GAS LIFT; 11,260.3 LEAK - GLM; 11,260.0 SPACER PIPE; 11,244.0 PACKER - PATCH - UPR; 11,240.0 SPACER PIPE; 11,210.0 PACKER - PATCH - UPR; 11,206.0 GAS LIFT; 10,495.2 Casing Production; 2,415.5 GAS LIFT; 5,293.0 SURFACE; 36.7-3,393.7 XO Threads ; 2,413.7 SLEEVE; 2,292.0 NIPPLE; 2,291.6 Casing Production; 80.8 CONDUCTOR; 37.0-114.0 Casing Prdctn - Pup; 77.4 Casing Production; 37.5 HANGER; 30.3 WNS PROD KB-Grd (ft) 43.83 RR Date 7/18/2004 Other Elev CD2-53 ... TD Act Btm (ftKB) 16,985.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032049400 Wellbore Status PROD Max Angle & MD Incl (°) 95.66 MD (ftKB) 16,557.78 WELLNAME WELLBORECD2-53 Annotation Last WO: End Date 4/12/2016 H2S (ppm) DateComment SSSV: NIPPLE 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) 11,765.4 6,977.2 57.14 LOCATOR 4.520 Baker GBH-22 Locator Sub (overall length .99') Baker 80-40 2.990 11,766.3 6,977.7 57.14 SEAL ASSY 3.990 Baker 80-40 10' Seal Assembly (inside of PBR 9.0') Baker 80-40 2.990 Top (ftKB) 11,767.8 Set Depth 11,869.4 Set Depth 7,031.1 String Ma 3 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-m 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) 11,767.8 6,978.5 57.15 PBR 5.880 Baker 80-40 10' PBR Baker PN:H68 3-19- 0140, control # 1056159 27-02 2.970 11,781.1 6,985.7 57.38 PACKER 5.960 Baker 7" x 3-1/2" FHL Retrievable Packer Baker PN: H781-20 -3595, Control # 1053079 82-02 2.920 11,822.4 7,007.5 58.90 NIPPLE 4.500 HES 2.813" X Nipple HES 2.813 11,861.6 7,027.3 60.34 POOR BOY OVERSHOT 5.990 Baker Poor-Boy Overshot w/ half muleshoe (7.35' swallow) 3.610 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) 2,292.0 1,794.8 59.82 SLEEVE 3 1/2" G-FN ON 2.81" ISO SLEEVE 12/11/2022 1.765 11,206.0 6,670.3 56.96 PACKER - PATCH - UPR 3.5" Paragon II Packer ME @ 11,250' (SN:ALPP35012) Latch (SN:ALPAL35004) Quadco PIIP ALPP 35013 12/11/2022 1.625 11,210.0 6,672.5 56.97 SPACER PIPE Spacer pipe 12/11/2022 1.600 11,240.0 6,688.8 57.01 PACKER - PATCH - UPR 3.5" Paragon II Packer ME @ 11,252' (SN:ALPP35021) Quadco PIIP ALPP 35011 12/9/2022 1.625 11,244.0 6,691.0 57.01 SPACER PIPE 2-1/16" P-110 Spacer Pipe 12/9/2022 1.590 11,260.0 6,699.7 57.03 LEAK - GLM Eline - LOG UP and Find Leak in Glm#3 @11,260' RKB 5/31/2019 0.000 11,275.6 6,708.2 57.05 PACKER - PATCH - LWR 3.5" Paragon II Packer ME @ 11,278' Quadco PIIP ALPP 35024 10/14/2022 1.625 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) 5,293.0 3,501.2 55.53 1 GAS LIFT DMY BTM 1 0.0 4/26/2019 0.000 10,495.2 6,281.8 56.49 2 GAS LIFT OV BTM 1 0.0 11/16/2022 0.250 11,260.3 6,699.9 57.03 3 GAS LIFT OV BTM 1 0.0 5/16/2019 EXT PKG.. Patch ed Over, Left in Pocke t 0.250 11,384.1 6,767.5 56.58 4 PROD DMY BTM 1 0.0 3/26/2016 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) 12,394.0 7,205.2 81.48 OPEN HOLE 6.125 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) 12,394.0 16,985.0 1 OPEN HOLE FRAC 3/6/2006 0.0 0.00 0.00 CD2-53, 1/10/2023 1:16:28 PM Vertical schematic (actual) OPEN HOLE; 12,394.0-16,985.0 OPEN HOLE FRAC; 12,394.0 PRODUCTION; 34.4-12,394.3 NIPPLE; 11,822.4 NIPPLE; 11,506.3 PACKER; 11,463.4 GAS LIFT; 11,384.1 Casing Prdctn - Pup; 11,316.0 PACKER - PATCH - LWR; 11,275.6 GAS LIFT; 11,260.3 LEAK - GLM; 11,260.0 SPACER PIPE; 11,244.0 PACKER - PATCH - UPR; 11,240.0 SPACER PIPE; 11,210.0 PACKER - PATCH - UPR; 11,206.0 GAS LIFT; 10,495.2 Casing Production; 2,415.5 GAS LIFT; 5,293.0 SURFACE; 36.7-3,393.7 XO Threads ; 2,413.7 SLEEVE; 2,292.0 NIPPLE; 2,291.6 Casing Production; 80.8 CONDUCTOR; 37.0-114.0 Casing Prdctn - Pup; 77.4 Casing Production; 37.5 HANGER; 30.3 WNS PROD CD2-53 ... 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" #$%& " #'%! & "(!$ & & &) #$ &# ! && )( & # ! *+* + ,-./0 1234 ,5516789:;612.8/< CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Roby, David S (OGC) To:Glessner, Dana; Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]GMT MT7-06(PTD 221-048, Sundry, 321-590) production test extension APPROVAL Date:Monday, December 13, 2021 12:44:51 PM Dana, Good news. Thanks for the update. Dave Roby (907)793-1232 From: Glessner, Dana <Dana.Glessner@conocophillips.com> Sent: Monday, December 13, 2021 12:43 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Roby, David S (OGC) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL]GMT MT7-06(PTD 221-048, Sundry, 321-590) production test extension APPROVAL Victoria & Dave, just wanted to let you know that we were able to startup the MT7 drillsite yesterday with MT7-06. All fluids are now flowing through the drillsite and crosscountry line to the ACF. thanks, Dana Glessner ConocoPhillips Staff Production Engineer Office: 907-265-6478 Dana.Glessner@conocophillips.com From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Friday, December 10, 2021 3:27 PM To: Glessner, Dana <Dana.Glessner@conocophillips.com> Cc: Roby, David S (OGC) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL]GMT MT7-06(PTD 221-048, Sundry, 321-590) production test extension APPROVAL Thank you for the update Dana From: Glessner, Dana <Dana.Glessner@conocophillips.com> Sent: Friday, December 10, 2021 2:43 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Cc: Roby, David S (OGC) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL]GMT MT7-06(PTD 221-048, Sundry, 321-590) production test extension APPROVAL Victoria, as of this morning we have produced 59,191 total bbls of liquid during the test period. We are targeting startup of the drillsite by Monday with MT7-06. thanks, Dana Glessner ConocoPhillips Staff Production Engineer Office: 907-265-6478 Dana.Glessner@conocophillips.com From: Glessner, Dana Sent: Tuesday, December 7, 2021 9:40 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Roby, David S (CED) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL]GMT MT7-06(PTD 221-048, Sundry, 321-590) production test extension APPROVAL Victoria, as of this morning we are at 46,967 total bbls of liquid produced during our test period. We still need 2-3 more days of test data to dial in our decline rate though. We are frac’ing MT7-01 today and once we have that successfully frac’d we will have to move the flowback unit off of MT7-06 and on to MT7-01. At that point we will have to make a decision to startup the drillsite or leave MT7-06 shut-in and wait for MT7-01. We expect to make a decision by Dec 11 or 12 to go for startup or not. Our frac has been delayed by cold weather by 2 days since I talked to you last Friday. Thank you, Dana Glessner ConocoPhillips Staff Production Engineer Office: 907-265-6478 Dana.Glessner@conocophillips.com From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Tuesday, December 7, 2021 8:19 AM To: Glessner, Dana <Dana.Glessner@conocophillips.com> Subject: RE: [EXTERNAL]GMT MT7-06(PTD 221-048, Sundry, 321-590) production test extension APPROVAL What is the current status. ~How many bbls fluid produced? Timing for DS SU? From: Glessner, Dana <Dana.Glessner@conocophillips.com> Sent: Monday, December 6, 2021 9:02 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL]GMT MT7-06(PTD 221-048, Sundry, 321-590) production test extension APPROVAL Thank you Victoria for a quick response on this one. thanks, Dana Glessner ConocoPhillips Staff Production Engineer Office: 907-265-6478 Dana.Glessner@conocophillips.com From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Monday, December 6, 2021 8:12 AM To: Glessner, Dana <Dana.Glessner@conocophillips.com>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL]GMT MT7-06(PTD 221-048, Sundry, 321-590) production test extension APPROVAL CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Dana, Approval is granted to increase the production limit to 75,000 bbls total fluid with associated gas for an additional 5 to 7 days. The original approval was for 21 days with 50,000 bbls total fluid produced. Drillsite startup is expected on or before December 12, 2021. Previous sundry approved(Sundry 321-590): Flaring for the purpose of testing the well prior to regular production is authorized in accordance with 20.AAC 25.235(d)(6). Flared volumes must be reported on monthly gas disposition report. If test production is sufficient to sustain production through drillsite production facilities test shall be terminated and production routed to permanent facilities instead of testing facilities. Unless otherwise approved by the AOGCC testing is limited to 21 days and 50,000 bbls of liquids. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Glessner, Dana <Dana.Glessner@conocophillips.com> Sent: Friday, December 3, 2021 5:06 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: FW: MT7-06 production test update/question Victoria, thank you for taking my phone call this afternoon. We are currently production testing our unfrac’d producer MT7-06 (PTD 221-048) to determine if we will be able to start the MT7 drillsite up with it alone. We have been cleaned up and in production test mode since 11/26/21. As of today we have produced 29,000 bbls fluid total at an average 5% water cut. On Wednesday 12/1 we were producing 3300 bfpd at 1000 psi tubing pressure and 100% open choke. In an attempt to reduce the backpressure on the well, yesterday, we bypassed the line heater on the portable test separator setup and dropped the tubing pressure by 200 psi, liquid rates increased to 5000-5200 bfpd at 50% choke. We are currently working to open the choke back up to 100%. We believe that with current rates we may be able to go for a drillsite startup late next week but would like to request an additional 5-7 days in order to establish and confirm the decline rate. Since the drillsite startup would only be with this one well we want to ensure adequate flow to keep the crosscountry line from freezing until our next producer comes online ~mid-late December. The current approved sundry (321-590) for the production test is for 21 days or 50,000 bbls total fluid produced. At current rates and as we continue to open the choke over the weekend I think we may exceed the 50,000 bbls fluid limit of the approved sundry by early Monday. I would like to request a revision to the sundry and an additional 25,000 bbls of fluid for a total of 75,000 to get us through another 5-7 days of testing. Please let me know if you have any questions and if you approve to continue testing beyond the 50,000 bbls limit. Thank you, Dana Glessner ConocoPhillips Staff Production Engineer Office: 907-265-6478 Cell: 661-331-7-30 Dana.Glessner@conocophillips.com From: Glessner, Dana Sent: Friday, December 3, 2021 3:05 PM To: 'dave.roby@alaska.gov' <dave.roby@alaska.gov> Subject: MT7-06 production test update/question Hello Dave, are you working today and available for a quick phone call? I wanted to talk to you about our MT7-06 production test progress and ask for an increase in our approved fluid limit to get us through 1 more week of testing. thanks, Dana Glessner ConocoPhillips Staff Production Engineer Office: 907-265-6478 Dana.Glessner@conocophillips.com From:Smith, Travis T To:Loepp, Victoria T (OGC) Subject:Re: [EXTERNAL]Re: CRU well CD2-53 (PTD# 204-089) short term production Date:Wednesday, December 1, 2021 5:14:31 PM Thank you! Travis Get Outlook for Android From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Wednesday, December 1, 2021 5:13:40 PM To: Smith, Travis T <Travis.T.Smith@conocophillips.com> Subject: Re: [EXTERNAL]Re: CRU well CD2-53 (PTD# 204-089) short term production Travis, An ~3 day production period is approved to determine if a FCO is needed. Will then revisit. Victoria Sent from my iPhone On Dec 1, 2021, at 5:07 PM, Smith, Travis T <Travis.T.Smith@conocophillips.com> wrote: The issue with the timeframe is the uncertainty if we will need to use coil or not. Our initial attempt to flow would be very short, 3 days or less. If we need coil to attempt another FCO that work won’t happen until we can mob a coil crew to Alpine. After that attempt, we would want another short period (3 days or less). In other words, the intervals that we would have the well online would be quite short, but I can’t accurately guess at how long we might have to wait until we can do coil work at Alpine if necessary. Travis From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Wednesday, December 1, 2021 5:00 PM To: Smith, Travis T <Travis.T.Smith@conocophillips.com> Subject: [EXTERNAL]Re: CRU well CD2-53 (PTD# 204-089) short term production CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. How long of a production period? Sent from my iPhone On Dec 1, 2021, at 4:04 PM, Smith, Travis T <Travis.T.Smith@conocophillips.com> wrote: Victoria— CRU producer well CD2-53 (PTD# 204-089) has ongoing wellwork to address downhole fill that was preventing the well from flowing. The well had a tubing patch over a leaking gas lift mandrel at 11,260’ RKB—this patch had to be pulled to allow coiled tubing access for a fill cleanout. We have been preparing to set a new patch over the GLM at 11,260’ RKB, but pumping operations indicate the well has again locked up with no ability to pump into the perforations. Going forward we would like to attempt to flow the well on a limited basis to determine if it will surface fluid prior to resetting the patch. If the well will not flow, we intend to do another FCO with coil, and then flow the well shortly before resetting the patch. During these limited periods of flow, we would like to use lift gas down the IA to prevent formation fluid from inflowing into the IA. Would you approve a limited amount of production from this well (prior to resetting the tubing patch) to assist with this wellwork? Thanks very much, please let me know if you have any questions. Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By LAST TAG: CTMD 12,390.0 11/23/2021 CD2-53 praffer Last Rev Reason Annotation End Date Wellbore Last Mod By REV REASON: Pull Iso-Sleeve & P2P Patch 11/23/2021 CD2-53 praffer Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.05 Top (ftKB) 37.0 Set Depth (ftKB) 114.0 Set Depth (TVD) … 114.0 Wt/Len (l… 62.40 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 36.7 Set Depth (ftKB) 3,393.7 Set Depth (TVD) … 2,370.7 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 34.4 Set Depth (ftKB) 12,394.3 Set Depth (TVD) … 7,205.3 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description OPEN HOLE OD (in) 6 1/8 ID (in) Top (ftKB) 12,394.0 Set Depth (ftKB) 16,985.0 Set Depth (TVD) … 7,200.3 Wt/Len (l…Grade Top Thread Tubing Strings Tubing Description Tubing – Completion Upper String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 30.3 Set Depth (ft… 11,337.1 Set Depth (TVD) (… 6,741.7 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-m Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 30.3 30.3 0.00 HANGER 2.992 11.000 FMC P120198- 0002, CPAI MM 1061993 9 FMC 11'' x 3 1/2'' TC-1A- EMS Tubing Hanger 2,291.6 1,794.6 59.83 NIPPLE 2.812 4.508 Camco KBG-2-9 Camco 3 1/2'' x 2.813''DS PROFILE BP 6I Nipple w/ Isolation Sleeve SN: HTN- 3 5,293.0 3,501.2 55.53 GAS LIFT 2.818 4.750 Camco KBG-2-9 Camco 3 1/2'' x 1'' KBG-2-9 GLM W/ DV (IBTM BXP) SN:18439-03 10,495.2 6,281.8 56.49 GAS LIFT 2.818 4.750 Camco KBG-2-9 Camco 3 1/2'' x 1'' KBG-2-9 GLM W/ DV (IBTM BXP) SN:18439-17 11,260.3 6,699.9 57.03 GAS LIFT 2.818 4.750 Camco KBG-2-9 Camco 3 1/2'' x 1'' KBG-2-9 GLM W/ DCK-2-SOV Installed) SN:18439-18 11,307.1 6,725.3 57.03 LOCATOR 2.992 4.500 Baker PN: H453010 065, Control # 1061596 6 Baker GBH-22 Locator Sub ( Spaced out 7') 11,307.6 6,725.6 57.03 SEAL ASSY 2.980 3.980 Baker Baker 80-40 20' Seal Assembly ( Total Length - 29.50') Tubing Description Tubing – Production String Ma… 5 1/2 ID (in) 4.81 Top (ftKB) 32.8 Set Depth (ft… 11,778.1 Set Depth (TVD) (… 6,984.1 Wt (lb/ft) 17.00 Grade L-80 Top Connection Hyd 513 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 32.8 32.8 0.00 HANGER 4.900 11.000 FMC PN: P100016 7005 FMC Casing hanger 11" x 5 -1/2" UH-1A-EMS 11,313.9 6,729.0 56.99 XO Reducing 4.400 5.500 5-1/2" 17# L-80 Hyd 513 Box XO 5" Hyd 521 Box locator Coupling 11,325.9 6,735.6 56.92 SBE 4.000 5.000 Baker PN: H02- 47472-03 Baker 80-40 20' SBE 5" Hyd 521 Pin XO 4-1/2" Hyd 521Box 11,345.0 6,746.0 56.81 XO Reducing 2.900 4.500 4-1/2" 12.6# L-80 Hyd 521 Pin XO 3-1/2" 9.3# EUE- 8rd Pin 11,384.1 6,767.5 56.58 GAS LIFT 2.818 4.851 Camco KBG-2-9 Camco 3-1/2" x 1" KBG-2- 9 GLM w/ DV installed, BK Latch SN:17950-04 11,432.2 6,794.0 56.44 LOCATOR 2.990 4.500 Baker 80-40 Baker GBH-22 Locator Sub 11,433.2 6,794.6 56.44 SEAL ASSY 2.990 3.990 Baker 80-40 Baker 80-40 20' Seal Assembly (Spaced out 7.14' from full located) 11,440.3 6,798.5 56.42 PBR 2.990 5.000 Baker PN: H683 -19-0143, control #: 1053894 09, ser02 Baker 80-40 20' PBR 11,463.4 6,811.3 56.37 PACKER 2.980 5.960 Baker PN: H781 -20-3595 Baker 7" x 3-1/2" FHL Retrievable Packer 11,506.3 6,835.1 56.41 NIPPLE 2.813 3.500 HES HES 2.813" X Nipple 11,765.4 6,977.2 57.14 LOCATOR 2.990 4.520 Baker 80-40 Baker GBH-22 Locator Sub (overall length .99') 11,766.3 6,977.7 57.14 SEAL ASSY 2.990 3.990 Baker 80-40 Baker 80-40 10' Seal Assembly (inside of PBR 9.0') Tubing Description Tubing – Completion Lower String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 11,767.8 Set Depth (ft… 11,869.4 Set Depth (TVD) (… 7,031.1 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-m CD2-53, 11/24/2021 1:09:01 PM Vertical schematic (actual) OPEN HOLE; 12,394.0-16,985.0 OPEN HOLE FRAC; 12,394.0 PRODUCTION; 34.4-12,394.3 POOR BOY OVERSHOT; 11,861.6 NIPPLE; 11,822.4 PACKER; 11,781.1 PBR; 11,767.8 SEAL ASSY; 11,766.3 LOCATOR; 11,765.3 NIPPLE; 11,506.3 PACKER; 11,463.4 PBR; 11,440.3 SEAL ASSY; 11,433.2 LOCATOR; 11,432.2 GAS LIFT; 11,384.1 SBE; 11,325.9 SEAL ASSY; 11,307.6 XO Reducing ; 11,313.9 LOCATOR; 11,307.1 GAS LIFT; 11,260.3 GAS LIFT; 10,495.2 GAS LIFT; 5,293.0 SURFACE; 36.7-3,393.7 NIPPLE; 2,291.6 CONDUCTOR; 37.0-114.0 HANGER; 32.8 HANGER; 30.3 WNS PROD KB-Grd (ft) 43.83 Rig Release Date 7/18/2004 CD2-53 ... TD Act Btm (ftKB) 16,985.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032049400 Wellbore Status PROD Max Angle & MD Incl (°) 95.66 MD (ftKB) 16,557.78 WELLNAME WELLBORECD2-53 Annotation Last WO: End Date 4/12/2016 H2S (ppm) DateComment SSSV: NIPPLE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Nominal ID (in) OD Nominal (in)Make Model Com 11,767.8 6,978.5 57.15 PBR 2.970 5.880 Baker PN:H683 -19-0140, control # 1056159 27-02 Baker 80-40 10' PBR 11,781.1 6,985.7 57.38 PACKER 2.920 5.960 Baker PN: H781 -20-3595, Control # 1053079 82-02 Baker 7" x 3-1/2" FHL Retrievable Packer 11,822.4 7,007.5 58.90 NIPPLE 2.813 4.500 HES HES 2.813" X Nipple 11,861.6 7,027.3 60.34 POOR BOY OVERSHOT 3.610 5.990 Baker Poor-Boy Overshot w/ half muleshoe (7.35' swallow) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 5,293.0 3,501.2 55.53 1 GAS LIFT DMY BTM 0.000 0.0 4/26/2019 2 10,495.2 6,281.8 56.49 1 GAS LIFT OV BTM 0.250 0.0 6/13/2019 3 11,260.3 6,699.9 57.03 1 GAS LIFT OV BTM 0.250 0.0 5/16/2019 EXT PKG.. Patch ed Over, Left in Pocke t 4 11,384.1 6,767.5 56.58 1 PROD DMY BTM 0.000 0.0 3/26/2016 Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 OPEN HOLE FRAC 3/6/2006 12,394.0 16,985.0 0.0 0.00 0.00 Notes: General & Safety End Date Annotation 5/20/2016 NOTE: WAIVERED WELL OA x FORM COMMUNICATION 3/1/2012 NOTE: Welded sleeve onto surface csg from bottom of starter head to 21.5' w/ X65 12" x 500 wall pipe 9/3/2010 NOTE: View Schematic w/ Alaska Schematic9.0 7/18/2004 NOTE: TREE: FMC 4-1/16 5K - TREE CAP CONNECTION: 7" OTIS CD2-53, 11/24/2021 1:09:02 PM Vertical schematic (actual) OPEN HOLE; 12,394.0-16,985.0 OPEN HOLE FRAC; 12,394.0 PRODUCTION; 34.4-12,394.3 POOR BOY OVERSHOT; 11,861.6 NIPPLE; 11,822.4 PACKER; 11,781.1 PBR; 11,767.8 SEAL ASSY; 11,766.3 LOCATOR; 11,765.3 NIPPLE; 11,506.3 PACKER; 11,463.4 PBR; 11,440.3 SEAL ASSY; 11,433.2 LOCATOR; 11,432.2 GAS LIFT; 11,384.1 SBE; 11,325.9 SEAL ASSY; 11,307.6 XO Reducing ; 11,313.9 LOCATOR; 11,307.1 GAS LIFT; 11,260.3 GAS LIFT; 10,495.2 GAS LIFT; 5,293.0 SURFACE; 36.7-3,393.7 NIPPLE; 2,291.6 CONDUCTOR; 37.0-114.0 HANGER; 32.8 HANGER; 30.3 WNS PROD CD2-53 ... WELLNAME WELLBORECD2-53 STATE OF ALASKA Huta 2 $ Z019 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONSAOGCCCC 1. Operations Abandon Ll Plug Perforations Ll Fracture Stimulate U Pull Tubing Ll Operations shutdown Ll Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well ❑ Other: Tubinc Patchn 2. Operator 4. Well Class Before Work:5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc Develo ment P ❑ Stratigraphic ❑ Exploratory P ry ❑ Service ❑ 204-089 3. Address: P.O. Box 100360 6. API Number: Anchorage AK 99510 50-103-20494-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0372097 1 ADL0380075 CRU CD2 -53 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Colville River Field /Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 16,985 feet Plugs measured feet true vertical 7,200 feet Junk measured feet Effective Depth measured feet Packer measured 11,463 feet true vertical feet true vertical 6,811 feet Casing Length Size MD TVD Burst Collapse Conductor 77' 16" 114' 114' Surface 3357' 9-5/8" 3,394' 2,371' Production 12,360 7" 12,394' 7,205' Liner 11,745' 5-1/2" 11,778' 6,984' Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) 3.5" L-80 11,337' MD 6,742' TVD Packers and SSSV (type, measured and true vertical depth) PUP Upper Patch Packer 11,250' MD 6,694' TVD PIIP Lower Patch Packer 11,275' MD 6,708' TVD BAKER FHL Packer 11,463' MD 681 1'TVD BAKER FHL Packer 11, 781' MD 6986' TVD 12. Stimulation orcement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A N/A N/A 14. Attachments (required per 20 AAC 25.070,25071,&25.283) 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 ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Authorized Name: Sara Carlisle Contact Name: Rachel Kautz/Sara Carlisle Authorized Title: ell Integrity & Compliance Specialist Contact Email: n2549(-conocoohillios.com &-- O — 659-7126 Authorized Signature: � VN 4 "� Date: Contact Phone: Form 10-404 Revised 4/2017 1/7-1— 17-///' p �y,"J ,#r llti RBDMS.i L"" UN 2 8 2019 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 20, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7a' Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, JUN 28 2019 F" OGCC Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the installation of a retrievable tubing patch set in producer CRU CD2 -53 (PTD 204-089) to repair the well. Please contact Rachel Kautz or me at 659-7126 if you have any questions. Sincerely, Sara Carlisle Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. CRU CD2 -53 DESCRIPTION OF WORK COMPLETED SUMMARY DATE OPERATION DETAILS CRU CD2 -53 was found to have a leak in the tubing at —11,260'near/at a gas lift mandrel. A patch was set Executive across the leak area to repairthe tubing. A passing TIFL on 6/18/19 confirmed the patch restored tubing Summary integrity. E -LINE SET LOWER ANCHOR AT 11276' RKB ME. SET QUADCO UPPER PACKER, SPACER PIPE, SNAP LATCH IN 6/5/2019 LOWER ANCHOR. TOP OF PATCH AT 11250' ELMD. LRS PERFORMING PASSING MIT -T TO 2500#. ***TEST TOOL LEFT IN TOP OF PATCH" *(OAL=24", 1-3/4" FN) READY FOR SLICKLINE TO SET OV. SET BAITED 2.5" RB ON TEST TOOL @ 11,222' SLM. PULLED GLV FROM 10,495' RKB, SET 1/4" OV @ SAME. 6/6/2019 PULLED PARAGON TEST TOOL @ 11222' SLM. SET 2.81" ISO SLEEVE (OAL = 22"/ 2.125" ID) @ 2292' RKB. COMPLETE. 6/13/2019 PULLED OV @ 10,495' RKB ( CHECK STUCK OPEN W. DEBRIS) REPLACED WITH NEW. PASSING DDT ON IA. PULLED TEST TOOL @ 11,222' SLM. SET 3.5" SIO SLEEVE @ 2292' RKB. JOB COMPLETE. RE-TIFL (PASSED): Initial T/I/O/00 = 185/1300/735/420. IA FL @ 10495' (st #2, OV). SI WV & double blocked AL line. Stacked WHP's to T/I/O/00 = 935/970/500/410 in 1 hr. IA FL @ same location. Bled AL line to 300 psi. 6/18/2019 Bled IA to 380 psi in 1 hr. IA FL @ same location. Starting T/I/O/00 = 965/380/340/400. 15 min T/I/O/00 = 970/380/330/395. 30 min T/I/O/00 = 975/380/325/395. IA FL @ same location. 45 min T/I/O/00 = 975/380/320/395. 60 min T/I/O/00 = 975/380/920/395. IA FL @ same location. Final T/I/O/00 = SI 975/380/920/395. WNS PROD WELLNAME CD2 -53 WELLBORE CD2 -53 ConocoPhillips Alaska. Inc. C.,.1. 1: en be PN Mandrellnserts VMial W,amallc(azlud) 31 ell HANGER; 30.3 N TOPOIKB) (ftKB) Make MMel OO (in) Se, Type Inch TyPe PoOSixe (in) TRORun (pill Run Deft Co. 11,260.3 6,699.9 Camco KBG-2- 1 GAS LIFT OV BTM 0350 0.0 T116120-1919 EX T HANGER, 320 9 PKG.. Patch ed Over, Left in POOR, I 411,384,1 63675 Camco HBG -2- 1 PROD DMV BTM 0.000 0.0 32612016 9 Notes: General & Safety Ene Dzm conWCioR: 3ZanK0 711812004 NOTE: TREE FMC 4 -1/165K -CTIC N:im TREE CAP CONNECTION: >" OTIS 913/2010 NOTL View SCheno3UCwl Alaska SchematC9R NIPPLE: 2291531112012 NOTE Welded deeve onto smraCe ca9 from bottom of slader bead to 21.5'vd X6512' x 500 wall pipe SLEEVE: 2.2920 g 01fi NO TE: WAIVEREDWELLOAx FORM COMMUNICATION GUNFACE;36.]333i]- GAS IIEr, S,HSO GPS OFT', 10.1953 PACKF3�11,2EHD GAS LIFT IT2a]3 SPACER PiPE', 11, E1.0 PACKER', 112]5.0 LOCATOR',11p11 PC Sio. :113139 6EALASSY', 11,3P1.fi SBE; 11.3258 CAS OFT: 11 ]a Li Loc1 v/3zz n3EALASSM. Bn.11i,z Per. 11 H03 PACKER, tl,asll NIPPLE:11.509.3 LOCATOR; 11,7fi5.3 BEM.AssY; It,]W S PBRII,]6]0 PACKER: 11.81.1 WPPLE,I,9II.a POOR BOY OVEr3HOT ll.03f.6 PACKER', 11.WI.2 NIPPLE: 11.9112 ALEG: 11,%3.1 PROWCTON=,-12.Y1.3�� e OPEN NOTE FflAC; 13,SW3 OPEN HOLE; 12.5SLO-189050 ORIGINATED ALASKA E -LINE SERVICES 42260 Kenai Spur Hwy PO BOX 1481- Kenai, Alaska 99611 PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION 204059 1 Alpine 30 TICKET # WELL q API # LOG DESCRIPTION DATE OF LOG �" 1 1 1�•� 11itsialffis M1. Munro BP North Slope 1 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc. IxC`E'V^§ 1 0 0 Attn: NSK-69 C 700 G Street J(1N 112019 Anchoraee. Alaska 99501 A r)f-%^.. AOGCC 0 0 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR 0 0 1 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 Please return via e-mail a copy to both Alaska E -Line Services and Conoco Phillips Alaska: VS -11. PROACTivE DiAynosiic SERVICES, INC. WELL LOG TRANSM/TiAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 2040Pg 30P23 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection (Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Caliper Report 2) Signed Print Name: ProActive Diagnostic Services, Inc. Attn: Diane Williams RECEIVED 130 West International Airport Road Suite C MAY 2 2 2019 Anchorage, AK 99518 pdsanchoraaeAmemorvlop com AOGCC 10 -May -19 CD2 -53 CD 50-103-20494-00 Date: hLoq PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(&MEMORYLOGCOM WEBSITE: WWW.MEMORYLOG.COM D-Wch[ve,N4esterTempbtePiles\'le plateaDstributio,,\T,e,s tt Sheet,C.nc.PHlips_T.,a.,tdo,x ji S-11. PRoAcrivE DiagnosTic SERVICES, INC. WELL LOG TRANSMITTAL To: ConocoPhillips Alaska, Inc. Kaylie B. Plunkett ATO- P.O. Box 100360 Anchorage, Alaska 99510 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) STP Leak Detection 2) Signed : Print Name: ProActive Diagnostic Services, Inc. Attn: Diane Williams 130 West International Airport Road Suite C Anchorage, AK 99518 Ddsancho raaeO-memorvloa.com 12 -May -19 CD2 -53 r, BL/CD RECEIVED MAY 2 1 2019 AOGCC 50-103-20494-00 Date : Oj w l q PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245$952 E-MAIL: PDSANCHORAGEr(DMEMORYLOGCOM WEBSITE: WWW.MEMORYLOG.COM 204089 30 82 7 D:\A�hives\Mas@�Templu[eFiles\Templa[es\Dislnbumn\Transrzti[GlShe=ts.C..,mPbillips Tran tbo:: 20$089 30 82 3 Memory Multi -Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: CD2 -53 Log Date: May 10, 2019 Field: Alpine Log No.: 14377 State: Alaska Run No.: 1 API No. 50-103-20494-00 Pipe Description: 3.5 inch 9.3 Ib. L-80 EUE-M Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 11,499 Ft. (MD) Inspection Type: Corrosive and Mechanical Damage Inspection COMMENTS: This caliper data is tied into the top of GLM 4 at 11,384 feet per the wellbore schematic dated May 9, 2019. This log was run to assess the condition of the tubing to see if there are any holes below 10,400 feet and to determine the condition of the tubing with respect to internal corrosive and mechanical damage prior to setting a patch. A 3-D log plot of the caliper recordings from 11,200 feet to 11,499 feet (end of log), where a leak is suspected, is included in this report. The caliper recordings indicate the 3.5 inch tubing logged appears to range from good to poor condition, with a maximum recorded wall penetration of 54% in an area of general corrosion in joint 357 (11,226 ft). Additional wall penetrations ranging from 20% to 53% wall thickness are recorded in 34 of the 378 joins logged. No significant areas of cross-sectional wall loss are recorded throughout the tubing logged. The caliper recorded intermittent deposits from -9,600 feet to the top of GLM 4 at -11,257 feet, restricting the I.D. to 2.80 inches at 11,103 feet. A graph illustrating the minimum recorded diameters on a joint -by -joint basis across the tubing logged is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 13%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: Deposits Deposits 2.80 inches 354 11,101 Ft. (MD) 2.81 inches 331 10,382 Ft. (MD) No other significant I.D. restrictions are recorded throughout the tubing logged. C. Goerdt C. Waldrop G. Clayton ProActive Diagnostic Services, Inc. / R0. Ro;x 1369, Stafford, Ti: 77,197 Phone: (281) 431-7100 cr (888) 565-9035 Fax: (281) 431-7125 E-mail: PDSAnalvsis( memorvloe com Prudhoe Bay Field Office Prone: (907) 659-2307 Fax: (907) 659-2314 Corrosion 54 357 11,226 Ft. (MD) Line Corrosion 53 356 11,167 Ft. (MD) Corrosion 47 358 11,232 Ft. (MD) Corrosion 41 355 11,161 Ft. (MD) Corrosion 35 354 11,132 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 13%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: Deposits Deposits 2.80 inches 354 11,101 Ft. (MD) 2.81 inches 331 10,382 Ft. (MD) No other significant I.D. restrictions are recorded throughout the tubing logged. C. Goerdt C. Waldrop G. Clayton ProActive Diagnostic Services, Inc. / R0. Ro;x 1369, Stafford, Ti: 77,197 Phone: (281) 431-7100 cr (888) 565-9035 Fax: (281) 431-7125 E-mail: PDSAnalvsis( memorvloe com Prudhoe Bay Field Office Prone: (907) 659-2307 Fax: (907) 659-2314 Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (383- 11,498.8') Well: CD2 -53 Field: Alpine Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: May 10, 2019 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 42 F 50 1,561 100 3,131 11 4,696 GLM 1 a LL 11 6,280 2 I I a 1 I 0 250 1 7,841 300 9,404 GLM 2 10,975 GLM 3 GLM 4 NEW 362 11,474 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 362 j F 1 a I I a 1 I 1 (14S Minimum Diameter Profile Well: CD2 -53 Survey Date: May 10, 2019 Field: Alpine Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc Tool Size: 1.69 inches Country: USA Tubing I.D.: 2.992 inches Minimum Measured Diameters (in.) 1.75 2 2.25 2.5 2.75 s M CL d O JR—' PDS Report Overview S Body Region Analysis Well: CD2 -53 Survey Date: May 10, 2019 Field: Alpine Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 pef L-80 EUE-M Analyst: Waldro Pipe Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE-M 2.992 in 39 ft 11,499 ft Damage Configuration (body) 50 40 30 20 10 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole Limber of jo nts damaged (total — f25) 20 4 41 0 0 Damage Profile (%wall) Penetration body Metal loss body 0 50 100 GLM 1 (6:00) GLM 2 (1:00) GLM 3 (6:30) GLM 4 (5:30) Bottom of Survey = 362 PDS Report Joint Tabulation Sheet Well: CD2 -53 Survey Date: May 10, 2019 Field: Alpine Analyst: Waldrop Company: ConocoPhihlps Alaska, Inc. Pipe Description 3.5 in. 9.3 ppf L-80 EUE-M Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 39 ft 11,499 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. Damage Profile I.D. Comments (% wall) (in.) 0 50 100 39 0 12 3 Pu 1R29 0. 2 9 4 2.9 0 0.01 3 0 2.96 Pu 0 E03-13 4 2. 0 0.03 1 3 .93I.J. De osit 0 0.03 13 3 2.93 Lt. Deposits. j 0.03 1 2.95 0 0.02 9 4 95 0 0.02 9 3 2.94 0 0. 4 14 4 .93 0 0.02 7 3 2.95 0 0.04 14 5 .94 110 n m 12 4 Lt. sits. 12 1 390 0 0.03 13 3 2.95 13 421 0 0. 9 2.95 14 452 0 0.03 12 4 2.94 15 483 0 0.02 7 32.95 16 514 1 0 0.028 2.94 7 544 0 0.02 8 1 3 2.96 18 575 0 0.02 9 3 2.94 19 606 0 0.04 142 96 20 636 0.04 5 3 2.95 I Shallow Line of Pits. 21 667 0 0.03 11 3 2.96 22 697 0 0.02 7 3 2.94 23 728 0 0.03 1 4 2.92 1 It. Deposits 24 759 0 0.02 8 2 2.93 25 790 0 0.04 15 5 2.90 Shallow Line of Pits. Lt. Deposits, 26 821 0 0.04 14 3 2.93 Lt. Deposits. 7 852 O.02 9 4 Lt. De 28 883 0 0.02 9 3 2.90 It. . 29 914 0 0.03 13 3 2.89 Lt. De osits. 30 945 0 0.03 13 2 2.92 Lt. De sits. 1 975 0 0.03 11 3 2.9 32 1006 0 0.05 20 3 2.91 Line of Pits. Lt. Deposits. 3 1037 0 0.03 11 3 294 4 1068 0 0.02 9 3 2.94 35 1099 0 0.04 14 4 2.94 36 1110 0 0.02 9 3 2.93 Lt. Denos't . 37 1 1161 0 0.02 8 3 2.95 38 1192 0 0.03 13 5 2.93 39 1223 0.04 15 4 2-93 ShallowLint! of Pits. 40 1254 0 0.03 11 1 4 2.94 41 1285 0 0.03 12 4 2.94 4 1316 0.0 1 4 2. 4 43 1347 0 0.04 15 4 2.94 Shallow Pitting. 44 1376 0. 2 2.94 45 1409 0 0.0 7 4 2.95 46 1440 0 0.03 11 2 2.96 47 1471 0 13 2.96 48 1501 0.0 8 2 2. gr Penetration Body Metal Loss Body Page 1 PDS Report Joint Tabulation Sheet Well: CD2 -53 Survey Date: May 10, 2019 Field: Alpine Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Descrip' n 3.5 in. 9.3 ppf L-80 EUE-M Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 39 ft 11,499 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. Damage Profile I.D. Comments (% wall) (in.) 0 50 100 4 1533 0 0.03 13 98 50 0 13 4 2.97 51 1591 0 0.04 14 3 2.96 5 1 0 3 12 4 2.94 53 1650 0 0.04 17 412-96 hallow Lin of its. 54 1679 0 0.02 7 55 1 0 0. 13 Lt. De s' . 56 1742 0 0.02 57 1772 0.05 0.05 19 Shallow Line of Pits8 1802 0.0 59 1834 0 0.04 17 Shallow Line of Pits. 60 18 0 0.02 8 6 1894 004 1 Sh w Line of P' 62 1923 0 0.02 6 2 2.96 63 1955 0 0.03 13 2 2.96 64 1 1984 0 0.02 9 2 996 65 2015 0 0.03 13 4 2.94 66 2045 0 0.03 1 3 9.95 67 2076 0 0 2 2 297 68 2106 0 0.0311 2 2.96 69 136 0 9 2.96 70 2167 0 0.03 11 1 4 1 2. 71 2198 0 0.03 10 3 2.96 7 0 10 73 2260 0 0.03 0 4 .99 73.1 2291 0 0.02 7 2 2.95 Pu 73.2 2301 0 0 0 2.81 AMCO S NIPPL 73.3 2307 0 0.05 19 3 2.95 Pu Shallow Pitting, 74 317 0 11 2 2. 4 75 2 0.0 1 2 2.9 76 2381 0 0.03 11 2 2.96 77 1 0 0.02470 3 1 2.94 78 2444 0 0.02 7 1 2 1 2.93 79 2475 0 0.02 7 2 2.95 80 2507 0 0.02 8 1 2.97 81 2538 0 0.02 8 1 2.95 82 2570 0 0.02 7 2 2.95 83 2601 0 0.02 6 2 2.94 84 2631 0 0.03 10 2 2.95 85 2662 0 0.03 12 7 2.94 86 2694 0 0.03 12 = 2.94 87 2726 0 0.02 7 2 1 2.q,l 88 2757 0 0.03 11 2 2.95 89 1 2788 0 0.02 8 2 2.95 90 2820 0 0.02 8 3 2.95 91 851 0 0 9 2.95 2882 0 2 7 1 2.95 93 2914 0 0.02 7 1 2.98 4 45 0.0 6 1 2.96 95 7 0 7 --- Penetration Body Metal Loss Body Page 2 J;4s- PDS Report Joint Tabulation Sheet Well: CD2 -53 Survey Dater May 10, 2019 Field: Alpine Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description 3.5 in. 9.3 ppf L-80 EUE-M Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 39 ft 11,499 ft. Joint No. Jt. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. Damage Profile I.D. Comments (% wall) (in.) 0 50 100 96 3008 0 0.02 9 1 2.94 97 3037 0 0.01 5 1 2.95 98 3068 0 0.03 12 3 2.95 99 3099 0 0.02 7 2 2.97 10 3131 0 0.02 9 2 2.95 101 3162 0 0.02 6 2 2.95 102 3193 0 0.02 7 2 2 97 103 3226 0 0.04 14 8 2.94 104 3257 0 0.03 10 4 2.96 105 3288 0 0.03 12 2 2.95 106 3319 0 0.03 11 1 2.95 107 3351 0 0.02 6 2 2.95 108 3382 0 0.01 5 1 2.95 109 3414 0 0.03 11 2 2.94 110 34450.02 7 2 2.95 111 1 3476 0 0.02 7 1 112 3507 1 0 0.02 7 1 1 2.94 113 3539 0 0.04 14 1 2 2.96 114 3570 0 0.02 7 1 2 2.95 115 3601 0 0.01 4 1 1 2.93 116 3632 0 0.03 13 2 2.95 117 3664 0 0.02 7 2 2.94 118 3695 0 0.02 9 2 2.94 119 3725 0 0.02 9 1 2.94 120 3756 0 0.02 7 2 1 2.94 121 1 3788 0 0.04 14 2 2.94 122 3819 0 0.02 9 2 2.94 123 3851 0 0.02 8 1 2.95 124 3883 0 0.02 7 2 2 si 125 3914 0 0.01 6 1 1 2.94 126 3945 0 0.02 7 2 2.95 127 3976 0 0.02 6 3 2.93 128 4008 0 0.03 10 2 2.94 129 4038 0 0.02 7 1 1 2.95 130 4068 0 .01 5 2 1 2.94 131 4099 0 0.02 7 1 2.94 132 1 4131 0 0.02 8 3 2.94 133 4162 0 0.01 5 2 2.94 134 4194 0 0.02 8 1 2.93 135 4225 0 0.02 8 1 2.95 136 4256 0 0.02 8 2 2.94 137 4289 0 0.03 12 2 2.94 138 4319 0 0.02 8 2 2.95 139 4351 0 0.02 7 2 2.95 140 4382 0 0.03 12 1 2.9 141 4413 0 0.02 6 1 5 142 4445 0 0. 7 2 2. 143 4476 0 0.02 6 1 2.95 144 4 0 0.02 6 1 .94 1 453 9 0 0.02 7 1 2. Penetration Body Metal Loss Body Page 3 ji-�s PDS Report joint Tabulation Sheet Well: CD2-53 Survey Date: May 10, 2019 Field: Alpine Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description 3.5 in. 9.3 ppf L-80 EUE-M Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 39 ft 11,499 ft. Joint No. It. Depth (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal loss % Min. Damage Profile I.D. Comments (% wall) (in.) 0 50 100 146 4571 0 0.02 7 1 2.94 147 4602 0 0.02 7 1 2.95 148 4633 0 0.01 4 1 2.94 149 4665 0 0.02 7 2 2.94 150 4696 0 0.02 6 2 2.93 Lt. Deposits. 151 4728 0 0.02 7 2 2.95 152 4759 0 0.03 10 3 2.94 153 4789 0 O.OL- 9 3 2.93 154 4821 0 0.02 8 2 2.95 155 4852 0 0.02 9 2 2.95 156 4884 0 0.02 6 1 2.97 157 4915 0 0.02 6 1 2.94 158 7 0 0.02 9 2 2.95 159 4978 0 0.01 5 0 2.95 160 5009 0 0.02 7 2 2.95 161 5041 0 0.02 9 2.94 162 1 5072 1 0 0.01 5 1 1 2.95 163 .5104 0 0.01 1 5 1 12.95 164 51 0 0.0 2 .9 165 5166 0 0.02 6 1 1 2.94 166 5198 0 0.02 6 2 2.93 167 5229 0 0.02 6 2 2.93 168 5261 0 0.02 7 2 2.94 168.1 5292 0 0.05 18 2 2.91 Pup Shallow Lineits. Lt. Deposits. 168.2 5302 0 0 0 0 2.88 168.3 5308 0 0.01 5 1 -GLN&IILAICH-9-6:00) 2.96 Pu 169 5312 0 0.03 12 2 9,94 170 5344 0 0.02 7 2 2.94 171 5375 0 0.02 7 4 2.94 JZ2 5406 0 0.02 6 2 2.94 173 5437 0 0.02 7 1 2.93 Lt. Deiposits. 174 5468 0 0.01 5 2 2.94 175 5500 0.02 8 2 2.94 176 5532 0 0.02 6 1 2.95 177 5563 0 0.02 6 3 2.94 178 1 5595 0 1 0-02 9 3 2.95 179 5624 0 0.02 7 2 2.93 180 5654 0 0.02 6 1 2.95 1 5686 0 0,02 6 2 2.95 182 5717 0 0.01 5 2 2.94 183 5Z49 0 0.02 7 2 2.95 184 5780 0 0.026 1 2.95 185 5812 0 0.02 6 2 2.93 186 5643 0 0.02 8 4 2.94 187 5874 0 0.01 1 5 1 1 2.95 188 1 5906 0 0.02 1 8 1 4 T 2.95 189 5938 0 0.01 5 1 1.96 190 5969 0 0.02 7 3 2.95 1 5999 0 0.02 6 1 2 1 2.96 192 6030 0 0.02 8 1 2 1 2.94 Penetration Body Metal Loss Body Page 4 jib. Well: CD2 -53 Field: Alpine Company: ConocoPhilips Alaska, Inc. PDS Report Joint Tabulation Survey Date: May 10, 2019 Analyst: Waldrop Sheet Pipe Description 3.5 in. 9.3 ppf L-80 EUE-M Tubing Nom. ID 2.992 in. Body Wall Top Depth Bottom Depth 0.254 in. 39 ft 11,499 ft. Joint )t Depth No. (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 3 2 02 7 2 2. 94 6092 0 0 7 3 2.95 195 6123 0 0.02 8 2 2.94 196 6155 0 0.02 7 3 2.95 197 6186 0 0.02 6 2 294 198 6217 0 0.02 6 1 2.94 199 6 48 0.02 9 ,9 200 G 0 0.01 1 201 6311 0 0.03 11 6 2.94 202 0 0.02 7 3 2. 203 6372 0 0.02 7 2 2.95 204 64 4 0.0 7 3 2. 05 4 0 0.02 7 2 2.9 206 6467 0 0.02 7 3 2.94 207 6498 0 0.03 13 4 2. 208 1 6529 0 8 1 2.93 209 1 6560 0 0.02 6 2 2.94 210 6591 1 0 0.02 6 1 2.94 211 6623 1 0 0.02 7 2 .94 212 6653 0 0.01 6 1 2.94 213 6684 0 0.02 7 3 .95 214 6715 0 0.02 7 94 215 6747 0 0.01 6 1 2 2.95 216 6778 0 0.02 8 1 5 .94 217 6810 0 0.01 4 1 4 218 6841 0 0.02 7 2 2.94 219 6872 0 0.02 9 1 2 94 2206904 0 0.01 5 1 2.93 22 1 69350 0.02 6 1 5 222 6967 0 0.01 5 1 . 4 2236998 0 0.02 6 1 2.93 2 7030 0.01 5 2 2,95 225 7061 0 0. 2 7 2 2.94 226 7092 0 0.02 6 2 2.94 7 1 7124 0 7 = 2.94 228 1 7155 0 .02 7 1 2.94 229 7187 0 0.03 11 2 2.94 2 0 7 17 0.01 5 94 231 7248 0 0.02 6 2 2.94 232 7279 o 0.02 6 2 2.94 233 000.002 7 3 234 7341 0 .2 7 3 2. 4 235 7371 7 2 2.95 6 402 G 95 237 7432 6 3 2.94 38 7464 MOO.02 6 1 .95 39 74955 1 .93 240 7527 4 2 2.93 Lt. De osits. 41 5 7 .97 4 7589 6 2 2.94 Penetration Body Metal Loss Body Page 5 JR -S Well: CD2 -53 Field: Alpine Company: ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Survey Date: May 10, 2019 Analyst: Waldrop Sheet Pipe Descrip Uon 3.5 in. 9.3 ppf L-80 EUE-M Tubing Nom. ID 2.992 in. Body Wall Top Depth Bottom Depth 0.254 in. 39 ft 11,499 ft. Joint )t. Depth No. (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss °% F Min. LD. (in.) Comments Damage Profile (%wall) 0 50 100 43 762 1 0 0.01 5 2 44 76 0 5 2 .93 osits. 245 7684 0 0.02 6 1 2.94 7715 0 1 4 1 6 24 7746 0 0.02 7 2 2. 7778 0 0.02 8 2 2.94 7809 0 0.0 6 2 2.9a 7841 0.02 9 2 294 7872 0 0.02 6 1 2.93 Lt. Deposits. 7904 A55 00 7 2 2. 2 Lt. sits. 7935 0 0.01 6 2 2.94 7967 0.02 62.94 79 0.02 7 3 2.92 t. De ' s 8030 0 0.02 8 2 2.94 57 8060 0.02 6 1 2.94 2 0 02 6 1 .93 osi 259 8124 0 0.01 5 1 2.94 260 815 0 0.02 7 2 2.94 6 7 0 7 .95 262 8217 0 0.02 8 2 2.93 Lt. Deposits. 263 9 0 6 1 .93 osit 264 8281 0 0 6 1 9 265 8312 0 0.02 6 1 2.94 266 34 0 9 3 .93 osit . 67 8375 0 0. 6 1 4 268 840510.02 02 7 1 2.94 69 84379 2 194 270 846803 13 1 .94 271 0 9 2 2 . De osit . 272 85317 4 273 85630 7 2 2.93 Lt. De osits. 274 85 7 1 .93 7 86260 7 .9 276 865502 7 3 2.94 277 8 7 9 1 94 78 87182 6 1 279 87492 8 1 2.93 280 87 16 .95 28 88121 6 2 2. 4 282 88431 5 2 2.94 283 8874 13 1 193 284 1 8905 0 0.02 7 1 2.94 285 8937 0 0.02 6 1 2.94 286 8968 0 0.02 7 1 2.93 287 8999 0 0.03 10 2 2.93 Lt. Deposits. 2 9029 0 0.02 7 2 2.94 2 9061 0 M2 7 3 2.93 Lt. Deo 290 9092 0 0.02 8 4 2.94 1 4 0.02 7 1 .9 It. De 't 292 91 00.07 1 293 Penetration Body Metal Loss Body Page 6 ii -S Well: CD2 -53 Field: Alpine Company: ConocoPhilips Alaska, Inc. PDS Report Joint Tabulation Survey Date: May 10, 2019 Analyst: Waldrop Sheet Pipe Description 3.5 in. 9.3 ppf L-80 EUE-M Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 39 ft 11,499 ft. Joint No. Jt. Depth (Ft.) Pen.Pen. Upset (in.) Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 93 9187 0 0.03 13 2 2.94 94 0 .02 7 2 2.94 295 9248 0 0.03 10 2 2.94 296 9279 0 0,02 9 3 2.93 osits 297 9310 0 0 3 298 9341 0 0.02 9 2 2.94 299 9373 0 0.029 . 4 300 9404 0 0.02 9 2 2. 301 9436 0 0.02 9 4 2.94 302 1 9467 0 0.05 8 2. Shall Pittin . De osi . 303 9498 0 0.02 6 2 2.94 04 5300 1 R03 13 3 2. 4 305 95610.03 2 2.94 306 9593 0 0.03 13 3 2.94 307 9623 0 0.04 2 2. hallow Pitfing. 308 9654 0 0.04 17 2 2.9 allow Pi 309 9685 0 0.04 17 3 2.92 Shallow Pittin . Lt. De osits. 10 9717 0 0.03 13 2 2.9 . De 311 9748 0 Q.05 1 .92 Ilow Pi . It n. - e 312 312 9780 0.04 0.03 13 1 2.93 Lt. De osits. 313 9 1] 0 0.04 15 3 .91 al ow Pi fin 14 9842 0 0.04 17 4 .89 ShAlgw Line of Pits. L. Deposits. 315 9872 0 0.04k2l 3 2.90 Shallow Pitfin . Lt. Deposits. 316 4 0 5 5 .89 tallow Pi 'n t. e sits. 317 9935 0 0. 7 Line f its. osits. 318 9967 0 0.05 3 2.90 Line of Pits. Lt. Deposits. 319 9 87 Lin f Pits. Deposita, 320 10029 0 0.06 3 2.90 Isolated Pitting,Lt. Deposits. 321 1 0 .O5 4 .89 i of Pi t. DeJ38 1 0. 4 2. 0 Sh II w Pitfi t. De o 'ts. 10121 0 0.05 4 2.89 Shallow Pitting. Lt. De osits. 10153 0.05 06 22 4 90 I ted Pi Lt. its. 10184 0 0.0 18 Shallow Line Pits. Lt. sit . 10216 0 0.06 22 3 2.89 Line of Pits. Lt. e osits. 10246 0 9 4 .89 Shallow Line f Pits. e osi s. 10277 0 0.05 19 4 2.88 Shallow Line of Pits. Lt. Deposits. 329 10308 0 0.05 21 4 2.91 Line of Pits Lt. Deposits. 30 10338 0 0.05 19 3 2.91 Shallow Pitting. t. De sits. 331 1036 0 0.07 26 5 2.81 Line of Pits. Deposits. 332 10401 0.05 0.05 20 4 2.90 Line of Pits. Lt. Deposits. 333 104 0 0.06 23 4 2.91 Li of Pits. Lt. Der)osits, 334 1 10464 1 0.04 0.05 20 4 287 Lin Pits. L Dt2pQsits. 334.1 10493 0 0.02 9 1 2.90 Pu LL Deposits. 33 10498 4 8 0 88 2 LA H(a 1:0 334.3 10504 0 2.93 Pu 7 0 2.90 hallo P'ttin . Lt. osits3 1 8 .04 !.04 a 2.88 f Pits. t. De os'337 10570 0 2.86 Line of Pits. Lt. De osits. 338 1 5 0. .85 e of Pis t. De '33 1 0.06 2.88 1 ine of Pits I t. De osi Penetration Body Metal Loss Body Page 7 ii4-s Well: CD2 -53 Field: Alpine Company: ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Survey Date: May 10, 2019 Analyst: Waldrop Sheet Pipe Description 3.5 in. 9.3 ppf L-80 EUE-M Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 39 ft 11,499 ft. Joint Jt. Depth No. (Ft.) Pen. Upset (in.) Pen. Body I (in.) Pen, % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 0 10663 0.04 1 0.05 19 3 2.88 Shallow Line of Pits. Lt. osi 341 10694 0 1 0.06 2.88 Is at d Pittina Lt. Deposij5, 342 10725 0.06 0.06 22 5 2.88 Line of Pits. Lt. Deposits. 34 1 757 0. 4 0.03 3 1 2.88 Lt. De o i s. 44 1 788 07 26 4 2.88 Line Qf Eits. Lt. Deposits. 345 10819 0 0.06 24 3 2.87 Line f Pits. Lt. n---- 346 10851 0.04 7 2 4 2 Is ltd o;-:-- Lt. --- 347 7 10882 1 0.04 6 24 4 2.88 Lne o Pits. L.1 e 348 10 14 0 .05 21 5 2.88 Line of Pits. Lt. De -sits. 349 0944 6 25 5 2. in- Pit,.11e o ' 350 10975 1 0.07 1 0.06 22 5 2.88 Isolated Pittin If De -sits. 351 11007 1 0 25 6 2.8 Line Pits. e 35 038 0.29 7 2.86 1 -late tin t. D S. 353 11069 0.05 0.07 28 4 2.83 Line of Pits. Lt. De osits. 354 1 jilol I n. 6 35 7 2.80 Corr i n. D --- e 35511 0.0 0.1 41 7 o rosin Lt. D sits. 356 1 11164 53 9 2.85 Line Corrosion. Lt De -sits. 357 95 54 3 2.87 Corrosion.5 1 2 47 11 . 5 C rrosi n358.1 11258 10 4 2.91 Pu Lt. De osits. 358. 7 6 %0.140.14 0 2.89 M 3 TCH 6:308 3 112 12 3 2. Pu . De359 11272 2 2.93 Lt De -sits9.1113 1' 4 0 P S all Line Pits. e 'ts. 35 11309 0 0 2. BAK R 80-4 CC SEM Y 359.3 11337 0 0 0 0 2.84 SBE 4 1134 0 .OS 1 5 2. P Shall ine C r onion Lt. -sits. 360 11348jO.040.05 5 1 2.93 Lt. De -sits. 60.1 11 2.95 P--- 36121340 2. GM4LTH. •30 360.3 11390 11 4 2.90 P.. Lt. De -sits. 361 11394 7 1 L. 361.1 11425 1 3 2. Pu flow e of its. Lt. osi 361 .2 114320 0 2.96 BAKER 80-40 SEAL ASSEMBLY 1. 1145 0 BAKER 8- PBR 3 114610 2. 7" " FH ETR L PACKFIR 361.5 11469 20 5 2.92 PLine of PiL. De osits. 1147 6 1 2. 3 Lt. si Penetration Body Metal Loss Body Page 8 PDS Report Cross Sections Well: CD2 -53 Survey Date: May 10, 2019 Field: Alpine Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Cross Section for Joint 357 at depth 11,226.289 ft. Tool speed = 52 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 93% Tool deviation = 59° Finger = 6 Penetration= 0.138 in. Corrosion 0.14 in.= 54% Wall Penetration HIGH SIDE= UP Well: CD2 -53 Field: Alpine Company: ConocoPhillips Alaska, Inc. Country: USA PDS Report Cross Sections Survey Date: May 10, 2019 Tool Type: UW MFC 24 No. 214320 Tool Size: 1.69 No. of Fingers: 24 Cross Section for Joint 356 at depth 11,167.459 ft. Tool speed = 51 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 94% Tool deviation = 64° Finger = 7 Penetration = 0.135 in. Line Corrosion 0.13 in. = 53%Wall Penetration HIGH SIDE= UP jiPDS Report Cross Sections Well: CD2-53 Survey Date: May 10, 2019 Field: Alpine Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc Tool Size: 1.69 Country: USA No. of Fingers: 24 Cross Section for Joint 354 at depth 11,103.359 ft. Tool speed = 52 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area = 99% Tool deviation = 20° Minimum I.D. =2.797 in. Deposits Minimum I.D. = 2.80 in. HIGH SIDE= UP ji35 Well: CD2-53 Field: Alpine Company: ConocoPhillips Alaska, Inc. Country: USA Tubing: 3.5 in. 9.3 ppf L-80 EUE PDS Report Cross Sections Survey Date: May 10, 2019 Tool Type: UW MFC 24 No, 214320 Tool Size: 1.69 No. of Fingers: 24 Cross Section for Joint 331 at depth 10,381.649 ft Tool speed = 50 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area= 98% Tool deviation = 640 Minimum 1. D. =2.807 in. Deposits Minimum I.D. =2.81 in. HIGH SIDE= UP 1 WN$ PROD WELLNAME CD2 -53 WELLBORE CD2 -53 ConocoPhillips rren Announces Max Angle$MD TD A'raAaD, ula Field Name 5OJO3'*=WI WMlb.,..m InoII°) MDIXRBI pc[B(m IXKBI ALPINE 501032049400 PROD 8588 18,55]]8 16,9850 Ins: N PPLE No X3. (PP.) pate miz;n a um KB -0M lnl RIg BNex9e Dah Last WO: 4/12/2018 43.83 ]/182004 cp2<s. sa2Pfa3 ]1NPM Last Tag V«Iras[nnntlwlztuep Abrobeon p11KIn in 1 End Date 1 pbaw. LMModw Inst Tag: RKB 12,089.0 629/2011 ,0253 ninem HwGE6.,e,_ Last Rev Reason Mno.W. EndDM w.M.. L«1 Moa By wwGEH, 338 Rev Rea3om T5 gnnComm CD2-53deylg Casing Strings Casing Dmetlpnon oD gni Mpnl Top heel sw Dapm 101681 BM Dapth (Twl... WUP,n R..j... T.,no. CONDUCTOR 1H 15.05 3740 114.0 114.0 62.40 HAO WELDED C«InB D«crrptlon OD 1101 ID gni TOP MNBI eM OFpN IDXBI aMpgNn ITw1... YMen IL. OruN TopTmmd SURFACE 85/8 8.82 38.7 3,393) 2,3)0.] 36,00 J-55 BTC Ca......Opnon o0 gn1 Mgnl Top IXKBI 8«DepM gtltBl eM Depm nvDl... WeLnn g.. areae Top lnrmd PRODUCTON ) 6.28 344 12,3&1,3 7,2053 28.00 L-80 BTCM CaaNIg O«[rlpnon Op 1101 ,.1101 Top Tval SMD«m IDKBI Sol Depin (Tial,., YNlan IL. BrWB ToplNrYtl OPEN HOLE 61.8 12,394.0 16,965,1 7,210.3 copplmrOR.rzo-v4g Dmg Strings rumngpm[nplan zo-me Ma... UPPER 312 COMPLETION 3.5' Ip(in) 2.09 Tep (nKel 36.3 aM peMn ln. 11,337.1 sM prom lTwll-vA1mn6 8,]41] 9.30 Bratle L. Top c3nnecnan EUEm NIPPLE.22af a Completion Details Tap Rwl TOPmcI Nmnlntl Top (T.)(sm) (°I Xem Dm coon ID Nn 30.3 30.3 0.00 HANGER FMC 1T'x312"TC- tA-EMS Tubing Hangar 2.992 3.29tB 1,]84.8 58.83 NIPPLE CMCO 31I2'x 2.813"DSPRORL BP 61 Nipple w/Isolation 2.812 SI8Wo SN: Hi 11,30].1 84725,3 57.03 LOCATOR Baker GBH722Lomlor Sub ISpaced out T) 2992 smRAce„s z3ser- 11,3026 8,]25.6 9.03 SEAL ABSY Baker 904020'Deal Assambly(Total Length -29.50) 2980 GnS LIR,e.A30 Tuning D«[rlplion SbFg Ma... M(Inl 5u7bn,D ABUNERx 512 4.81 35 -TUBING Top (pKB) 32.5 SM pytn gale 11,7>B.1 eM p«N(NDI (... 6984.1 W1(blli 17.00 Orade L -e0 Tap Connmtlan Hytl513 Completion Defall5 , GAa LIFTID,WSl Top nwl_. Top°) ncl NMIn. TOPg(KBI gntBl norn. Com ID lip 328 328 0.00 HANGER FMCCninghang3r 11'x5-12'UH-IA-EMS 4800 11,3138 6]29.0 55.99 XO Reducing 5 -12'17#L -BO Hyd 5138ox XO S'Hytl 521 Boxlocelor Coupling 4.400 R11111T 11„101 11,325.9 6,7358 56.92 SBE Baker W4029 SBE 5'Hytl 521 Pin X00.12"Hyd 521B.4.006 11,345.0 57480 56.81 XO ReduUn 4 -la -12.W 12'12.&tL-80Hyd 521 Pin X03-12'9.39 EUE-&d Rn 2.9W 11,4322 6)84.0 56.44 LOCATOR Baker GBH -22 Lomwr Sub 2,990 LOGT0p. 11, 3011 11,937.2 8,794.8 56 TEALA3SY Baker 804020'93.1 Assembly (9p3rod out 7.14' from lml lemmd) 2.990 m Reeucoa. galea 31:725 58.42 PBR Baker804030'PBR 2990 sE.elsssr; n.nle 11,4834 8,8113 5H.37 PACKER Baker Tx3-1?PHIL Retrievable Packer 2,9&1 sae. n.nsa 11,5083 683.11 1 58,11 NIPPLE HES 2.813' X N ripple 2,813 11,765.9 8,90.2 5],14 LOCATOR Baker GBH- 22 Locator Sub (.or.I lai,9h 99') 2,990 11,766.3 BO7.7 9.14SEALASSY Baker 804010' S.al AWMIny(1nside of PER 9.0) 2,990 ca-_. uFr 113«1 Tubing Dmerlpom 6nNg Ms... M (In) LOWER STACKER 3V2 298 PACKER Tap I in 11j9.8 Bel Depin (R. 11,888,1 BH paprn IryDI 1,., ],031.1 wt(RBtI 8.30 Orad. L-80 Top CenneNon EUE�m Completion Details L...R.11 r.- .L.Y Top MXa TOPnwI Top M[I Nominal (nKa r) nemo« eom ID On 11,7628 g,.78.51 9d6 PBR B.k31804010' PBR 2,970 PBR.nnw; 11,781 11 6.985.71 57.38 PACKER Bak.r7'x3-1/2'FHLRelrievebl, Pecker 2991 P.I R. 11.11' 1 11,822.4 7,00].5 50.90 NIPPLE HES 2813' XNIppie 2,813 NPPIE 09043 MONS 7,OD.3 80.34 POOR BOY Bakm Poor -Boy Cv'3mhct w/hall Muleshoe (7.35' swallow) 3610 OVERSHOT Tubing Omnlpnon S.M9 Ma... 1.19.1 Top(DNB) am.1..110 ln. b« Dopm Oval(... wx (ib -1 Orad. Top CnnnMlan TUBING 45k3.5' 3112 2.00 11,866.0 11,953.6 7,0708 9.30 LW EUEmotl Completion. Details -.0 TOR, 11 ia51"Onig) sE AIIr, n.le9a TOP MtI Hvminal TOP BMq M-1 I°I go. pm Dom Ib lin 11,8912 ],0.11.) 61]9 PACKER BAKER SABJ PACKER W MILLOUT EXTENSION Pelf,n]six 11,991,2 ],065.0 6311 NIPPLE HES XN NIPPLE NO GO w/ 2.812POLISH BORE 2,750 PKKER. 11 791 1 11,953.1 7,0703 1 8352 WLEG BELL COLLAR W,,,,NEGUIO E 3.000 ... Other In Hole (Wire -Ing, retrievable plugs, valves. pumps, }fish, etc.) rvPPLE. 11.62]4 To m4e1 T"I'VOl Topinel ("a) IY D« com Ron Dem mpp 11,911.0 7,004.9 63]0 CAT VLV BTANpING 12.813 XN CAT STANDING VALVE 962019 O.OW POOR ecr OVEFfl OT FOR: Summary it 961. slvlDMe 3/62008 PmPPen[Daipned llbl PrpPantln FomMtlnn 1101 Pp@ER, f!ea12 Sl9tl bRp 6 Top D."0TK W BIm LIMBI LMk m Flul Fye vorcuoin(nb9 Valslunylbb6 1 3'BI2008 12,384.0 16,985.0 1=0 Mandrel Inserts w rvwttE: 11 W12 fRT ffiArvpw v'VLV, 11 W10 no Tap MAN N To (w) IM elMWe ModN OD an)fbry Lyles union Type Type Ponslxe TRORun (in)pull Ran Otle Com 5283.0 3,501.2 Camco HBG -2- 1 GAS LIFT DMY BTM Onion 0.0 4282019 2 10,495.2 8281.8 Camco KBG-2 1 GAS LIFT GLV BTM 0198 2,09 .0 4282019 9 3 11,260.3 8.890.9 Cemm I KBG 2 1 GAS LIFT OV BTM 0250 0.0 5/]2018 9 4 11,384.1 6,767,5 OMO. KBG-2- 1 PROD OMY BTM -0 W0 00 32620(8 9 PRJJVGTIOrv_x <� 1_"n1'� ' oPE,nsEPP u. a o GPEN noLe.0 as n,r v -o :WNS PROD WELLNAME CD253 WELLBORE CD2 -53 conocoPhiuips - coza3,sarz9+F]2�«PN Notes: Genre I B Safety v rtcY SNwefl:leuwll Fntl Data MnoWMon )/182004 NOTE: TREE'. FMC 9 -1/165K -TREE CAP CONNECTION:7' OTIS nANGER ]o9� 03/2010 NOTE; Vmw Sclumadc w/Alaska Sorometic90 FLWGER:92's 3/iR012 NOTE: Weltled sleeve onlo surfem "o from bMlom of slartar head to 21.5'w/X8512"x 500 wall pipe 5/202018 NOTE: WAIVEREO WEI17 Ax FORM COMMUNICATION roaouwcr,. trn-111 p Hm PLE.2, .le HRF.cE. s,..,.,._v GAEUFT,1.Ll GAS LIFT, 108852 GASLIPT. 11, 21,. IAUTOR, 11, 90i 1 AG FA. -O: 11313 B SEALAESY, 11N76 SBE, 11}259 G56 LIFT; 11.3P11 LO14TOR, 114'':2 ;FAL POOY, 1143.2 PHP, 11 N8 ] PR[HEF 1166S4 NIPRE: II S 5d LOUTGR, 11,-L5' SFAL%SS V, i1,i3tl3 PBR. 1118' 8 PARKER, 11.1611 NIPRE, If 9224 POOR SOV OWPSHOT. 111A18 CALKER; 116811 NPC_E, 11 V 12 CAT GT Ll, v_ tL.at PROOLICO011..an-_8 9 ' OPEN HOLEI'I.O. OPEN HOLE1t VS -11. PROACTIVE DIACINGSTIC SERVICES, INC. WELL LO TRANSMITTAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 20 40x9 30819 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) STP Leak Detection 2) Signed Print Name: ProActive Diagnostic Services, Inc. RECEIVED Attn: Diane Williams 130 West International Airport Road MAY 2 1 2019 Suite C Anchorage, AK 99518 AOGCC odsanchoraaeOmemorvloa com l� 12 -May -19 CD2 -53 CD 50-103-20494-00 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 M INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-9952 E-MAIL: PDSANCHORAGEC(DMEMORYLOGCOM WEBSITE: WWW.MEMORYLOGCOM D:\A.W ei u\taste,T—PlateFiles\Te-Pl.t \DUDibolion\T.,.itWShee CommPhilliPs Ttenunit.dor STATE OF ALASKA MAY 11 2016 ALA.OIL AND GAS CONSERVATION COMION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon E Plug Perforations r Fracture Stimulate r Pull Tubing F Operations Shutdown r Performed: Suspend E Perforate r Other Stimulate r Alter Casing F Change Approved Program(- Plug for Redrill E Perforate New Pool E Repair Well F Re-enter Susp Weill" r 2. Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory r 204-089 3.Address: 6.API Number: P. O. Box 100360,Anchorage, Alaska 99510 Stratigraphic r Service E 50-103-20494-00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL 380075,ADL 372097 CRU CD2-53 • 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NONE Colville River Field/Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 16985 feet Plugs(measured) None true vertical 7200 feet Junk(measured) None Effective Depth measured 7374 feet Packer(measured) 11463, 11781, 11891 true vertical 4567 feet (true vertical) 6811, 6986, 7042 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 3357 9 5/8 3394 2371 PRODUCTION 12360 7 12394 7205 OPEN HOLE 4591 6 1/8 16985 7200 Perforation depth:Measured depth: 0 True Vertical Depth: 0 SCANNED JAN 2 5 ZD17 Tubing(size,grade, MD, and TVD) 3.5 x 5 1/2, L-80, 11954 MD, 7071 TVD Packers&SSSV(type, MD, and TVD PACKER- BAKER FHL RETRIEVABLE PACKER @ 11463 MD, 6811 TVD PACKER- BAKER FHL RETRIEVABLE PACKER @ 11781 MD, 6986 TVD PACKER- BAKER SAB-3 Packer @ 11891 MD, 7042 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): None Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-in Subsequent to operation Off Line 14.Attachments(required per 20 AAC 25.070,25.071,&25.283 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development F Service E Stratigraphic (— Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas I- WDSPL r Printed and Electronic Fracture Stimulation Data E GSTOR r WINJ E WAG E GINJ r SUSP E SPLUG I- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt 316-170 Contact Sara Heskin 265-1027 Email: sara.heskin@conocophillips.com Printed Name Sara Heskin Title Associate Wells Engineer Signature - Phone:265-1027 Date 5 M ())1 / i l / ► to Form 10-404 Revised 5/2015 VIZ—. //2-1/C, Submit Original Only 0/4RBDMS IN MAY 1 1 2016 WNSD ah CD2-53 ConocoPhillips $ Well Attribut l Max AngleWD TD AI i5k<i.11,, - Wellbore API/UWI Field Name Wellbore Status incl(") MD(ftKB) Act Btm(ftKB) CCHOOt higlps " 501032049400 ALPINE PROD 95.66 16,557.78 16,985.0 ° ..- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Coe-53,5/10/2016746:08 AM SSSV:NIPPLE Last WO: 4/12/2016 43.83 7/16/2004 Vertical schematicLex-lush Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;30.3-• Last Tag.RKB 12,086.0 6/29/2011 Rev Reason:WORKOVER;GLV C/O;SET ISO lehallf 5/3/2016 Ally RI - SLEEVE Casing Strings HANGER;32.8 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread _1.4 CONDUCTOR 16 15.052 37.0 114.0 114.0 62.40 H-40 WELDED 11! _ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1...Grade Top Thread 1SURFACE 9 5/8 8.921 36.7 3,393.7 2,370.7 36.00 J-55 BTC j F( 1 Casing Description (in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ` ■: PRODUCTION 7 6.276 34.4 12,394.3 7,205.3 26.00 L-80 BTCM L; Cas ng Description (in) ID(in) °Top(RKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread -_ OPEN HOLE 61/8 12,394.0 16,985.0 7,200.3 I Tubing Strings Tubing DescriptionString Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection UPPER I 3 1/2 2.992 30.3 11,337.1 1 1 I 6,741.7 9.30 L-80 EUE-m COMPLETION 3.5" 1 1 1 CONDUCTOR;37.0-114.0 Completion Details Nominal ID XO Threads;2,289.7 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 30.3 30.3 0.00 HANGER FMC 11"x 3 1/2"TC-1A-EMS Tubing Hanger 2.992 NIPPLE;2,2918 5, C.I.. 2,291.6' 1,794.6 59.83 NIPPLE Camco 3 1/2"x 2.813"DS PROFILE BP 61 Nipple w/ 2.812 SLEEVE;2,292.0 leiIsolation Sleeve SN:HTN-3 PP XO Threads;2,294.0 11,307.1 6,725.3 57.03 LOCATOR Baker GBH-22 Locator Sub(Spaced out 7') 2.992 11,307.6 6,725.6 57.03 SEAL ASSY Baker 80-40 20'Seal Assembly(Total Length-29.50') 2.980 ,1 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection LOWER 51/2 4.813 32.8 11,778.1 6,984.1 17.00 L-80 Hyd 513 COMPLETION 5.5"x 3.5" Completion Details SURFACE;36.7-3,393.7 Nominal ID Top(ftKB) Top(ND)(RKB) Top Incl(°) Item Des Com (in) X0 Threads;5,283.5 32.8 32.8 0.00 HANGER FMC Casing hanger 11"x 5-1/2"UH-1A-EMS 4.900 GAS LIFT;5,293.0 ar 11,313.9 6,729.0 56.99 XO Reducing 5-1/2"178 L-80 Hyd 513 Box XO 5"Hyd 521 Box locator 4.400 XO Threads;5,2995 , Coupling 11,325.9 6,735.6 56.92 SBE Baker 80-40 20'SBE 5"Hyd 521 Pin XO 4-1/2"Hyd 4.000 XO Threads;10,491.4 !4 521 Box GAS LIFT;10,495.2 ', - 11,345.0 6,746.0 56.81 XO Reducing 4-1/2"12.68 L-80 Hyd 521 Pin XO 3-1/2"9.3#EUE-8rd 2.900 xo Threads;10,501.7 Pin 11,432.2 6,794.0 56.44 LOCATOR Baker GBH-22 Locator Sub 2.990' X0 Threads;11,256.6 GAS LIFT;11,260.3 W. . 11,433.2 6,794.6 56.44 SEAL ASSY Baker 80-40 20'Seal Assembly(Spaced out 7.14'from full located) 2.990 xo Threads;11266.8 IN 11,440.3 6,798.5 56.42 PBR Baker 80-40 20'PBR 2.990 i 11,463.4 6,811.3 56.37 PACKER Baker 7"x 3-1/2"FHL Retrievable Packer 2.980 LOCATOR;11,3071 is 11,506.3 6,835.1 56.41 NIPPLE HES 2813"X Nipple 2.813 ' LES 11,765.4 6,977.2 57.14 LOCATOR Baker GBH-22 Locator Sub(overall length.99') 2.990 XO Reducing;11,313.9 11,766.3 6,977.7 57.14 SEAL ASSY Baker 80-40 10'Seal Assembly(inside of PBR 9.0') 2.990 SEAL ASSY;11,307.6 MMS' Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(R.. (ND)(...Wt(lb/ft) Grade Top Connection SEE;11,325.9 _ LPOWER STACKERRI 31/21 2.9921 11,767.8 11,869.4 7,031.1 Depth 1 9.301 L-80 'Top /MICompletion Details Nominal ID ii Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) a-" 11,767.8 6,978.5 57.15 PBR Baker 80-40 10'PBR 2.970 GAS LIFT;11,384.1 _ 11,781.1 6,985.7' 57.38 PACKER Baker 7"x 3-1/2"FHL Retrievable Packer 2.920 11,822.4 7,007.5 58.90 NIPPLE HES 2.813"X Nipple 2.813 11,861.6 7,027.3 60.34 POOR BOY Baker Poor-Boy Overshot w/half muleshoe(7.35' 3.610 OVERSHOT swallow) LOCATOR;11,4322 - SEAL ASSY;11,433.2 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(IL.Set Depth(ND)(...Wt(16/t) Grade Top Connection TUBING 4 5"x3 5" I 31/21 2.9921 11,869. 4 11,953.61 7,070.61 9.301 L- 80 IEUE-mod PER;11,440.3 Completion Details PACKER;11,463.4 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) i.. . 11,8912 7,041.7 61.39 PACKER BAKER SAB-3 PACKER w/MILLOUT EXTENSION 3.875 11,941.2 7,065.0 63.11 NIPPLE HES XN NIPPLE NO GO w/2.812"POLISH BORE 2.750 11 11,953.1' 7,070.3 63.52 WLEG BELL COLLAR WIRELINE GUIDE - 3.000 II LOCATOR;11,7653 NMOther In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top)TVD( Top not SEAL ASSY;11,766.3 Top(ftKB) (ftKB) (°1 Des Corn Run Date ID(in) FOR;11,767.8 111M2.292.0 1,794.8 59.82 SLEEVE 3 1/2"G-FN ON 2.81"ISO SLEEVE 4/30/2016 1.765 PACKER;11,781.1 Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(ND) (9001 (ftKB) (ftKB) (ftKB) Type Date Corn it 12,394.0 16.985.0 7,205.2 7,200.3 OPEN HOLE 3/6/2006 Frac job completed with 3080146 behind pipe and FRAC 3080548 total pumped IF Mandrel Inserts POOR BOY OVERSHOT; i=i"="i St 11,881 8 eh PACKER;11,091 2 ' ` N � Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (Rre(RKB) Make Model OD 9n) SeType Type (in) (psi) Run Date Com _-, 1 5,293.0 3,501.2 Camco KBG-2- 1 GAS LIFT GLV BTM 0.188 1,846.0 4/29/2016 BOT 111 9 TOM NIPPLE;11,941.2 i LATC 11 H WLEG;11,953.1 = _ ONL 2 10,495.2 6,281.8 Camco KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 4/16/2016 .OT 9 TOM LAIC H ONL Y PRODUCTION;34.4-12,394.3, ° - OPEN HOLE FRAC;12,394.0 OPEN HOLE;12,394.0-18,985.0t. i WNS lip • CD2-53 ConocoPhillips Alaska,Inc, ConocoPhiihps..` CO2-03,5/10120167:46:08 AM Vertical srdwmakc(achu9 HANGER,30.3 t(_s,.r HANGER,328 1 Ll. Mandrel Inserts St ati �'r j:�. N Top(TVD) Valve Latch Port Size TRO Run a3 Top(1tKB) (RCont KB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Co -(I 3 11,260.3 6,699.9'Cantu) KBG-2- 1 GAS LIFT OV 'BTM 0.313 0.0 4/29/2016 BOT 9 TOM ' - LATC -- —0.104" H ONL I 4 11,384.1 6,767.5 Camco KBG-2- 1 GAS LIFT DMY �BK 0.000 0.0 3/26/2016 / Notes:General&Safety 9 CONDUCTOR,37.0-114.0 End Date Annotation 7/18/2004 NOTE:TREE: FMC 4-1/16 5K-TREE CAP CONNECTION: 7"OTIS XO Threads;2,289.7 9/3/2010 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE;2,291 6 8/29/2011 NOTE:WAIVERED WELL OA x OOA COMMUNICATION SLEEVE;2,292.0, Ii 3/1/2012 NOTE:Welded sleeve onto surface csg from bottom of starter head to 21.5'w/X65 12"x 500 wall pipe XO Threads,2,294.0 a i SURFACE;36.7-3,393.7_ • XO Threads,5,263.5 1 GAS LIFT',5,293.0 '.1: XO Threads',5,299.5 • I XO Threads;10,491.4 GAS LIFT,10,495.2 : XO Threads,10,501.7 4 I I XD Threads,11,256.6 i. GAS LIFT;11,260.3 .: XO Threads,11,266.8 4 LOCATOR',11,307.1 me V XO Reducing;11,313.9 SEAL ASSY;11,307.6 SBE,11,325.9 I ameM I Ij GAS LIFT,11,384.1 ^i! I LOCATOR 11,432.2 III SEAL ASSY,11,433.2 -- PBR;11,440.3 PACKER;11,463.4 L 1 1 LOCATOR;11,765.3 IME SEAL ASSY,11,766.3, PBR,11,767.8 -"'lf: PACKER,11,781.1 eve eiia 11 I POOR BOY OVERSHOT; ': I111 11,861.6 _ I PACKER;11,891 2 'a °' I 1 NIPPLE,11,941.2 a WLEG,11,953.1 in PRODUCTION,34.4-12,394.3` •:,•• .-• OPEN HOLE FRAC;12,394.0 OPEN HOLE;12,394.0-16,985.0 Operations Summary (with Timelog Depths) :t CD2-53 t,titips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth MKS) 3/23/2016 3/23/2016 13.50 MIRU MOVE MOB P Swap rig to Generator power. 00:00 13:30 Disconnect all lines between modules, BD rockwasher lines. Move pipe shed©04:00 hrs. Remove beaverslide,skid rig floor and pull sub off of well @ 10:00 hrs- continue with move to CD2. 3/23/2016 3/23/2016 3.50 MIRU MOVE MOB P Sub arrived on location.Lay matting 13:30 17:00 and hurcultite.Spot rig over well.Had to remove back stair landing to cellar in order to clear adjacent well. Remaining modules arrived on location @ 14:30 3/23/2016 3/23/2016 3.00 MIRU MOVE RURD P Lower stomper begin skidding rig over 17:00 20:00 well center. 3/23/2016 3/24/2016 4.00 MIRU MOVE RURD P Lay hurculite and rig mats,spot pipe 20:00 00:00 shed,pit,pump,gen module. 3/24/2016 3/24/2016 6.00 MIRU MOVE RURD P Continue with Rig up.Setting out stair 00:00 06:00 ways and landing,complete rigging up handi berm,hooking up innerconnect and steam lines. 3/24/2016 3/24/2016 3.50 MIRU MOVE RURD P Complete hooking up pipe skate rail to 06:00 09:30 rig floor,test.Hook up all innerconnect lines&steam lines to sub. Hard line crew rigging up tiger tank and hard line.On hi-line as of 09:00 hrs. **Rig accept 09:30** 3/24/2016 3/24/2016 3.50 MIRU WELCTL RURD P Begin taking on fluid,spot kill tank. 09:30 13:00 Call out FMC,bring lubricator up to the rig floor. 3/24/2016 3/24/2016 1.50 MIRU WELCTL MPSP P PJSM-test lubricator to 1000 psi.Pull 13:00 14:30 BPV.500 psi below BPV. 3/24/2016 3/24/2016 4.50 MIRU WELCTL BOPE P C/O BOPE with 3.5"X 6"VBR in both 14:30 19:00 top&bottom,rigging up hard line and choke to kill tank. 3/24/2016 3/24/2016 0.50 MIRU WELCTL SFTY P Hold Pre-spud meeting with crew. 19:00 19:30 3/24/2016 3/24/2016 0.50 MIRU WELCTL SEQP P Pressure test mud lines to 3,000 psi. 19:30 20:00 Circulate seawater to tiger tank and test to 2,500 psi. 3/24/2016 3/24/2016 2.50 MIRU WELCTL KLWL P Pump 50 bbls of seawater down the IA 20:00 22:30 taking returns up the tubing to the tiger tank at 2 bpm,475 psi.Shut down pump and line up to pump down the tubing taking returns up the IA to the tiger tank.Stage up to 5 bpm at 1,120 psi.Monitor bbls pumped and bbls returned,pumped 496 bbls,returned 495 bbls.Shut down pump,bleed off lines and allow well to U-tube. 3/24/2016 3/24/2016 1.00 MIRU WELCTL KLWL P Allow well to U-tube.Open up well and 22:30 23:30 observe flow from the tubing and static from the IA.Shut in and continue to U- tube. 3/24/2016 3/25/2016 0.50 MIRU WELCTL OWFF T Open up well for 30 minutes no flow 23:30 00:00 test.Observe minimal flow from the tubing at a decreasing rate,continue to monitor. 3/25/2016 3/25/2016 1.50 MIRU WELCTL OWFF T Continue to monitor well,slight flow/ 00:00 01:30 drip from tubing side. Page 1/17 Report Printed: 5/10/2016 �f 4. Operations Summary (with Timelog Depths) y CD2-53 ConocoPhillips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation OMB) End Depth(ftKB)' 3/25/2016 3/25/2016 1.25 MIRU WELCTL CIRC T Reverse circulate tubing volume at 2 01:30 02:45 bpm 150 psi. 3/25/2016 3/25/2016 0.50 MIRU WELCTL OWFF P Observe well'and static.Tubing on a 02:45 03:15 slight vaccume. 3/25/2016 3/25/2016 0.50 MIRU WELCTL RURD P RD squeeze manifold. 03:15 03:45 3/25/2016 3/25/2016 1.00 MIRU WHDBOP MPSP P Install BPV, test 1000 psi from below. 03:45 04:45 3/25/2016 3/25/2016 2.00 MIRU WHDBOP NUND P ND tree.SIMOPs Begin loading and 04:45 06:45 strapping DP. 3/25/2016 3/25/2016 3.00 MIRU WHDBOP NUND P NUBOPE.Hook up OA valve-180 psi 06:45 09:45 on OA-bleed down to bleed trailer, leave open. IA fluid packed. 3/25/2016 3/25/2016 4.25 MIRU WHDBOP NUND P Hook up choke and kill lines. 09:45 14:00 3/25/2016 3/25/2016 2.00 MIRU WHDBOP NUND P M/U&run in 3 1/2"TJ-open lower 14:00 16:00 ram door to inspect with 2"clearance. Increase closing pressure to 2500 psi on upper 3 1/2"X 6"VBR's as per Hydril recommendations-function test 6 times to break in. 3/25/2016 3/25/2016 2.00 MIRU WHDBOP RURD P Fill stack with fresh water and purge 16:00 18:00 out air. MU TIW and Drat Valve,MU test blank to top drive.MU XO to test joint. Body test.Start BOPE test witnessed by AOGCC-Johnnie Hill. 3/25/2016 3/26/2016 6.00 MIRU WHDBOP BOPE P 1) Test Annular to 250/2500 18:00 00:00 PSI with 3-1/2"test joint 2) Test Upper 3'V2' x 6"VBR's, Upper Kill line and Upper IBOP 3) Test Lower 3'/i'x 6"VBR's, Lower Kill line and Lower IBOP 4) Upper pipe rams with 5-1/2" test joint,Choke valves#1,#12,#13, #14 5) Test Choke Valves#9,#11 and HCR Kill 6) Test Super choke flow through 7) Test Choke valves#5,#8, #10 and Manual Kill 8) Test Choke Valve#4,#6,#7 and 4 1/2"Dart Valve 4"XT39 9) Test Choke line Manual valve flow through 10) Test Choke Valve#2 and TIW Valve 4"XT-39 FOSV 11) Test Choke valve#3 12) Test HCR Choke Page 2/17 Report Printed: 5/10/2016 Operations Summary (with Timelog Depths) mon , 4 s, CD2-53 ComicoPhitlips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr),' Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB); 3/26/2016 3/26/2016 1.50 MIRU WHDBOP BOPE P 13) Test Manual Choke 00:00 01:30 14) Test Lower 3'/2'x 6"VBR's with 5-1/2"test joint 15) Test Annular to 250/2500 PSI with 5-1/2"test joint 16) Test Blind Rams All tests other than annular tested to 250/3000 PSI as per Permit/Sundry. Perform Koomey test with initial pressure at 2950 PSI.Function rams to closed position.Allow pressure to finalize.Starting test Koomey pressure @ 1800 PSI.Initial 200 PSI increase in 17 Seconds,with a final 2950 PSI obtained in 71 seconds.Observed 5 nitrogen bottles with an average pressure of 2650 PSI. All H2S and Combustible gas alarms tested with audible and light alarms. Test witnessed by AOGCC rep— Johnnie Hill 3/26/2016 3/26/2016 1.50 MIRU WHDBOP RURD P RD BOP testing equipment.Blow 01:30 03:00 down all lines and line up BOPE for normal opertaions.Pull blanking plug. 3/26/2016 3/26/2016 3.00 COMPZN RPCOMP MPSP P Pull BPV,well static.Terminate 03:00 06:00 control line.M/U tubing hanger, BOLDS. 3/26/2016 3/26/2016 1.00 COMPZN RPCOMP RURD P P/U Bales extensions prior to P/U 06:00 07:00 tubing hanger and completion string. M/U TD. 3/26/2016 3/26/2016 2.00 COMPZN RPCOMP PULL P Pull tubing hanger broke over @ 07:00 09:00 122K,Continue pulling string broke over @ 166K cut was not 100%clean, jarred during break over. Lay down tubing Hanger.Set up to pump down tubing to clean up well prior to POOH. 3/26/2016 3/26/2016 1.00 COMPZN RPCOMP CIRC P Circulate 8 BPM down tubing up IA- 09:00 10:00 1750 psi.Pumped 430 bbls till well cleaned up,roughly 40 bbls of brine came across shakers @ 380 bbls away. Take SPR with SW around Pump 1 =20 spm/90 psi /30 spm= 220 psi Pump 2=20 spm/90 psi/30 spm= 220 psi 3/26/2016 3/26/2016 0.50 COMPZN RPCOMP OWFF P Flow check for 15 mins-good. PJSM 10:00 10:30 for laying down and standing back 3 1/2"tubing 3/26/2016 3/26/2016 2.00 COMPZN RPCOMP PULL P TOOH with tubing-P/U weight 117K. 11,250.0 10,310.0 10:30 12:30 Lay down first 3 joints,begin standing back and strapping the next 100 stands. 3/26/2016 3/26/2016 1.00 COMPZN RPCOMP SFTY P Pre-spud meeting with Grants crew. 10,310.0 10,310.0 12:30 13:30 3/26/2016 3/26/2016 1.50 COMPZN RPCOMP PULL P Continue TOOH racking back 3-1/2" 10,310.0 8,990.0 13:30 15:00 de-completion.Lay down SSSV. RD spooler. PU weight 112K. Page 3/17 Report Printed: 5/10/2016 Y'. 41 Operations Summary (with Timelog Depths) � . CD2-53 c: acoPhiilips '' Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKSj'< 3/26/2016 3/26/2016 5.00 COMPZN RPCOMP PULL P Continue to POOH racking back 3-1/2" 8,990.0 1,850.0 15:00 20:00 completion from 8,990'to 1,850', 100 total stands racked back.Strap tubing in derrick.Observed calc hole fill. Tubing in derrick 9,318,08'. 3/26/2016 3/26/2016 2.50 COMPZN RPCOMP PULL P Lay down tubing from 1,850'to 1,850.0 0.0 20:00 22:30 surface.Strap all joints and jewelery. Monitor well on trip tank and observe calculated hole fill.Lay down a total of 54 joints plus pup joints on GLM and cut joint.Recovered 13.74'of the cut joint. 3/26/2016 3/26/2016 0.50 COMPZN RPCOMP RURD P Clean and clear floor.RD casing 0.0 0.0 22:30 23:00 equipment. 3/26/2016 3/27/2016 1.00 COMPZN RPCOMP BHAH P Pick up Baker tools for BHA.Change 0.0 23:00 00:00 out elevators. 3/27/2016 3/27/2016 0.50 COMPZN RPCOMP RURD P RIH with Wear Ring and set across 00:00 00:30 wellhead, 10.75"OD 9"ID. 3/27/2016 3/27/2016 2.50 COMPZN RPCOMP BHAH P PJSM with Baker rep.Make up BHA 0.0 430.0 00:30 03:00 #1 as per Baker from surface to 430'. BHA weight 53K. 3/27/2016 3/27/2016 9.00 COMPZN RPCOMP PULD P Pick up drillpipe and single in the hole 430.0 6,500.0 03:00 12:00 from 430' Rabbit each joint off the skate.Monitor well on trip tank.6500 ft up weight 120K,down weight 95K 3/27/2016 3/27/2016 0.50 COMPZN RPCOMP SVRG P Service TD,iron roughneck, 6,500.0 6,500.0 12:00 12:30 drawworks. 3/27/2016 3/27/2016 8.50 COMPZN RPCOMP PULD P Continue singling in DP from 6,500'to 6,500.0 11,204.0 12:30 21:00 11,204'. PU 205K,SO 113K. 3/27/2016 3/27/2016 0.50 COMPZN RPCOMP FISH P Kelly up on joint 343 at 11,237'and 11,204.0 11,260.0 21:00 21:30 pump at 1 bpm,500 psi.PU 206K,SO 114K.Engage fish at 11,260'.PU 210K,slack off and verify fully engaged.Pick up to 11,237'.PU 210K with 5K drag, 3/27/2016 3/27/2016 0.50 COMPZN RPCOMP PULD P Lay down joint 343 and blow down top 11,260.0 11,237.0 21:30 22:00 drive. 3/27/2016 3/28/2016 2.00 COMPZN RPCOMP TRIP P POOH from 11,237'to 9,535'.Monitor 11,237.0 9,535.0 22:00 00:00 well on trip tank.Max running speed 60-90 ft/min and max overpull 40K as per Baker rep. Initial PU 215K,final PU 200K. 3/28/2016 3/28/2016 7.00 COMPZN RPCOMP TRIP P TOOH racking back drillpipe from 9,535.0 1,000.0 00:00 07:00 9,535'to 1,000'. Initial PU 200K. Monitor well on trip tank. Max running speed 60-90 ft/min and max overpull 40K as per Baker rep.SIMOPS-load 64 joints of 3-1/2"563 tubing in the pipe shed and prep to be drifted. 3/28/2016 3/28/2016 3.50 COMPZN RPCOMP MPSP P PJSM.Change over handling tools. 1,000.0 1,090.0 07:00 10:30 MU storm packer and RIH to set at 90' MD.Test packer to 900 psi and charted for 10 minutes. RD testing equipment and drain stack. 3/28/2016 3/28/2016 0.50 COMPZN RPCOMP RURD P Pull wear bushing. 1,090.0 1,090.0 10:30 11:00 3/28/2016 3/28/2016 2.00 COMPZN RPCOMP BOPE P PJSM.Change Upper pipe rams to 1,090.0 1,090.0 11:00 13:00 solid body 2-3/8". Page 4/17 Report Printed: 5/10/2016 • • 0 0 Operations Summary (with Timelog Depths) a CD2-53 ifli Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/28/2016 3/28/2016 2.50 COMPZN RPCOMP BOPE P PJSM.Set Test plug.RU and test 2- 1,090.0 1,090.0 13:00 15:30 3/8"rams to 250/3,000psi and chart for 5 minutes. Blow down and rig down testing equipment.Pull test plug. 3/28/2016 3/28/2016 2.00 COMPZN RPCOMP MPSP P PJSM.MU storm packer retrieval tool. 1,090.0 1,000.0 15:30 17:30 RIH to 90'and engage packer.Open valve and well was static.Release packer and POOH laying down packer and setting tools. 3/28/2016 3/28/2016 0.50 COMPZN RPCOMP TRIP P POOH 4"DP from 1,000'to to 741'. 1,000.0 741.0 17:30 18:00 3/28/2016 3/28/2016 0.50 COMPZN RPCOMP RURD P PU handling equipment for BHA for 2- 741.0 741.0 18:00 18:30 3/8"patch. 3/28/2016 3/28/2016 0.50 COMPZN RPCOMP TRIP P POOH from 741'to 430'.PU 52K. 741.0 430.0 18:30 19:00 Monitor well on trip tank at HWDP, well is static. 3/28/2016 3/28/2016 1.50 COMPZN RPCOMP BHAH P PJSM.LD HWDP and BHA as per 430.0 204.0 19:00 20:30 Baker rep. 3/28/2016 3/28/2016 2.00 COMPZN RPCOMP PULL P RU Single joint elevators and power 204.0 0.0 20:30 22:30 tongs.LD 2-3/8"patch to pipe shed for a total of 17 joints and seal assembly. Total fish length 525'. Monitor well and confirm static once out of the hole. 3/28/2016 3/28/2016 0.50 COMPZN RPCOMP RURD P Clean and clear rig floor.Prep for next 0.0 0.0 22:30 23:00 BHA run. 3/28/2016 3/29/2016 1.00 COMPZN RPCOMP BHAH P PJSM on BHA#2.MU BHA as per 0.0 221.0 23:00 00:00 Baker rep and RIH with 3-1/2"EUE tubing from the derrik.TIH to 221'. LD top single on stand#2 and bottom single on stand#3,make corrections on pipe tally. 3/29/2016 3/29/2016 2.00 COMPZN RPCOMP TRIP P RIH from 221 to 1,635'with 3-1/2" 221.0 1,600.0 00:00 02:00 EUE Tubing from the derrick.PU 54K SO 59K.Change out seal rings and inspect threads. Monitor well 3/29/2016 3/29/2016 2.00 COMPZN RPCOMP MPSP P M/U storm packer-RIH set 100'-test 1,600.0 1,600.0 02:00 04:00 1000 psi/10 mins 3/29/2016 3/29/2016 1.00 COMPZN RPCOMP BOPE P Suck out stack,set test plug,shut 1,600.0 1,600.0 04:00 05:00 blinds&bleed off Koomey. 3/29/2016 3/29/2016 3.00 COMPZN RPCOMP BOPE P Swap 2 3/8"Top rams to 3.5 X 6 VBR 1,600.0 1,600.0 05:00 08:00 3/29/2016 3/29/2016 2.50 COMPZN RPCOMP BOPE P PJSM-Test Upper VBR with 3.5& 1,600.0 1,600.0 08:00 10:30 5.5 test joints-250/3000 psi 3/29/2016 3/29/2016 1.50 COMPZN RPCOMP BOPE P PJSM-R/D test equipment.Pull test 1,600.0 1,600.0 10:30 12:00 plug,Set wear ring,P/U equipment, TIH 100'ft and pull storm packer. 3/29/2016 3/29/2016 1.00 COMPZN RPCOMP RURD P PJSM,R/U Doyon casing equipment 1,600.0 1,600.0 12:00 13:00 3/29/2016 3/29/2016 5.00 COMPZN RPCOMP TRIP P Trip in hole to 9625'with 3-1/2"tubing 1,600.0 9,625.0 13:00 18:00 from derrick. 3/29/2016 3/29/2016 1.50 COMPZN RPCOMP RURD P Clean and clear floor. Prep for 3-1/2" 9,625.0 9,625.0 18:00 19:30 563, P/U pups for space out. 3/29/2016 3/29/2016 3.00 COMPZN RPCOMP PULD P Pick up and single in with 3-1/2"563 9,625.0 11,228.0 19:30 22:30 tubing from pipe shed from 9625'to 11228'. Drift all tubing to 2.86", monitor well and observe calculated displacement. M/U torque to 3000 Ft- lbs, Up Wt=127k,Dn Wt=86k. Page 5/17 Report Printed: 5/10/2016 • ,,,,,, • Operations Summary (with Timelog Depths) i' rb =jam _ ,: CD2-53 CormacoPhiihps Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time- End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK6) End Depth MKS) 3/29/2016 3/29/2016 1.00 COMPZN RPCOMP PULD P P/U a joint of 4"drillpipe with 3 pup 11,228.0 11,228.0 22:30 23:30 joints of 3-1/2"563 below it(9.80', 5.90',3.89')in order to engage overshot with proper space-out for digital slickline rig up. 3/29/2016 3/30/2016 0.50 COMPZN RPCOMP CIRC P M/U top drive,establish circulation 11,228.0 11,228.0 23:30 00:00 with seawater,take SPRs. Pumping 5 BPM,660 PSI. 3/30/2016 3/30/2016 1.50 COMPZN RPCOMP CIRC P Pumping 40 Bbl viscous pill chasing 11,228.0 11,228.0 00:00 01:30 with seawater. Initial pump @ 5 BPM, 675 PSI. Increase to 7 BPM when viscous pill turns the corner. Returns clean up shortly after pill at surface. No losses observed while pumping. (SimOps,PJSM with Digital Slickline for R/U). 3/30/2016 3/30/2016 0.50 COMPZN RPCOMP FISH P Ready to engage overshot on tubing 11,228.0 11,248.0 01:30 02:00 stub. Up Wt=120M#,Dn Wt=91 M#. Online with pump at 4 BPM,450 PSI. Very slowly RIH,observe stub at 11248'. P/U,make certain of spaceout to get wireline as close to the floor as possible. Cut-lip guide won't engage first time,work 1-1/2 turns in pipe and RIH again. Fully engage overshot(4'),P/U to verify overpull. P/U to neutral weight plus 34M#overpull to put pup coupling just above floor to set slips. 3/30/2016 3/30/2016 1.00 COMPZN RPCOMP DSL P Break out pup and joint of drill pipe, 11,248.0 11,248.0 02:00 03:00 blow down top drive. RU floor valve, and X-O. 3/30/2016 3/30/2016 4.50 COMPZN RPCOMP DSL P Begin rigging up digital slickline.P/U 11,248.0 11,248.0 03:00 07:30 tool string. 3/30/2016 3/30/2016 1.00 COMPZN RPCOMP DSL P Stab riser onto wirelines valves. 11,248.0 11,248.0 07:30 08:30 pressure test to 1000 psi with diesel. 3/30/2016 3/30/2016 1.00 COMPZN RPCOMP DSL T Attempt to RIH,tagging up at FOSV or 11,248.0 11,248.0 08:30 09:30 just below.Try to work through obstruction.Pop off to inspect. 3/30/2016 3/30/2016 3.00 COMPZN RPCOMP DSL T Ice plug in 4ft pup up up through 11,248.0 11,248.0 09:30 12:30 rotary table to wireline valves on rig floor.Begin to steam to thaw out pup, stabbing valve and riser.Break off and install heater truck on lubricator above wireline valves to prevent freeze up higher on the string.Inspect BHA- Drift down through floor equipment, good drift.M/U connection. 3/30/2016 3/30/2016 0.50 COMPZN RPCOMP DSL T Test stack again to 1000 psi.-good 11,248.0 11,248.0 12:30 13:00 test. 3/30/2016 3/30/2016 4.00 COMPZN RPCOMP DSL P Open safety valve and RIH with DSL. 11,248.0 11,248.0 13:00 17:00 Engage fish with GR tool at 11,788'. Jar fish until free,begin POOH. Hung up in GLM,GR tool shears and POOH. 3/30/2016 3/30/2016 3.50 COMPZN RPCOMP DSL P At surface,re-pin tools and RIH to re- 11,248.0 11,248.0 17:00 20:30 engage fish. Engage and begin POOH with fish. Page 6/17 Report Printed: 5/10/2016 R 4I • • Operations Summary (with Timelog Depths) CD2-53 Conor illiips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time '- End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/30/2016 3/31/2016 3.50 COMPZN RPCOMP DSL P At 2600',DIGI SL stuck with fish. 11,248.0 11,248.0 20:30 00:00 Unable to move up or down,very little jar action. R/U to pump down pump-in sub with seawater. Establish circulation down tubing with good returns. Pump.4 BPM,64 PSI. Increase pump rate to 1 BPM,230 PSI. DIGI SL works wire while pumping. While attempting to shear free to come out of hole,fish comes free. Work fish to surface with some hang ups along the way. 3/31/2016 3/31/2016 1.75 COMPZN RPCOMP DSL T At surface,close TIW valve and P/U 11,248.0 11,248.0 00:00 01:45 lubricator. Lay down lower patch assembly(mule shoe pup,R-nipple, pup,packer,and seal receptacle). All accounted for except packer is missing 1 and 1/2 seal elements. (Out of 3 total). Make up string shot toolstring. 3/31/2016 3/31/2016 3.50 COMPZN RPCOMP DSL P RIH with stringshot,get on depth,tie 11,248.0 11,248.0 01:45 05:15 in and fire string shot from 11,857'to 11,868'. POOH with string shot. 3/31/2016 3/31/2016 3.50 COMPZN RPCOMP DSL P Changed tools and RIH with Brush 1 1,248.0 11,248.0 05:15 08:45 and gauge ring to 11866'.POOH with Brush and gauge ring. 3/31/2016 3/31/2016 6.25 COMPZN RPCOMP DSL P Changed out tools for Chemical 11,248.0 11,248.0 08:45 15:00 Cutter.PJSM and Made up CC. RIH and put CC on Depeth.Made Cut @ 11,866'.Some pumping was required to get down with tools below the Packer.POOH and laid down tools. 3/31/2016 3/31/2016 2.00 COMPZN RPCOMP DSL P Lay down digital slickline BHA and 11,248.0 11,248.0 15:00 17:00 chemical cutter. R/D wireline lubricator and equipment. 3/31/2016 3/31/2016 1.00 COMPZN RPCOMP PULL T M/U XO's to tubing,attempt to pull 11,248.0 11,248.0 17:00 18:00 tubing. P/U to 166K with no movement. Bring on pumps at 6 BPM,875 PSI. Continue to work string to maximum of 190K,no movement. 3/31/2016 3/31/2016 0.50 COMPZN RPCOMP CIRC T Circulate well at 6 BPM,875 PSI. 11,248.0 11,248.0 18:00 18:30 3/31/2016 3/31/2016 1.00 COMPZN RPCOMP RURD T Blow down top drive and break down 11,248.0 11,248.0 18:30 19:30 X-O's. 3/31/2016 3/31/2016 4.00 COMPZN RPCOMP DSL T RU DIGI-SL lubricator and equipment, 11,248.0 11,248.0 19:30 23:30 pressure test slickline equipment in lubricator to 1000 PSI,MU string shot BHA and go back to well with quick test sub. PT quick test and begin RIH with string shot. 3/31/2016 4/1/2016 0.50 COMPZN RPCOMP DSL T RIH with string shot. 11,248.0 11,248.0 23:30 00:00 4/1/2016 4/1/2016 2.50 COMPZN RPCOMP DSL T Continue to RIH with string shot. Get 11,248.0 11,248.0 00:00 02:30 on depth,tie in,and fire string shot from 11679'-11689'. POOH with string shot. 4/1/2016 4/1/2016 0.50 COMPZN RPCOMP DSL T At surface,swap out string shot for 11,248.0 11,248.0 02:30 03:00 chemical cutter. Page 7/17 Report Printed: 5/10/2016 so 0 x Operations Summary (with Timelog Depths)41q 02i? CD2-53 conoc ,ithaps Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time ra End Time Our(hr) Phase Op Code Activity Code Time.P-T-xOperation (ftKE) End.'Depth(ftK8),. 4/1/2016 4/1/2016 3.50 COMPZN RPCOMP DSL T RIH with chemical cutter to 11688'. 11,248.0 11,688.0 03:00 06:30 Get on depth,tie in,and fire chemical cutter. See good indication at surface. 1 4/1/2016 4/1/2016 1.75 COMPZN RPCOMP DSL T RD Wireline chem cutter and tools. 11,688.0 11,688.0 06:30 08:15 4/1/2016 4/1/2016 0.75 COMPZN RPCOMP RURD T Service draw works/CO Hyd hose. 11,688.0 11,688.0 08:15 09:00 RD X-over and wireline valves from rig floor. 4/1/2016 4/1/2016 2.00 COMPZN RPCOMP CIRC P P/U on pipe-122K up weight 90K 11,688.0 11,688.0 09:00 11:00 down.Sit right above cut and pump sweep around @ 8 bpm/240 psi.Total pumped 536 bbls.Saw light to med traces of sand mixed with schmoo over the shakers before and after sweep. lay down DSL equipment at the same time 4/1/2016 4/1/2016 1.00 COMPZN RPCOMP RURD P Clean up rig floor,set up Casing 11,688.0 11,688.0 11:00 12:00 Tongs. 4/1/2016 4/1/2016 1.00 COMPZN RPCOMP TRIP P TOOH racking back first 21 stands of 11,688.0 9,725.0 12:00 13:00 3 1/2"563 TBG to 9725' 4/1/2016 4/2/2016 11.00 COMPZN RPCOMP PULL P Lay down 3 1/2"EUE decompletion 9,725.0 1,488.0 13:00 00:00 string. 4/2/2016 4/2/2016 2.00 COMPZN RPCOMP PULL P Continue to pull and lay down 3-1/2" 1,488.0 440.0 00:00 02:00 EUE tubing,at surface with overshot. Lay down overshot. 4/2/2016 4/2/2016 1.50 COMPZN RPCOMP PULL P Pull 3-1/2"tubing fish(13 joints plus 2 440.0 0.0 02:00 03:30 cut joints.total=439.34')from overshot to cut at 11,688'. Chem cut looks good. 4/2/2016 4/2/2016 1.50 COMPZN RPCOMP RURD P Release overshot from fish. Clean 0.0 0.0 03:30 05:00 and clear rig floor. Load and process 12 joints HWDP. 4/2/2016 4/2/2016 2.50 COMPZN RPCOMP BHAH P PJSM-M/U BHA#3(overshot and 0.0 398.0 05:00 07:30 jars),UP WT=54K,DN WT=60K. 4/2/2016 4/2/2016 0.50 COMPZN RPCOMP TRIP P RIH with 4"DP on elevators to 966'. 398.0 966.0 07:30 08:00 4/2/2016 4/2/2016 1.50 COMPZN WHDBOP MPSP P M/U and RIH 90'with storm packer. 966.0 1,056.0 08:00 09:30 Set packer,and test to 1000 PSI. (10 minutes,charted). 4/2/2016 4/2/2016 2.00 COMPZN WHDBOP RURD P Pull wear bushing and install 5-1/2" 1,056.0 1,056.0 09:30 11:30 test joint. Rig up test equipment,M/U XT-39 FOSV&dart valve. Page 8/17 Report Printed: 5/10/2016 • Operations Summary (with Timelog Depths) CD2-53 ConocciPhinips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time< End Time Dur(hr)„ Phase. Op Code Activity Code Time P-T-x Operation (ftKB) End.Depth(ftKB) 4/2/2016 4/2/2016 5.50 COMPZN WHDBOP BOPE P Weekly BOPE test,witness waived by 1,056.0 1,056.0 11:30 17:00 AOGCC rep. Matt Herrera With 5-1/2"Test Joint: 1) Test Annular,CV's 1, 12, 13, 14,4"Kill Line,XT-39 Dart. 2) Test UPR 3-1/2"x 6"VBRs, CV's 9, 11,XT-39 FOSV,4"Kill in Mezzanine 3) Test CV's 7,8 4) Test CV's 6, 10 5) Test Super Choke&Man. Operated Choke 6) Test CV's 2,5&Manual Kill 7) Test HCR Choke 8) Test LPR 3-1/2"x 6"VBRs 9) Test Blinds,CV's 3,4,6 With 3-1/2"Test Joint: 10) Test Annual&Man.Choke Valve 11) Test UPR 3-1/2"x 6"VBRs, Upper IBOP 12) Test LPR 3-1/2"x 6"VBRs, Lower IBOP All tests other than annular tested to 250/3000 PSI as per procedure (Sundry states 2,500 PSI) Perform Koomey test with initial pressure at 2950 PSI. Function rams to closed position. Allow pressure to finalize. Starting test Koomey pressure @ 1700 PSI. Initial 200 PSI increase in 12 Seconds, with a final 3000 PSI obtained in 51 seconds. Observed 6 nitrogen bottles with an average pressure of 2350 PSI. 4/2/2016 4/2/2016 0.50 COMPZN WHDBOP RURD P R/D and B/D BOPE test. 1,056.0 1,056.0 17:00 17:30 4/2/2016 4/2/2016 0.50 COMPZN WHDBOP RURD P Pull Test Plug&Install 9"ID wear 1,056.0 1,056.0 17:30 18:00 bushing. 4/2/2016 4/2/2016 2.00 COMPZN WHDBOP MPSP P M/U storm packer retrieval tool. RIH 1,056.0 966.0 18:00 20:00 90',latch and release storm packer. L/D retrieval tool and storm packer. 4/2/2016 4/2/2016 0.50 COMPZN RPCOMP RURD P Clean and clear rig floor. 966.0 966.0 20:00 20:30 4/2/2016 4/3/2016 3.50 COMPZN RPCOMP TRIP P RIH from 966'to 4760'with 4"drill 966.0 4,760.0 20:30 00:00 pipe stands from derrick. 4/3/2016 4/3/2016 3.50 COMPZN RPCOMP TRIP P Continue running in hole with drill pipe 4,760.0 11,195.0 00:00 03:30 stands off derrick to 11,195'. DN WT =112M#,UP WT=190M#. 4/3/2016 4/3/2016 0.75 COMPZN RPCOMP RURD P Pre-jarring Top Drive inspection, 11,195.0 11,195.0 03:30 04:15 prepare to PU DP singles and continue in hole. 4/3/2016 4/3/2016 1.00 COMPZN RPCOMP PULD P Pick up drill pipe and single in hole. 11,195.0 11,687.0 04:15 05:15 Page 9/17 Report Printed: 5/10/2016 '�C{ 0 I rIt Operations Summary (with Timelog Depths) ,, CD2-53 xi, conocoph. imps Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code .:Activity Code Time P-T-X Operation . (ftKB) End Depth(ftKB); 4/3/2016 4/3/2016 2.25 COMPZN RPCOMP FISH P Record up weight 190K/down 122K. 11,687.0 11,691.0 05:15 07:30 Circ B/U @ 6 bpm 780 psi. P/U 10 ft pup and working joint,tag top of fish @ 11686'-work overshot down pumping 4 bpm,No-go out on fish 5ft down. 11,691'.P/U weight 240K. Jar 240K-straight pull 260K-reset down 115K Jar 250K-Straight pull 265K-reset down 115K Jar 265K-straigh pull 300K-seen movement-work down 115K Jar 265K-straight pull 300K-string moving up,fish confirmed on-free- drag 250K 4/3/2016 4/3/2016 0.50 COMPZN RPCOMP RURD P Break out 10 ft pup,Line back up to 11,691.0 11,866.0 07:30 08:00 pump sweep. 4/3/2016 4/3/2016 1.50 COMPZN RPCOMP CIRC P Set back down 3 ft off bottom,pump 11,866.0 11,866.0 08:00 09:30 25 bbl HI visc sweep,followed by 450 bbls of Sw.While pumping working string 60ft up/down,drag slowly decreasing while pumping. Monitor returns noticed pro-visc type material returning over shakers prior to sweep. Sand/schmoo returns over shaker with sweep.Pump 50 bbls over displacement-well cleaned up.Final Up weight 200K,Down 122K. 4/3/2016 4/3/2016 0.50 COMPZN RPCOMP OWFF P Monitor well for 30 mins.-PJSM for 11,866.0 11,866.0 09:30 10:00 TOOH with fish. 4/3/2016 4/3/2016 8.50 COMPZN RPCOMP TRIP P TOOH standing back DP. 5-10k# 11,866.0 199.0 10:00 18:30 drag all the way out of hole,monitor well(static). 4/3/2016 4/3/2016 2.00 COMPZN RPCOMP PULL P At surface with fish,lay down 178'of 3 199.0 0.0 18:30 20:30 -1/2"tubing fish(cut joint,GLM on pups,2 joints,sliding sleeve with fluted centralizers on pups, 1 joint,cut joint). Both cuts good. Break out and L/D bumper sub,jars,overshot. 4/3/2016 4/3/2016 1.50 COMPZN RPCOMP BHAH P Clear tools from BHA#3 off rig floor. 0.0 0.0 20:30 22:00 Load rig floor with BHA#4 tools,steam tools,load and process 6 joints of drill pipe in shed. 4/3/2016 4/4/2016 2.00 COMPZN WELLPR BHAH P P/U BHA#4(Dragtooth shoe,dressoff 0.0 85.0 22:00 00:00 mill,casing scraper,boot baskets,and magnets). 4/4/2016 4/4/2016 8.50 COMPZN WELLPR TRIP P Tripping in hole on stands from derrick 85.0 11,860.0 00:00 08:30 with BHA#4. 4/4/2016 4/4/2016 0.50 COMPZN WELLPR REAM P Stop 10ft above fish,Perform weight 11,860,0 11,860.0 08:30 09:00 checks,Up 216K,Dwn 111K, establish pump rates 5 bpm/693 psi, RPM 50-torque free spin 10K.Shut down. Page 10/17 Report Printed: 5/10/2016 0 • Operations Summary (with Timelog Depths) CD2-53 ilhi� 1 Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End,.Depth MKS) 4/4/2016 4/4/2016 1.00 COMPZN WELLPR REAM P Dry tag top of tubing stub/fill @ 11864' 11,860.0 11,874.0 09:00 10:00 RKB.P/U and begin working down over 3 1/2"tubing stub.Work a total of 10'ft down,noticed pressure indication while dressing up top of 3 1/2"tubing. Dress gently with reduced pump rates. Shut down pumps and stop rotation, dry run X 2 clear drifts,no weight bobbles. 10ft clean around 3 1/2" tubing stub.Success. 4/4/2016 4/4/2016 1.50 COMPZN WELLPR CIRC P Pump 70 bbl Hi visc sweep from 11,874.0 11,874.0 10:00 11:30 bottom to circulate well clean.Sand/fill returns,no metal filings on magnets. 4/4/2016 4/4/2016 0.75 COMPZN WELLPR TRIP P No flow check PJSM for slip and cut. 11,874.0 11,480.0 11:30 12:15 Pull 5 stands. 4/4/2016 4/4/2016 2.25 COMPZN WELLPR SLPC P Slip and cut drill line. 11,480.0 11,480.0 12:15 14:30 4/4/2016 4/4/2016 4.00 COMPZN WELLPR TRIP P TOOH standing back DP 11,480.0 8,607.0 14:30 18:30 4/4/2016 4/5/2016 5.50 COMPZN WELLPR RGRP T Bent the Service Track on the Top 8,607.0 8,607.0 18:30 00:00 Drive when it contacted the Elevators. Wind was blowing 30+MPH while POOH with DP.The New Crew were attempting to keep the Track clear with a tether but it contacted the Elevators and bent some of the Trays about 12 links up from where it attaches to the Top Drive.Repairs expected to take 4 to 6 Hours. 4/5/2016 4/5/2016 2.00 COMPZN WELLPR RGRP T Continue repair to energy track. 8,607.0 8,607.0 00:00 02:00 4/5/2016 4/5/2016 5.50 COMPZN WELLPR TRIP P TOOH standing back drill pipe. 8,607.0 85.0 02:00 07:30 Monitor displacement by TT,well static. 4/5/2016 4/5/2016 1.50 COMPZN WELLPR BHAH P Lay down BHA#4. Shoe and dress-off 85.0 0.0 07:30 09:00 mill both look good. Normal milling shavings on both magnets. 4/5/2016 4/5/2016 1.00 COMPZN WELLPR BHAH P Clean and clear rig floor of BHA#4. 0.0 0.0 09:00 10:00 4/5/2016 4/5/2016 0.50 COMPZN WELLPR BHAH X P/U test packer per Baker rep. 0.0 30.0 10:00 10:30 4/5/2016 4/5/2016 1.00 COMPZN WELLPR TRIP X RIH on drill pipe to 1,045'. UP WT= 30.0 1,045.0 10:30 11:30 57M#,DN WT=61 M#. 4/5/2016 4/5/2016 1.50 COMPZN WELLPR PRTS X Set test packer per Baker rep.at 1,045.0 1,045.0 11:30 13:00 1,043'. R/U to test above and below to 2,500 PSI,charted,for 10 minutes each: -Above packer:PASS -Below packer:FAIL 4/5/2016 4/5/2016 3.25 COMPZN WELLPR TRIP X TIH on drillpipe stands from derrick to 1,045.0 5,030.0 13:00 16:15 5,030'. UP WT=107M#,DN WT= 87M#. 4/5/2016 4/5/2016 2.25 COMPZN WELLPR PRTS X Set test packer at 5,023'. R/U test for 5,030.0 5,030.0 16:15 18:30 above and below. 2,500 PSI,charted, 10 mins: -Above packer:PASS -Below packer:FAIL Blow down test and rig down lines. Page 11/17 Report Printed: 5/10/2016 0 0 ,,,,,:,- -,,,,v;,,,,,,,,,, Operations Summary (with Timelog Depths) o 4- CD2-53 c.xto tihps Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr),', Phase Op Code'. Activity Code Time P-T-X Operation (ftKB) End,Depth(ftKB), 4/5/2016 4/5/2016 4.50 COMPZN WELLPR TRIP X TIH on drillpipe stands from derrick to 5,030.0 11,852.0 18:30 23:00 11,852'. UP WT=114M#,DN WT= 204M#. 4/5/2016 4/6/2016 1.00 COMPZN WELLPR PRTS X Set test packer at 11,852'(center of 11,852.0 11,852.0 23:00 00:00 element @ 11,846'),pick up to circulate fluid around,then slack back down. Rig up to test packer. Begin pressure test above packer. 4/6/2016 4/6/2016 0.50 COMPZN WELLPR PRTS X Test packer at 11,846',test above and 11,852.0 11,852.0 00:00 00:30 below to 2,500 PSI, 10 minutes, charted: -Above packer:Fail -Below packer:Pass Call Town Engineer and discuss. 4/6/2016 4/6/2016 1.50 COMPZN WELLPR PULD P POOH laying down single joints of 11,852.0 11,696.0 00:30 02:00 drillpipe to 11,696'. 4/6/2016 4/6/2016 0.75 COMPZN WELLPR PRTS X Test packer at 11,691' (center 11,696.0 11,696.0 02:00 02:45 element)test above and below to 2,500 PSI, 10 minutes,charted: -Above packer:Fail -Below packer:Pass 4/6/2016 4/6/2016 1.00 COMPZN WELLPR PULD P POOH laying down single joints of 11,696.0 11,475.0 02:45 03:45 drillpipe to 11,475'. 4/6/2016 4/6/2016 0.50 COMPZN WELLPR PRTS X Test packer at 11,470' (center 11,475.0 11,475.0 03:45 04:15 element)test above and below to 2,500 PSI, 10 minutes,charted: -Above packer:Pass -Below packer:Fail 4/6/2016 4/6/2016 2.75 COMPZN WELLPR TRIP X RIH on drillpipe to 11,569'. 11,475.0 11,569.0 04:15 07:00 4/6/2016 4/6/2016 0.50 COMPZN WELLPR PRTS X Test packer at 11,564' (center 11,569.0 11,569.0 07:00 07:30 element)test above and below to 2,500 PSI, 10 minutes,charted: -Above packer:Fail -Below packer:Pass 4/6/2016 4/6/2016 1.00 COMPZN WELLPR PULD P POOH laying down single joints of 11,569.0 11,505.0 07:30 08:30 drillpipe to 11,505'. 4/6/2016 4/6/2016 0.50 COMPZN WELLPR PRTS X Test packer at 11,500' (center 11,505.0 11,505.0 08:30 09:00 element)test above and below to 2,500 PSI, 10 minutes,charted: -Above packer: Pass -Below packer:Fail 4/6/2016 4/6/2016 0.50 COMPZN WELLPR RURD X Unset test packer per Baker rep. UP 11,505.0 11,505.0 09:00 09:30 WT=198M#,DN WT=117M#. 4/6/2016 4/6/2016 6.50 COMPZN WELLPR TRIP X TOOH standing back drill pipe from 11,505.0 17.0 09:30 16:00 11,505'to 17'. (Decision made to add a stacked packer to completion,will need to convery on drill pipe). 4/6/2016 4/6/2016 0.25 COMPZN WELLPR BHAH X Lay down test packer. 17.0 0.0 16:00 16:15 4/6/2016 4/6/2016 0.75 COMPZ1 RPCOMP RURD X Expedite 3-1/2"tubing and 5-1/2"liner 0.0 0.0 16:15 17:00 tools to rig floor. L/D 3-1/2"X-O's. 4/6/2016 4/6/2016 4.00 COMPZ1 RPCOMP WAIT X Wait on third party tools(New stacked 0.0 0.0 17:00 21:00 packer and accesories from Baker), SIMOPS:service top drive and iron roughneck. Page 12/17 Report Printed: 5/10/2016 ! 0 ' - . Y ., Operations Summary (with Timelog Depths) Ofir a CD2-53 4. Philfps Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start'Irma'' End Time Dur(Pr),', Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)' 4/6/2016 4/6/2016 2.00 COMPZ1 RPCOMP BHAH X M/U stacked packer completion per 0.0 112.0 21:00 23:00 Baker rep. Poor-Boy overshot,Pup Joint,Joint 1 3-1/2",2.813"X-Nipple (w/RHC),Joint 2 3-1/2",Pup, FHL packer, 10'PBR,Locator Sub,Pup. X -O'd to drillpipe. Verified seal rings, packer pins,OD's,and lengths. 4/6/2016 4/6/2016 0.50 COMPZ1 RPCOMP RURD X Rig up power tongs and handling 112.0 112.0 23:00 23:30 equipment. 4/6/2016 4/7/2016 0.50 COMPZI RPCOMP TRIP X Begin TIH with 4 stands of HWDP 112.0 763.0 23:30 00:00 from derrick,and begin singling in with 9 make-up joints from shed. 4/7/2016 4/7/2016 7.50 COMPZ1 RPCOMP RCST X TIH on drillpipe with FHL packer. Top 763.0 11,864.0 00:00 07:30 of no-go at 11,864'. UP WT=206M#, DN WT=117M#. 4/7/2016 4/7/2016 1.50 COMPZ1 RPCOMP CRIH X R/U to pump corrosion inhibited brine. 11,864.0 11,864.0 07:30 09:00 P/U to 11,854'and pump 15 BBL of 9.8 corrosion inhibited brine at 3 BPM, 215 PSI. Chase inhibited brine with 8.5 PPG seawater @ 5.5 BPM,755 PSI. 4/7/2016 4/7/2016 0.50 COMPZ1 RPCOMP PACK X Slack off to 2'above no-go at 11,862' 11,864.0 11,864.0 09:00 09:30 and drop ball and rod to set packer. Pressure up to 1,900 PSI to set FHL packer. Top of packer=11,781'. 4/7/2016 4/7/2016 0.50 COMPZ1 RPCOMP PRTS X Pressure test IA to 2000 PSI for 10 11,864.0 11,864.0 09:30 10:00 minutes. Charted,good. 4/7/2016 4/7/2016 0.50 COMPZ1 RPCOMP PACK X Pressure up on drill pipe to 2000 PSI 11,864.0 11,864.0 10:00 10:30 and P/U string to shear seals from PBR. Observe 5M#overpull. Top of PBR=11,767'. 4/7/2016 4/7/2016 0.50 COMPZ1 RPCOMP RURD X R/D and B/D testing and circ.lines. 11,864.0 11,864.0 10:30 11:00 4/7/2016 4/7/2016 0.25 COMPZ1 RPCOMP TRIP X P/U and pull seals out of stump to 11,864.0 11,822.0 11:00 11:15 11,822'and observe u-tubing from well. 4/7/2016 4/7/2016 0.75 COMPZ1 RPCOMP CIRC X Mix and Pump 12 BBL slug. B/D top 11,822.0 11,822.0 11:15 12:00 drive. 4/7/2016 4/7/2016 6.50 COMPZ1 RPCOMP PULD 'P POOH from 11,864'to 8,000'laying 11,822.0 8,000.0 12:00 18:30 down 4"drill pipe. Monitor displacement in TT. 4/7/2016 4/7/2016 0.50 COMPZI RPCOMP RURD X Install SPT sensor in stand pipe for 8,000.0 8,000.0 18:30 19:00 Schlumberger MPD/MWD equipment. 4/7/2016 4/8/2016 5.00 COMPZ1 RPCOMP PULD P Continue to POOH from 8,000'to 8,000.0 1,990.0 19:00 00:00 1,990'laying down 4"drill pipe. Monitor at TT. 4/8/2016 4/8/2016 1.75 COMPZ1 'RPCOMP PULD P Continue TOOH laying down drill pipe. 1,990.0 0.0 00:00 01:45 4/8/2016 4/8/2016 1.25 COMPZ1 RPCOMP BHAH X Lay down seals from PBR,clear rig 0.0 0.0 01:45 03:00 floor of Baker running equipment. 4/8/2016 4/8/2016 1.00 COMPZN WHDBOP RURD P Bring FMC equipment to floor,remove 0.0 0.0 03:00 04:00 wear ring,install 3-1/2'test joint. Page 13/17 Report Printed: 5/10/2016 • Operations Summary (with Timelog Depths) y # CD2-53 s`YS. C coPhiltfp Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End,Depth(ftKB): 4/8/2016 4/8/2016 5.00 COMPZN WHDBOP BOPE P Weekly BOPE test,witness waived by 0.0 0.0 04:00 09:00 AOGCC rep.Guy Cook. With 3-1/2"Test Joint: 1) Test Annular,CVs 1, 12, 13, 14,4"Kill Line,XT-39 Dart. 2) Test UPR 3-1/2"x 6"VBRs, CV's 9, 11,XT-39 FOSV,4"Kill in Mezzanine 3) Test CV's 8, 10,HCR Kill 4) Test CV's 6,7 5) Test Super Choke&Man. Operated Choke 6) Test CVs 2,5&Manual Kill 7) Test LPR 3-1/2"x 6"VBRs 8) Test Blinds,CV's 3,4,6 With 5-1/2"Test Joint: 9) Test Annual, HCR Choke, Upper IBOP 10) Test UPR 3-1/2"x 6"VBRs, Man Choke,Lower IBOP 11) Test LPR 3-1/2"x 6"VBRs All tests other than annular tested to 250/3000 PSI as per procedure (Sundry states 2,500 PSI) Perform Koomey test with initial pressure at 3000 PSI. Function rams to closed position. Allow pressure to finalize. Starting test Koomey pressure @ 1850 PSI. Initial 200 PSI increase in 16 Seconds, with a final 3000 PSI obtained in 72 seconds. Observed 6 nitrogen bottles with an average pressure of 2550 PSI. 4/8/2016 4/8/2016 1.00 COMPZN WHDBOP RURD P B/D top drive and test lines. Clean 0.0 0.0 09:00 10:00 and clear rig floor. 4/8/2016 4/8/2016 2.00 COMPZN RPCOMP RURD P Bring completion equipment to the rig 0.0 0.0 10:00 12:00 floor,rig up Doyon casing running equipment. 4/8/2016 4/8/2016 2.50 COMPZN RPCOMP PUTB P PJSM,P/U seal assemmbly with 0.0 455.0 12:00 14:30 locator sub,Baker 3-1/2'x 7"FHL packer,Camco 3-1/2"x 1"GLM, Baker SBE,and associated 3-1/2" 9.3#EUE-8RD tubing per detail to 455'. PU WT=50k,SO WT=50 k. 4/8/2016 4/8/2016 0.50 COMPZN RPCOMP RURD P C/O handling equipment to 5-1/2" 455.0 455.0 14:30 15:00 4/8/2016 4/9/2016 9.00 COMPZN RPCOMP PUTB P RIH with 5-1/2"Hydril-513 17#L-80 455.0 6,138.0 15:00 00:00 casing per detail to 6198'. 4/9/2016 4/9/2016 4.75 COMPZN RPCOMP PUTB P RIH with 5-1/2"Hydril-513 17#L-80 6,138.0 9,552.0 00:00 04:45 casing per detail from 6138'to 9350' 4/9/2016 4/9/2016 0.75 COMPZN RPCOMP PUTB P P/U X-O from 5-1/2"17#Hydril-513 to 9,552.0 9,552.0 04:45 05:30 5-1/2"15.5#Hydril-563. M/U X-O,set casing equipment for 15.5#Hydril 563. 4/9/2016 4/9/2016 3.25 COMPZN RPCOMP PUTB P Continue running 5-1/2"Hydril-513 9,552.0 11,767.0 05:30 08:45 17#L-80 casing per detail from 9350' to 11767'. P/U WT=220M#,S/O WT = 113M#. Page 14/17 Report Printed: 5/10/2016 • • Operations Summary (with Timelog Depths) R CD2-53 ConocoPhitlips ,v Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr). Phase Op Code Activity Code Time P-T-X Operation (IS(S) End,Depth(ttKS): 4/9/2016 4/9/2016 0.75 COMPZN RPCOMP HOSO P P/U 15'Pup with X-O's to head pin. 11,767.0 11,767.0 08:45 09:30 M/U 2"high pressure hose. Circ hose. 4/9/2016 4/9/2016 0.50 COMPZN RPCOMP HOSO P Wash down at 1BPM,80 PSI. Locate. 11,767.0 11,767.0 09:30 10:00 Pressure up to 230 PSI. Locate No- Go at 11,767'. 4/9/2016 4/9/2016 1.00 COMPZN RPCOMP CRIH P Reverse circulate corrosion inhibited 11,767.0 11,767.0 10:00 11:00 brine @ 2 BPM,400 PSI up to 2.8 BPM,655 PSI. Totalum ed=115 p p BBL. 4/9/2016 4/9/2016 0.75 COMPZN RPCOMP PACK P Set on depth and test annulus to 1000 11,767.0 11,767.0 11:00 11:45 PSI for 5 min,good. Pressure up on tubing to 2500 PSI. Observe packer set @ 1900 PSI. Hold 2000 PSI&pull 200M#over. Observe shear. 4/9/2016 4/9/2016 1.25 COMPZN RPCOMP HOSO P L/D 15'pup joint,joint 59,and joint 60 11,767.0 11,767.0 11:45 13:00 for space out. P/U 3.38'pup joint and join 60. 4/9/2016 4/9/2016 0.50 COMPZN RPCOMP THGR P M/U hanger and landing joint. R/U 11,767.0 11,767.0 13:00 13:30 circulation hose. 4/9/2016 4/9/2016 0.50 COMPZN RPCOMP THGR P Drain stack and B/D choke,kill,and 11,767.0 11,767.0 13:30 14:00 hole fill lines. 4/9/2016 4/9/2016 0.75 COMPZN RPCOMP THGR P Land hanger and RILDS. P/U= 11,767.0 11,767.0 14:00 14:45 205M#,S/O=155M#. Seal Assembly @ 11,774'. 4/9/2016 4/9/2016 2.75 COMPZN RPCOMP PRTS P R/U for tubing and annulus tests. Test 0.0 0.0 14:45 17:30 5-1/2"to 2500 PSI for 10 minutes,test 5-1/2"x 7"annulus to 2500 PSI for 30 minutes. 4/9/2016 4/9/2016 0.50 COMPZN RPCOMP RURD P B/D lines,break X-O's,L/D landing 0.0 0.0 17:30 18:00 joint. 4/9/2016 4/9/2016 2.00 COMPZN RPCOMP RURD P R/D power tongs,pumping/testing 0.0 0.0 18:00 20:00 equipment,clean and clear rig floor of casing running equipment,C/O power tongs to 3-1/2". 4/9/2016 4/9/2016 1.50 COMPZN WHDBOP MPSP P M/U RBP,X-O pup,3 joints of 3-1/2" 0.0 0.0 20:00 21:30 HYD-563 from derrick,X-O and head pin. RIH and set bridge plug at 103'. 2750 PSI to shear,R/D equipment, L/D running tool. 4/9/2016 4/9/2016 1.00 COMPZN WHDBOP MPSP P R/U and test RBP to 1000 PSI for 10 0.0 0.0 21:30 22:30 minutes. B/D and R/D lines. 4/9/2016 4/10/2016 1.50 COMPZN WHDBOP NUND P N/D BOP Stack. Remove flow riser, 0.0 0.0 22:30 00:00 kill line,choke line,break bolts on DSA,bring tubing spool to BOP deck. 4/10/2016 4/10/2016 1.00 COMPZN WHDBOP NUND P Continue to N/D BOPE stack. Stand 0.0 0.0 00:00 01:00 back stack on BOP landing,remove FMC wellhead adapter and DSA. 4/10/2016 4/10/2016 2.50 COMPZN WHDBOP WWSP P As per FMC reps,prep 5-1/2"casing 0.0 0.0 01:00 03:30 hanger seals,install new tubing spool on well head. Test seals to 5000 PSI for 10 minutes. Witness test. 4/10/2016 4/10/2016 4.00 COMPZN WHDBOP NUND P N/U BOPE stack. 0.0 0.0 03:30 07:30 4/10/2016 4/10/2016 2.00 COMPZN WHDBOP NUND P Install test plug and test BOPE breaks 0.0 0.0 07:30 09:30 after N/U to 250/2500 PSI for 5 minutes(charted,good). B/D lines and pull test plug. Page 15/17 Report Printed: 5/10/2016 0 • 0...!, - ,'',',", , Operations Summary (with Timelog Depths) 0 CD2-53 'hingps .gym Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur{hr) Phase Op Code Activity Code Time P-T-X Operation {ftKB) End Depth(ftKS) 4/10/2016 4/10/2016 2.50 COMPZN WHDBOP MPSP P R/U and pull bridge plug as per Baker 0.0 0.0 09:30 12:00 rep. First attempt saw 17k#overpull and released from plug. Screw into top drive&apply 2k#DN WT then pull bridge plug free. POOH L/D bridge plug and retrieving tool. 4/10/2016 4/10/2016 1.50 COMPZN RPCOMP RURD P R/U to run completion. 0.0 0.0 12:00 13:30 4/10/2016 4/10/2016 1.00 COMPZN RPCOMP PUTB P RIH with 3-1/2"9.3#EUE-8rd tubing 0.0 0.0 13:30 14:30 per detail. P/U seal assembly and GLM with associated pups and X-O. Hang up GLM attempting to go through tubing hanger. 4/10/2016 4/10/2016 1.75 COMPZN RPCOMP WAIT T Consult with Town engineer. Wait on 0.0 0.0 14:30 16:15 slim collars for bottom of GLMs, change out collar. 4/10/2016 4/11/2016 7.75 COMPZN RPCOMP PUTB P Continue to RIH with 3-1/2" 0.0 3,687.0 16:15 00:00 completion as per tubing detail to 3,687'. UP WT=68M#,DN WT= 63M#. 4/11/2016 4/11/2016 7.00 COMPZN RPCOMP PUTB P Continue to RIH with 3-1/2"EUE-8rd 3,687.0 9,022.0 00:00 07:00 completion as per tubing detail to from 3687'to 9022'. UP WT=114M#,DN WT=77M#. 4/11/2016 4/11/2016 1.75 COMPZN RPCOMP RURD P P/U Camco tools and R/U to run 9,022.0 9,022.0 07:00 08:45 control line. P/U Camco BP6i Nipple and hook up and test control line. 4/11/2016 4/11/2016 3.75 COMPZN RPCOMP PUTB P RIH with 3-1/2"Hyd-563 tubing from 9,022.0 11,321.0 08:45 12:30 derrick,from 9022'to 11321'. Running control line and clamps on each connection. UP WT=140M#, DN WT=80M#. 4/11/2016 4/11/2016 0.75 COMPZN RPCOMP RURD P R/U Bail extension,M/U X-O,head 11,321.0 11,321.0 12:30 13:15 pin,and cement hose. 4/11/2016 4/11/2016 1.25 COMPZN RPCOMP HOSO P Break circulation with 1BPM, 150 PSI, 11,321.0 11,333.0 13:15 14:30 locate at 11,333'. 4/11/2016 4/11/2016 2.00 COMPZN RPCOMP HOSO P L/D 3 joints for space out,M/U 3.83' 11,333.0 11,333.0 14:30 16:30 pup joint&joint#73, M/U hanger and landing joint. 4/11/2016 4/11/2016 0.75 COMPZN RPCOMP THGR P Terminate control line at tubing 11,333.0 11,333.0 16:30 17:15 hanger. 4/11/2016 4/11/2016 0.25 COMPZN RPCOMP HOSO P Locate after hanger and landing joint 11,333.0 11,333.0 17:15 17:30 made up to ensure proper space out. 4/11/2016 4/11/2016 0.50 COMPZN RPCOMP RURD P R/U to reverse circulate corrosion 11,333.0 11,333.0 17:30 18:00 inhibited brine. 4/11/2016 4/11/2016 2.00 COMPZN RPCOMP CRIH P Reverse circulate corrosion inhibited 11,333.0 11,333.0 18:00 20:00 brine(190 BBLS)pumping @ 4.5 BPM,2220 PSI. Chase with 15 BBLs sea water. 4/11/2016 4/11/2016 1.00 COMPZN RPCOMP THGR P Drain BOP stack,land hanger. UP 11,333.0 11,333.0 20:00 21:00 WT=140M#, DN WT=80M#. RILDS. 4/11/2016 4/11/2016 1.00 COMPZN RPCOMP PRTS P Test tubing to 3000 PSI for 15 11,333.0 11,333.0 21:00 22:00 minutes. Bleed tubing to 1500 PSI. Test IA to 2500 PSI for 30 minutes. Both tests good,charted. Bleed IA and tubing to 0 PSI. Pressure up to shear SOV(GLM#3),see shear at 1900 PSI. Page 16/17 Report Printed: 5/10/2016 • • Operations Summary (with Timelog Depths) .1.-. ikiiiitetis CD2-53 ConocoPhiilips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P=T-X Operation (EKE) End Depth(ftKB) 4/11/2016 4/11/2016 0.50 COMPZN RPCOMP OWFF P Monitor well for 30 minutes. 0.0 0.0 22:00 22:30 4/11/2016 4/11/2016 0.50 COMPZN RPCOMP RURD P R/D pumping equipment,pull landing 0.0 0.0 22:30 23:00 joint,B/O and L/D X-O. 4/11/2016 4/11/2016 0.50 COMPZN WHDBOP MPSP P Per FMC rep.,set BPV and test in 0.0 0.0 23:00 23:30 direction of flow to 1000 PSI. 10 minutes,charted. 4/11/2016 4/12/2016 0.50 COMPZN WHDBOP OTHR P Clean and clear rig floor of tubing 0.0 0.0 23:30 00:00 running equipment. 4/12/2016 4/12/2016 0.50 COMPZN WHDBOP OTHR P Clean and clear rig floor. 0.0 0.0 00:00 00:30 4/12/2016 4/12/2016 1.50 COMPZN WHDBOP NUND P N/D BOP Stack. L/D riser,remove 0.0 0.0 00:30 02:00 choke hose,kill hose,and Dutch riser nipple. 4/12/2016 4/12/2016 2.50 COMPZN WHDBOP SVRG P Perform BWM on BOPE. 0.0 0.0 02:00 04:30 4/12/2016 4/12/2016 1.00 COMPZN WHDBOP NUND P Finish N/D BOP,rack back on stump, 0.0 0.0 04:30 05:30 and remove DSA. 4/12/2016 4/12/2016 3.00 COMPZN WHDBOP NUND P N/U lower section of tree,terminating 0.0 0.0 05:30 08:30 control lines through tree flange. 4/12/2016 4/12/2016 0.50 COMPZN WHDBOP PRTS P Pressure test void and hanger seals to 0.0 0.0 08:30 09:00 250/5,000 PSI for 10/10 minutes- good test. 4/12/2016 4/12/2016 1.25 COMPZN WHDBOP NUND P Remove old horizontal flow valves 0.0 0.0 09:00 10:15 from wellhead and N/U upper section of tree. 4/12/2016 4/12/2016 1.75 COMPZN WHDBOP PRTS P Fill tree with diesel and pressure test 0.0 0.0 10:15 12:00 to 250/5,000 PSI for 5/10 minutes- good test. 4/12/2016 4/12/2016 1.00 COMPZN WHDBOP FRZP P Pull TWC and R/U to freeze protect 0.0 0.0 12:00 13:00 well with LRS. 4/12/2016 4/12/2016 2.00 COMPZN WHDBOP FRZP P Freeze protect well with 56 BBLS 0.0 0.0 13:00 15:00 diesel with LRS, 1.5 BPM, ICP 1,050 PSI/FCP 1,300 PSI. Open up IA to tubing and allow diesel to U-tube until equalized. 4/12/2016 4/12/2016 0.25 COMPZN WHDBOP FRZP P Blow down and rig down freeze 0.0 0.0 15:00 15:15 protect lines. 4/12/2016 4/12/2016 0.25 COMPZN WHDBOP MPSP P Install BPV. 0.0 0.0 15:15 15:30 4/12/2016 4/12/2016 2.50 DEMOB MOVE RURD P Secure well and prepare for move to 0.0 0.0 15:30 18:00 3S-613.OA=200 PSI,Lower IA=0 PSI,Upper IA=0 PSI,Tubing=0 PSI,Control line=1,500 PSI. Rig released at 18:00 hrs. Page 17/17 Report Printed: 5/10/2016 WNSOD CD2-53 IConocoPhillips 4Well Attrib Max Ang D TD AO' 1).: Wellbore API/DWI Field Name Wellbore Status ncl r) MD(ftKB) Act Btm(ftKB) cillps 501032049400 ALPINE PROD 95-66 16,557.78 16,985.0 ... Comment H2S(ppm) Date Annotation End Date KB-GM(k) Rig Release Date CO2-55 5/9120163.46:37 PM SSSV:NIPPLE Last WO: 4/12/2016 43.83 7/16/2004 Vertical xhama4p..(acloal) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;30.3- Last Tag:RKB 12,086.0 6/29/2011 Rev Reason:WORKOVER;GLV C/O;SET ISO lehallf 5/3/2016 r'fr. SLEEVE I Casing Strings HANGER:328 {�L =� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.052 37.0 114.0 114.0 62.40 H-40 WELDED 31,7 j Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 36.7 3,393.7 2,370.7 36 00 J-55 BTC Casing Description OD(in) ID I n) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 34.4 12,394.3 7,205.3 26.00 L-80 BTCM NY li� ! �,Y4C Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(1. Grade Top Thread OPEN HOLE 6 1/8 12,394.0 16,985.0 7,200.3 4 Tubing Strings Tubing DescriptionString Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(IbI/ft) Grade Top Connection UPPER I 31/2 2.992 30.3 11,337.1 6,741.7 9.30 L-80 EUE m COMPLETION 3.5" 1 CONDUCTOR;37.0-114.0 ; Completion Details 11- Nominal ID X0 Threads;2,289.7 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 7E 30.3 30.3 0.00 HANGER FMC 11"x 3 1/2"TC-1A-EMS Tubing Hanger 2.992 NIPPLE;2,291.61 i. 2 291 6 1,794.6 59.83 NIPPLE Camco 31/2"x 2.813"DS PROFILE BP 61 Nipple wl 2.812 SLEEVE;2,292.0 ift) PP Isolation Sleeve SN:HTN-3 xo Torsade;2,294.6 11,307.1 6,725.3 57.03 LOCATOR Baker GBH-22 Locator Sub(Spaced out 7') 2.992 11,307.6 6,725.6 57.03 SEAL ASSY +Baker 80-40 20'Seal Assembly(Total Length-29.50') 2.980 Tubing Description String Ma...ID lin) Top(ftKB) Set Depth(ft.J Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection LOWER 51/2 4.813 32.8 11,778.1 6,984.1 17.00 L-80 Hyd 513 COMPLETION 5.5"x 3.5" Completion Details SURFACE;36.7-3,393.7 � Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) XO Threads;5,283.5 i 32.8 32.8 0.00 HANGER FMC Casing hanger 11"x 5-1/2"UH-1A-EMS 4.900 GAS LIFT;5,293.0 11,313.9 6,729.0 56.99 XO Reducing 5-1/2"17#L-80 Hyd 513 Box XO 5"Hyd 521 Box locator 4.400 XO Threads;5,299.5 Coupling 11,325.9 6,735.6 56.92 SBE Baker 80-40 20'SBE 5"Hyd 521 Pin XO 4-1/2"Hyd 4.000 XO Threads,10,491.4ir 521 Box GAS LIFT;10,4952 r 11,345.0 6,746.0 56.81 XO Reducing 4-1/2"12.6#L-80 Hyd 521 Pin XO 3-1/2"9.3#EUE-8rd 2.900 XO Threads;10,501.7 Pin 1111 11,432.2 6,794.0 56.44 LOCATOR Baker GBH-22 Locator Sub 2.990 XO Threads;11,256.6 GAS LIFT;11,280.3 1' 11,433.2 6,794.6 56.44 SEAL ASSY Baker 80-40 20'Seal Assembly(Spaced out 7.14'from 2.990 f full located) XO Threads;11,266.8 11,440.3 6,798.5 56.42 PBR Baker 80-40 20'PBR 2.990 11,463.4 6,811.3 56.37 PACKER Baker 7"x 3-1/2"FHL Retrievable Packer 2.980 LOCATOR;11,307.1lir 11,506.3 6,835.1 56.41 NIPPLE HES 2.813"X Nipple 2.813 E 11,765.4 6,977.2 57.14 LOCATOR Baker GBH-22 Locator Sub(overall length.99') 2.990 XO Reducing;11,313.9 I 11,766.3 6,977.7 57.14 SEAL ASSY Baker 80-40 10'Seal Assembly(inside of PBR 9.0') 2.990' SEAL ASSY;71,307.6 Tubing Description Strin Ma...ID To ftKB )Set Depth(k..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection SBE;11,325.9 . LOWERS P I g (in) 1 P(ftKB) 1 ) LOWER STACKER 31/2 2.992 11,767.8 11,869.4 7,031.1 9.30 L-80 EUE-m III Completion Details Nominal ID Top(ftKB) Top)TVD)(ftKB) Top Incl(°) Item Des Com (in) 11,767.8 6,978.5 57.15 PBR Baker 80-40 10'PBR 2.970 GAS LIFT;11,384.1 I.,- 11,781.1 6,985.7 57.38 PACKER Baker 7"x 3-1/2"FHL Retrievable Packer 2.920 f' 11,822.4 7,007.5 58.90 NIPPLE HES 2.813"X Nipple 2.813 11,861.6 7,027.3 60.34 POOR BOY Baker Poor-Boy Overshot w/half muleshoe(7.35' 3.610 OVERSHOT swallow) LOCATOR;11,432.2 Mg Tubing Description 'String Me...'ID(in) 'Top(61(0) SetDepth(ft..]Set Depth)ND)I...IWt(Ib/ft) I Grade 'Top Connection SEAL ASSY;11,433.2 = TUBING 4.5"x3.5" I 31/2 2.992 11,8694 11,9536 7,070.6 9.30 L-80 EUE-mod PBR;11,44°_3 - - Completion Details PACKER;11,463.4 Nominal ID Top(MB) Top(ND)(ftKB) Top Incl Cl Item Des Com (in) 11,891.2 7,041.7 61.39 PACKER BAKER SAB-3 PACKER wl MILLOUT EXTENSION 3.875 MI 11,941.2 7,065.0 63.11 NIPPLE HES XN NIPPLE NO GO w/2.812"POLISH BORE 2.750 III 11,953.1 7,070.3 63.52 WLEG BELL COLLAR WIRELINE GUIDE 3.000 111. LOCATOR;11,765.3 MIN Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) _ Top(ND) Top Incl SEAL ASSY;11,766.3, - Top(ftKB) (060) (°) Des Com Run Date ID lin) PBR;11,767.8 - 2,292.0 1,794.8 59.82 SLEEVE 31/2"G-FN ON 2.81"ISO SLEEVE 4/30/2016 1.765 PACKER;11,781.1 Stimulations&Treatments Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Corn 12,394.0 16,985.0 7,205.2 7,200.3 OPEN HOLE 3/6/2006 Frac Job completed with 308014#behind pipe and FRAC 308054#total pumped Mandrel Inserts POOR BOY OVERSHOT, 11,861.6 at g ti R on PACKER;11,891.2 Top(TVD) Valve Latch Port Size TRO Run "' _r)) N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 7 1 5,293.0 3,501.2 Camco KBG-2- 1 GAS LIFT GLV BTM 0.188 1,846.0 4/29/2016 BOT 9 TOM NIPPLE;11,941.2 LATC H WLEG;11,953.1 ONL 2 10,495.2 6,281.8 Camco KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 4/16/2016 gOT 9 TOM LAIC H ONL Y PRODUCTION;34.4-12,394.3, t.... OPEN HOLE FRAC;12,394.0 OPEN HOLE;12,394.0-16,985.0 WNS 4111,00 • CD2-53 ConocoPhillips :, . '` Alaska.Inc. • ,., 002-53,5/9/2016 3:48:38 PM Vertical schematic(actual) HANGER.30.3—.. of. Mandrel Inserts HANGER:32.8 L St ati rik j Top(TVD) Valve Latch Port Size TRO Run ./N Top(MB) (RKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 3 11,260.3 6,699.9 Camco KBG-2- 1 GAS UFT OV BTM 0.313 0.0 4/29/2016 BOT 9 TOM '' LAIC ONL 4 11,384.1 6,767.5 Camco KBG-2- 1 GAS LIFT DMY BK 0.000 0.0 3/26/2016 Y 9 Notes:General&Safety CONDUCTOR;37.0-114.0 End Date Annotation 7/18/2004 NOTE.TREE. FMC 4-1/16 5K-TREE CAP CONNECTION' 7"OTIS XO Threads;z,209.7 j11. 9/3/2010 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE;2,291.6 C , i- 'ine , 8/29/2011 NOTE:WAIVERED WELL OA x OOA COMMUNICATION _ _ SLEEVE;2,292.0 3/1/2012 NOTE:Welded sleeve onto surface csg from bottom of starter head to 21.5'w/X65 12"x 500 wall pipe X0 Threads;2,294.0 I I SURFACE;36.7-3,393.7—� XO Threads;5,283.511. GAS LIFT;5,293.0I Y, XO Threads;5,299.5 ar I�Il XO Threads;10,491.4 GAS LIFT;10,495.2 XO Threads;10,501.7 I 1 II XO Threads;11,256.8 GAS LIFT;11,260.3 ., : XO Threads;11,266.8 LOCATOR;11,307.1 * YYi XO Reducing;11,313.9 SEAL ASSY;11,307.6 ,-air SBE;11,325.9 at: II CC GAS LIFT;11,384.1 Br 11 LOCATOR;11,432.2 SEAL ASSY;11,433.2 '- PBR;11,440.3 dk. PACKER;11,483.4 _ Mr X LOCATOR;11,765.3 WM SEAL ASSY;11,766.3, PBR;11,767.8 -. i1 LM PACKER,11,781.1 .t. POOR BOY OVERSHOT; 1II 11,861.6 ........ III PACKER;11,891.2 I. NIPPLE;11,941.2 -.. WLEG;11,953.1 1 PRODUCTION;34.4-12,394.3, OPEN HOLE FRAC;12,394.0 --• OPEN HOLE;12,394.0-16,985.0 - • PTO 24Ogy Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Wednesday,April 06, 2016 10:26 AM To: Loepp,Victoria T (DOA) Subject: CPAI CRU CD2-53 (PTD 204-089) - RWO Scope Change Notification Attachments: CRU CD2-53 - RWO Scope Change IA Leak Schematic - FINAL 20160406.pdf Importance: High Follow Up Flag: Follow up Flag Status: Flagged Victoria, We are going to perform a scope change on the CD2-53 RWO that Doyon 142 is currently executing. While performing the pre-rig well work last month,an IA pressure leak was discovered and the RWO scope was modified to include hunting for this leak. We finished our run with the test packer today and have determined that we have a production casing leak between 11,500' & 11,564' MD. To accommodate this leak,we are going to add another packer so that the new completion straddles the casing leak(please see attached Schematic). Please let me know if you have any questions or have concerns with our new plan forward. Regards, - Danny APR 2 0 2016 Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1509 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com 1 FMC Alpine Gen I Retrofitted ECRU CD2-53 ConocoPhilli w/Additional TubingtHead (" r , Alpine C-Sand Producer Updated RWO Scope 16"62.5#H-40 WLD,114'MD�r_L (Isolate Production Casing Leak) 34"OD Insulated Jacket 21'/:'12"65.4#X-65 Surface Casin Patch Surface Casing Cement Job • Welded bebw starterhead during 2012 excavation& Lead 10.7ppg AS Lite, Top Surface removal of conductor. Tail 15.8ppg Class G, Top 2894'MD • OA Shoe Squeeze 15.7ppg ArcticSet —2300'MD,Camco 3-%"x 2.813"BP-6i Nipple 13.2ppg Viscosified Pill Spotted On Top _• ;4"Control Line w/1x Clamp/Jt to Surface,Isolation Sleeve 4 . 5-1/2"Inner Casing String -15.5#L-80 HYD 563 to—2400'MD -17.0#L-80 HYD 513 Below 9-5/8"36#J-55 BTC,3393'MD/2370'TVD 12-W Suface Hole TD 3402'MD 4 3-1/2"Upper Completion -9.3#L-80 HYD 563 to BP-6i Nipple HW Pill -9.3#L-80 EUE-8RD AB-Mod Below Drilling Mud/Spacer Lead Cement —5300'MD,Camco 1"KBG-2-9 w/DV Tail Cement Arctic Pack Diesel Freeze Protect Seawater Brine w/Form Fluids Weighted Brine —10500'MD,Camco 1"KBG-2-9 w/DV —11187'MD,Camco 1"KBG-2-9 w/DCK-2 SOV I ' —11249'MD,Baker 20'80-40 SBE&Seal Assembly —11322'MD,HES 2.813"X Nipple —11375'MD,Camco 1"KBG-2-9 w/DV —11433'MD,Baker 10'80-40 PBR&Seal Assembly —11464'MD,Baker 7"x 3'/2"FHL Packer 7"Production Casing Leak ■ Target Depth:Shalloaerthan 11,470'MD Between 11,500'&11,564'MD , Leak Interval Isolated w/Test Packer Q a -11701'MD,HES 2.813"X Nipple w/RHC Plrg Body Installed for Ball&Rod Production Casing Cement Job Tail 15.8ppg Class G, Top 11663'MD —11753'MD,Baker 10'80-40 PBR&Seal Assembly —11766'MD,Baker 7"x 3-1/2"FHL Packer .:L Target Depth:Deep As Possible —11817'MD,HES 2.813"X Nipple w/RHC Pltg Body Installed for Ball&Rod Pre-Rig Tubing Cut-11866'MD —11866'MD,Baker Non-Sealing Overshot Fully-Located 11891'MD,Baker 7"x 3-1/2"SAB-3 Packer 11941'MD,HES 2.812"XN Nipple I1.71"RN Nipple Reducer Installed al 1.71"RXN Plug 11953'MD,Bell Collar WLEG � I � I 7"26#L-80 BTC-M,12394'MD/7205'TVD ► 8-'/:"Intermediate Hole TD 12407'MD ` _ _ I Date: 06-Apr-2016 J Drawn By: Danny Kane PTD 204 -og'3 Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Monday, March 21, 2016 9:51 AM To: Loepp,Victoria T (DOA) Cc: Schwartz, Guy L(DOA) Subject: RE: CPAI CRU CD2-53 - Sundry Request Revision (PTD 204-089, Sundry 316-170) Follow Up Flag: Follow up Flag Status: Flagged Victoria, Based upon the current RWO progress on CD1-15, Doyon 142 may be moving to CD2-53 as early as tomorrow night (Tuesday, 22-Mar-2016). Regards, - Danny Danny Kane %CANNED APR 2 0 2016 Senior Wells Engineer ConocoPhillips-ATO 1509 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com From: Kane, Danny Sent: Friday, March 18, 2016 9:18 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Subject: RE: CPAI CRU CD2-53-Sundry Request Revision (PTD 204-089,Sundry 316-170) Thank you Victoria. I just talked with Drew Huck(RWO Engineer for current D142 RWO CD1-15) and he expects the rig to be ready to move Tuesday/Wednesday of next week(March 22-23). Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1509 Office: +1907 265-6048 Mobile: +1 907 227-6037 danny.kane@conocophillips.com From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, March 18, 2016 9:09 AM To: Kane, Danny<Danny.Kane@conocophillips.com> 1 • • Cc:Schwartz, Guy L(DOA)<guy.schwartz@alaska.gov> Subject: [EXTERNAL]RE: CPAI CRU CD2-53-Sundry Request Revision (PTD 204-089,Sundry 316-170) Danny, I've updated the Sundry(316-170)with the requested changes. The Sundry review is in process. Keep me posted on when the rig is expected to move to this well. I will let you know when the sundry has been approved. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victo ria.LoeppCa�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Kane, Danny [ lailto:Dannv.Kane@conocophillips.com] Sent: Thursday, March 17, 2016 4:22 PM To: Loepp, Victoria T(DOA) Cc: Schwartz, Guy L(DOA) Subject: RE: CPAI CRU CD2-53 - Sundry Request Revision (PTD 204-089) Thank you, that will work well. Please give me a call if you'd like to discuss. Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1509 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday, March 17, 2016 4:18 PM To: Kane, Danny<Danny.KanePconocophillips.com> Cc:Schwartz, Guy L(DOA)<guy.schwartz@alaska.gov> Subject: [EXTERNAL]Re: CPAI CRU CD2-53-Sundry Request Revision (PTD 204-089) I will look at this first thing tomorrow morning- Sent from my iPhone On Mar 17, 2016,at 4:15 PM, Kane, Danny<Danny.Kane@conocophillips.com>wrote: Victoria, 2 • • I have included Guy in this email because of the urgency of this request. CPAI has started the pre-rig work in preparation for the CD2-53 RWO which I have submitted a 10- 403 sundry request for(I have not yet received it back). During the pre-rig work performed over the past few days,the well has repeatedly fail an MIT-IA pressure test to 2,500 psig—approximately 400psig will bleed off in the first 15 minutes after which another 40-50 psig will bleed off in the next 50 minutes. The tubing,tubing patch, &tubing tail plug do pass a MIT-T to 2,500 psig, so we have isolated the issue to the IA& it appears to be downhole. Because our internal policies require two tested barriers to be exposed to the atmosphere which would allow us to pull & L/D the 17 joints of the 2-3/8"4.6#L-80 TSH511 tubing joints that make up the majority of the tubing patch in this well,we cannot completely pull the patch in its entirety pre- rig. Therefore, I am asking for permission to change the scope of the RWO to add pulling the patch on- rig as well as adding IA diagnostics on-rig using a test packer to determine the IA leak location;assuming the leak is where we suspect it to be,the final well completion will not change. If the final completion design has to change, I'll contact the AOGCC to verify the new completion design is OK to install. I have amended the General Procedure to reflect the requested changes(see attached)and would like permission to amend the submitted sundry as outlined in the new general procedure. As the rig is expected to move at the beginning of next week, please contact me ASAP at this email or by calling 907- 227-6037 at your earliest convenience if you would like to discuss the proposed changes. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1509 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com <CRU CD2-53 Sundry - General Procedure REVISION 20160317.pdf� 3 • .t.;OF TFi ////,�s THE STATE Alaska Oil and Gas •r' of/` T AConservation Commission sKA 333 West Seventh Avenue ` GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALA5I�Q" Fax: 907.276.7542 www.aogcc.alaska.gov Daniel Kane Sr. Wells Engineer ConocoPhillips Alaska, Inc. .; 4% { s' P.O. Box 100360sctoiosE Anchorage, AK 99501 Re: Colville River Field, Alpine Oil Pool, CRU CD2-53 Permit to Drill Number: 204-089 Sundry Number: 316-170 Dear Mr. Kane: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this 2day of March, 2016. RBDMS MAR 12 2016 • RECEIVED • STATE OF ALASKA MAR 0 3 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS QOGCC 20 AAC 25.280 �` 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well U' Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing o,,, Change Approved Programs Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well CI Alter Casing a Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillipsAlaska,Inc. _ Exploratory ❑ Development D. 204-089 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20494-00 - 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a Will planned perforations require a spacing exception? Yes ❑ No❑i CRU CD2-53 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL380075; ADL372097 ' Colville River Field/Alpine Oil Pool. 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): /Zzj/— Plugs(MD): Junk(MD): 16985' . 7200' . 7374' - 4567' 'vv ' none 7437' Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 3353' 9.625" 3391' 2369' Intermediate Production 12356' 7" 12392' 7205' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4.5"x 3.5" L-80 11954' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV: CAMCO TRM-4E SAFETY VALVE 1 MD=2311 TVD=1804 PACKER-BAKER SAB-3 PACKER W/MILLOUT EXTENSION ' MD=11891 TVD=7042 12.Attachments: Proposal Summary ❑ Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑✓ ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 3/15/2016 OIL o - WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Daniel Kane @ 265-6048 Email Daniel.Kane@conocophillips.com Printed Name Daniel Kane 265-6048 Title Sr.Wells Engineer Phone r.- 2::::cp____, Signature Date Z.—IM+AR 201 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ?j\e -\'l0 Plug Integrity ❑ BOP Test er' Mechanical Integrity Test ❑ Location Clearance El Other:QN), fit-f ps—t5vrC h 0 SOU pyt,g ict7wi v!a'rpre Vt.-,f-tr 7-- f.- to 2500 p$-t, Post Initial Injection MIT Req'd? Yes ❑ No RBDMS i (, MAR 2 2 2016 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /1) --Lf U if APPROVED BY Approved by:alei COMMISSIONER THE COMMISSION Date: 3 ,.2z_/ „ VTL 3�2Z/�G ?AA ���� � 7 �� tuS Lalid ( 0 �,,._ubmit Form and Form 10-403 Revised 11/2015 O 1 \iGdiNaA for 12 months from the date of approval. 1,\'a(Attachments in Duplicate • •• ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 March 2nd,2016 Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission RECEIVED 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 MAR 0 3 2010 Dear Commissioner: ° 'O GCC ConocoPhillips Alaska,Inc. hereby submits an Application for Sundry Approval to workover Alpine Producer CRU CD2-53 (PTD#204-089). Well CD2-53 was spudded and completed in July Vas an Alpine A-sand gas-lifted producer. The well was fracture stimulated in 2006 and with the exception of the two integrity issues listed below,has produced without incident. In 2011, a shallow surface casing was found and repaired with a welded surface casing sleeve after excavating & removing the conductor. Unfortunately,a deeper surface casing leak was found while testing the shallower repair and ultimately an OA cement shoe was pumped to provide a base for a proposed Seal-Tite treatment. The surface casing leak was repaired during the pumping of the OA shoe and currently OA x formation communication exists through a failed OA cement shoe. The well has been subject to additional monitoring for OA x OOA communication since. In 2015,a TIFL failed immediately after an injection test,in preparation for a scale squeeze. Diagnostic work showed multiple tubing holes with extensive internal corrosion from —11250' to 11675' MD & isolated external corrosion from 11700' to 11765' MD. A tubing path from 11180' to 11788' MD (packer mid-element depths) was installed, successfully tested,and the well was brought back on production. Given the unknown tubing patch longevity & rig availability issues at Alpine, the well was placed on the RWO schedule. The proposed scope of this proactive rig work-over consists of pulling the existing tubing patch,pulling the 3-'h"upper completion to a tubing cut at 11,866' MD,running a new 5-'/2"inner casing string with a stacked packer placed above potential internal casing corrosion,and running a new 3-'/2"upper completion to bring the well back on gas-lifted production./ This Sundry is intended to document the proposed work for CRU CD2-53 because of the intent to pull tubing,&repair the well and also to request approval to workover this well. If you have any questions or require any further information,please call me at 265-6048 or email me at danny.kane(&,conocophillips.com. Sincerely, Danny Kane Wells Engineer CPAI Drilling and Wells • • • CRU CD2-53 Proposed Rig Workover ConocoPhillips Pull & Replace Tubing, Install Inner Casing String Alaska Original PTD#:204-089 CURRENT STATUS: (UPDATES IN BOLD BLUE FONT) CRU CD2-53,an Alpine C-sand gas-lifted producer,is currently producing with a tubing patch&known OA x formation communication. The well developed a surface casing leak in 2011 and while the near-surface leak(OA x OOA)has been temporarily repaired,OA x formation communication still exists through a failed cement shoe. In 2015,the well developed multiple tubing leaks as a result of severe internal corrosion and a temporary tubing patch was installed to bring the well back on production. The tubing patch longevity is uncertain and with the rig availability issues at Alpine,CPAI would like to perform a proactive work-over on CD2-53 to replace the tubing as well as to permanently fix both the OA x OOA and OA x formation communication issues. Please see below for a history of the well&annuli integrity diagnostics: - 2004—CRU CD2-53 was drilled&completed as an Alpine A-sand gas-lifted producer. - 2006—The Alpine-A sand was fracture stimulated(300M#open-hole frac). - 2011—Leak in OA found,OA x OOA communication. o July—OA no longer holding pressure,AOGCC notified. o August—Diagnostic work finds a surface casing leak—17.5'MD beneath the OA valve with a LLR of^'0.28 gpm. o September—Request made&AOGCC approves Sundry#311-265 to repair the surface casing leak by performing a surface excavation to weld a sleeve over the surface casing leak. - 2012—OA leak repair efforts completed. o March—Surface casing sleeve repair completed. MIT-OA still fails but the installed sleeve is competent. Continued excavating to 34'MD but unable to find the deeper leak. o April—Continued to try to repair the surface casing leak but unable to regain full integrity. Additional monitoring started. • Request made&AOGCC approves Sundry#312-140 to pump an OA shoe to give a base to perform a Seal-Tite repair of the deeper surface casing leak. • OA shoe pumped but still unable to get a passing MIT-OA. Leak rate too low to measure but slowly bleeds pressure. • Gel/Barite pill spotted down OA above the cement shoe but still unable to get passing MIT-OA. Leak rate too low to measure but slowly bleeds pressure. • Post-repair analysis determines that OA cement shoe is leaking but the shallower leak has been temporarily repaired by the OA shoe cement job. Well is placed back online but additional monitoring for OA x OOA communication put in place. - 2014—After monitoring the OA x OOA communication for two years and without seeing an OOA fluid level rise,the conductor is filled with frac sand&capped with RG-2401 sealant. o OA leak rate steady at—0.15-0.20 gpm&still exists to the present day. - 2015—TxIA communication develops,is diagnosed,&repaired with a tubing patch. o May—TIFL failed immediately after a pre-scale squeeze injectivity test. Diagnostics begin. o June—Tubing leak identified at 11,530' MD with a leak detect log. Attempt to patch—fails. o July—Additional tubing leaks found from 11,421'to 11,642'MD. MVRT showed severe internal tubing corrosion from 11,250'to 11,675' MD&isolated external tubing corrosion from 11,700'to 11,765'MD. o September—Tubing patch installed from 11,257'to 11,788'MD(packer mid-element depths)but MIT-T,MIT-IA,&CMIT-TxIA failed. o October—Additional tubing leak identified at 11,255'MD and tubing tail plug&GLM#2 DV replaced to get a passing CMIT-TxIA. Patch extension to 11,180'MD(packer mid-element) installed&MIT-IA passed—total patch from packer mid-elements 11,180'—11,788' MD. GLD installed&well brought back on production. 2016—Pre-Rig work prior to RWO discovers IA leak w/repeated failing MIT-lAs. a Tubing/tubing patch/tubing tail plug passes MIT-T to 2,500 psig without issue. Page 1 of 4 • • • CRU CD2-53 Proposed Rig Workover ConocoPhillips Pull & Replace Tubing, Install Inner Casing String Alaska Original PTD#:204-089 o Based upon diagnostics,the IA leak is believed to be below GLM#3 where a MicroVertilog showed external tubing corrosion. During the pre-fracture stimulation work in 2006,the CMPA sliding sleeve is believed to have been inadvertently opened&non-inhibited fluids were pumped into the IA between GLM#3(11,713'MD)&the CMPA sliding sleeve (11,803'MD). The original RWO scope included a proactive stacked packer above this interval as a precaution. A test packer will be used to determine the actual IA leak depth. SCOPE OF WORK: The objective of this proposed RWO will be to replace the tubing and install an additional casing string to bring the well back on production without restriction or any extra monitoring. The scope of the proposed RWO will be to pull the 3-'/2"upper completion to a pre-rig tubing cut at^'11,220'MD,fish the remaining tubing patch,&pull the 3-1/2"upper completion to a tubing cut at 11,866'MD. Pending a contingency clean-out run,a test packer will be picked up & used to isolate the IA leak. The completion will be reconfigured as needed, but the base plan is to run a new 5-'/"inner casing string with a stacked packer to place above potential internal casing corrosion,and run a new 3-'/2" upper completion to bring the well back on gas-lifted production. GENERAL WELL INFO: Well Type: Alpine Producer(Another embarrassing typo caught). MPSP: 1,260 psig using MPSP=(PP-(0.1*TVD)),or dry gas gradient to surface. 1,260 psig=(1,980 psig—(0.1 psig/ft*7,205'TVD)) (NOTE:I realized I had written a deeper than actual interpolated TVD of the SBHP gauge pressure. Since I calculate the estimated SBHP at the top of the Alpine C using the SBHP pressure at the depth recorded and then use the gradient measured to extrapolate the SBHP to the reservoir top;the reservoir pressure I had originally calculated was too high, hence the now lower MPSP.) Reservoir Pressure/TVD: Alpine C-Sand Top—1,980 psig/7,205'ND(5.3 ppg EMW) Wellhead Type: FMC Alpine Gen I Unihead(5M Tubing&Casing Head) BOP Configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT Results: MIT-T Passed 16-Mar-2016 'assed during pre-RWO set-up w/tubing tail plug. MIT-IA FAILED 16-Mar-2016 CMIT-TxIA last passed 20-Oct-2016 MIT-OA Failed 16-Apr-2015 LLR 0.194 gpm, OA Shoe Leaking Earliest Start Date: 20-Mar-2016 Production Engineer: Stefan Weingarth/Anu Sood Workover Engineer: Danny Kane (907)265-6048 danny.kane@conocophillips.com SUMMARY OF PROPOSED RWO PROCEDURE: Completed&Proposed Pre-Rig Work: 1. Function-tested all T&I.C. LDS. Perform POT&PPPOT on the T&I.C.pack-offs. 2. Installed 1.71"RXN Plug in the 1.71" RN Nipple Reducer within the 2.81"XN Nipple(11,941'MD). 3. Perform a 30-min MIT-T(PASS)&MIT-IA(FAIL)each to 2,500 psig. 4. Pull the OV from GLM#2(9,439'MD)&leave the pocket open. 5. Pull the existing Liner Patch Extension&Upper Patch Assembly from 11,180'to 11,262'MD. 6. Perform a 3-1/2"tubing cut at 11,220'MD after firing a string-shot at the cut location(^'42'above the top of the Middle Patch Assembly within the tubing). 7. Start proactively bleeding the OA&set BPV prior to rig arrival. Page 2 of 4 • • CRU CD2-53 Proposed Rig Workover ConocoPhillips Pull & Replace Tubing, Install Inner Casing String Original PTD#:204-089 Alaska Proposed Rig Workover Procedure: 1. MIRU RWO Rig. 2. Pull BPV. Circulate out freeze protect cap from the tubing by pumping down the IA. Circulate out freeze protect cap from the IA by pumping down the tubing. Obtain SITP&SICP,if still seeing pressure at surface,circulate 1.25 TxIA volume to the production packer/tubing tail plug. Obtain SITP & SICP, if still seeing pressure at surface,calculate new KWF&repeat circulation as necessary. Perform a 30-minute flow check on the TxIA to confirm the well is static. 3. Set BPV and perform a 10-minute test in the direction of flow by pressuring up on the IA to 1,000 psig. 4. ND tree,set the blanking plug, NU BOPE,&test BOPE to 250/2,500 psig low/high. 5. Pull the blanking plug,pull the BPV,screw in landing joint, BOLDS,&unseat the tubing hanger. 6. P/U on the 3-1/2"tubing,pull free at the pre-rig 3-Y2"tubing cut at 11,220 MD,and pull the tubing hanger to the rig floor. 7. Verify the well is static&TOH laying down the 3-1/2"upper completion to the pre-rig tubing cut at 11,220'MD. 8. TIH w/external tubing cutter&wash pipe as needed. Wash-over the 3-1/2'tubing stub&cut the tubing at -11,320' MD,-'58' below the top of the Middle Patch Assembly within the tubing. TOH slowly to clear the fish from the Middle Patch Assembly(now w/58'sticking out above tubing stub). Finish TOH&L/D fish. 9. TIH w/overshot dressed for the Middle Patch Assembly,engage,& latch-on. P/U to pull the Middle Patch Assembly free of the Lower Patch Assembly at 11,788'MD. Slowly pull the"'550'MD Middle Patch Assembly (including 17 jts of 2-3/8"4.6#L-80 TSH511 tubing)out of the tubing until it clears the tubing stub at 11,320' MD. TOH &L/D fish. 10. TIH w/overshot dressed for the 3-1/2"tubing on a full-bore work string,space-out for BOP stack,engage, latch onto the tubing stub at 11,320'MD,&set in slips. 11. R/U Digital Slickline. TIH & pull the Lower Patch Assembly. TIH &fire string shot straddling chemical cut location,&chemical cut the tubing at 11,866'MD. RDMO DSL. a. CONTINGENCY:If tubing exterior is in poor condition,perform a clean-out run to the tubing stub. 12. P/U to pull tubing fish free(11,320'to 11,866'MD),TOH laying down full-bore work string,&L/D fish. 13. TIH w/test packer on drill pipe to just above the tubing stub at 11,866' MD. Use the test packer to isolate the IA leak. Assuming the IA leak is below GLM#3(diagnostics thus far suggest that),proceed with the RWO as planned. If the leak is shallower,adjust the completion as needed to obtain the RWO objectives. 14. M/U&TIH w/the 5-%2"inner casing string with sealbore extension crossed over to 3%2"tubing with a stacked packer&poor-boy overshot. 15. With the poor-boy overshot over the tubing stub,spot corrosion-inhibited seawater into the IA from above the existing SAB-3 production packer to just above the stacked packer. 16. Fully-locate the poor-boy overshot on the 3-Y2" tubing stub at 11,866' MD, space-out one foot from fully- located,drop the ball&rod,&pressure-up to 2,000 psig to set the stacked packer. Bleed the tubing pressure &pressure-test the IA to 2,500 psig for 5 minutes to verify the packer has set properly. 17. P/U to shear the seal assembly out of the PBR on top of the stacked packer. Sting the seal assembly back into the PBR,space-out seven feet from fully-located,mark the pipe,&lay-down two 5%2"casing joints. 18. Space-out with 5%'casing pups and M/U the casing hanger&landing joint. 19. Shut-in the annular on the 5%2"casing and reverse-circulate corrosion-inhibited seawater chased by diesel to freeze protect down the 5-%2"x 7"annulus while taking returns up the 5%2"casing. 20. Open the annular,sting the seal assembly into the PBR,land the 5-%2"casing hanger,&RILDS. Page 3 of 4 • • CRU CD2-53 Proposed Rig Workover ConocoPhil li ps Pull & Replace Tubing, Install Inner Casing String Alaska Original PTD#:204-089 21. Pressure-test the 5-%2"x 7"annulus to 2,500 psig for 30 minutes while monitoring the 5-%z"casing for returns. Pressure-test the 5-%:"casing hanger pack-offs to 4,000 psig. 22. P/U a retrievable bridge plug,TIH to^'50'MD,set,&pressure-test from above to 1,000 psig. Release from the bridge plug&L/D the running tool. 23. Perform a 30-minute flow check on the 5-%"casing&5%"x 7"annulus. 24. ND BOPE, install new tubing head,&NU BOPE. Install the test plug&shell-test the BOPE&BOP stack/tubing head break to 250/2,500 psig. 25. P/U&TIH with the bridge plug retrieval tool, release the bridge plug,TOH,&L/D the bridge plug. 26. M/U&TIH w/the new 3-Y2"upper completion to above the SBE at the base of the 5%"casing. 27. Sting the seal assembly into the SBE until fully-located,space-out seven feet, mark the pipe at surface, & lay- down two tubing joints. 28. Space-out with tubing pups and M/U tubing hanger and landing joint. 29. Spot corrosion-inhibited seawater into the 3-%2"x 5-Y2"annulus by pumping down the tubing. 30. Sting the seal assembly into the SBE,land the tubing hanger,&RILDS. 31. Pressure-test the tubing to 3,000 psig&the 3%"x 5-14"annulus to 2,500 psig. Bleed the IA&then the tubing. Ramp up the IA pressure quickly to shear the SOV. 32. Back-out the landing joint&install BPV. 33. ND BOPE,NU tree,install tree test plug,&pressure test tree. 34. Freeze protect the well through the SOV. 35. Set BPV. 36. RDMO RWO Rig. Proposed Post-Rig Work 1. Pull BPV. 2. Pull the ball&rod and the RHC plug body from the 2.813"X Nipple at 11,532'MD. 3. Install the GLD as planned. 4. Pull the catcher sub on top of the 1.71"RXN plug at 11,941' MD. 5. Pull the 1.71"RXN plug from the 1.71"RN Nipple Reducer at 11,941'MD. 6. Pull the 1.71"RN Nipple Reducer from the 2.81"XN Nipple at 11,941'MD. 7. Reset well house(s)&re-attach flow line(s). 8. Turn well over to operations. Page 4 of 4 • •• CRU CD2-53 Proposed Rig Workover ConocoPhillips Pull & Replace Tubing, Install Inner Casing String Alaska Original PTD#:204-089 CURRENT STATUS: CRU CD2-53,an Alpine A-sand gas-lifted producer,is currently producing with a tubing patch&known OA x formation communication. The well developed a surface casing leak in 2011 and while the near-surface leak(OA x OOA)has been temporarily repaired,OA x formation communication still exists through a failed cement shoe. In 2015,the well developed multiple tubing leaks as a result of severe internal corrosion and a temporary tubing patch was installed to bring the well back on production. The tubing patch longevity is uncertain and with the rig availability issues at Alpine,CPAI would like to perform a proactive work-over on CD2-53 to replace the tubing as well as to permanently fix both the OA x OOA and OA x formation communication issues. Please see below for a history of the well&annuli integrity diagnostics: - 2004—CRU CD2-53 was drilled &completed as an Alpine A-sand gas-lifted producer. - 2006—The Alpine-A sand was fracture stimulated(300M#open-hole frac). - 2011—Leak in OA found,OA x OOA communication. o July—OA no longer holding pressure,AOGCC notified. o August—Diagnostic work finds a surface casing leak"'17.5' MD beneath the OA valve with a LLR of—0.28 gpm. o September—Request made&AOGCC approves Sundry#311-265 to repair the surface casing leak by performing a surface excavation to weld a sleeve over the surface casing leak. - 2012—OA leak repair efforts completed. o March—Surface casing sleeve repair completed. MIT-OA still fails but the installed sleeve is competent. Continued excavating to 34' MD but unable to find the deeper leak. o April—Continued to try to repair the surface casing leak but unable to regain full integrity. Additional monitoring started. • Request made&AOGCC approves Sundry#312-140 to pump an OA shoe to give a base to perform a Seal-Tite repair of the deeper surface casing leak. • OA shoe pumped but still unable to get a passing MIT-OA. Leak rate too low to measure but slowly bleeds pressure. • Gel/Barite pill spotted down OA above the cement shoe but still unable to get passing MIT-OA. Leak rate too low to measure but slowly bleeds pressure. • Post-repair analysis determines that OA cement shoe is leaking but the shallower leak has been temporarily repaired by the OA shoe cement job. Well is placed back online but additional monitoring for OA x OOA communication put in place. - 2014—After monitoring the OA x OOA communication for two years and without seeing an OOA fluid level rise,the conductor is filled with frac sand&capped with RG-2401 sealant. o OA leak rate steady at^'0.15-0.20 gpm&still exists to the present day. - 2015—TxIA communication develops,is diagnosed,&repaired with a tubing patch. o May—TIFL failed immediately after a pre-scale squeeze injectivity test. Diagnostics begin. o June—Tubing leak identified at 11,530' MD with a leak detect log. Attempt to patch—fails. o July—Additional tubing leaks found from 11,421'to 11,642' MD. MVRT showed severe internal tubing corrosion from^'11,250'to 11,675' MD&isolated external tubing corrosion from 11,700'to 11,765' MD. o September—Tubing patch installed from 11,257'to 11,788' MD(packer mid-element depths)but MIT-T, MIT-IA, &CMIT-TxIA failed. o October—Additional tubing leak identified at 11,255' MD and tubing tail plug&GLM#2 DV replaced to get a passing CMIT-TxIA. Patch extension to 11,180' MD(packer mid-element) installed&MIT-IA passed—total patch from packer mid-elements 11,180'—11,788' MD. GLD installed&well brought back on production. Page 1 of 4 • •• CRU CD2-53 Proposed Rig Workover ConocoPhillips Pull & Replace Tubing, Install Inner Casing String Alaska Original PTD#:204-089 SCOPE OF WORK: The objective of this proposed RWO will be to replace the tubing and install an additional casing string to bring the well back on production without restriction or any extra monitoring. The scope of the proposed RWO will be to pull the existing tubing patch,pull the 3-1/i'upper completion to a tubing cut at 11,866'MD,run a new 5-'/z"inner casing string with a stacked packer to place above potential internal casing corrosion,and run a new 3-%"upper completion to bring the well back on gas-lifted production. ✓ GENERAL WELL INFO: Well Type: Alpine A-Sand Producer l MPSP: 1,293 psig using MPSP=(PP-(0.1*TVD)),or dry gas gradient to surface. • 1,293 psig=(2,013 psig—(0.1 psig/ft*7,205'TVD)) c*'6rf Reservoir Pressure/TVD: Kuparuk A/C Mid-Perfs—2,013 psig/7,205'TVD(5.4 ppg EMW) Wellhead Type: FMC Alpine Gen I Unihead (5M Tubing&Casing Head) BOP Configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT Results: MIT-T Passed 31-Oct-2015 Passed after setting patch 11,180'-11,788'MD CMIT-TxIA Passed 20-Oct-2015 Passed after 1.71"RXN Plug reset at 11,941'MD MIT-OA Failed 16-Apr-2015 LLR 0.194 gpm, OA Shoe Leaking Earliest Start Date: 15-Mar-2016 Production Engineer: Stefan Weingarth/Anu Sood Workover Engineer: Danny Kane (907)265-6048 danny.kane@conocophillips.com SUMMARY OF PROPOSED RWO PROCEDURE: Su � Completed&Proposed Pre-Rig Work: 1. Function-test all T& I.C. LDS. Perform POT&PPPOT on the T& I.C. pack-offs. 2. Install 1.71" RXN Plug in the 1.71" RN Nipple Reducer within the 2.81"XN Nipple(11,941' MD). 3. Perform a 30-min MIT-T&MIT-IA each to 2,500 psig. If either fails, perform a 30-min CMIT-TxIA to 2,500 psig. 4. Remove the existing 2-%"4.6#L-80 TSH511 R2 tubing patch from the well(11,180'to 11,788' MD KB-35 packer mid-element to KB-35 packer mid-element). 5. Set catcher sub above the 1.71" RXN plug. 6. Swap the GLV from GLM#1(5,125' MD)for a DV. 7. Swap the OV from GLM#2(9,439' MD)for a DV. 8. Pull the DV from GLM#3(11,713' MD)&leave the pocket open. 9. Swap the TxIA entirely over to seawater with a 2,000'TVD freeze protect cap(diesel or weathered crude). 10. Perform a 30-min CMIT-TxIA to 2,500 psig to confirm the tubing plug integrity prior to cutting the tubing. 11. Perform a 3-'/2'tubing cut at 11,866' MD after firing a string-shot at the cut location. 12. Start proactively bleeding the OA. 13. Set BPV prior to rig arrival. SU P RS2 Page 2 of 4 • • IPV CRU CD2-53 Proposed Rig Workover ConocoPhillips Pull & Replace Tubing, Install Inner Casing String Alaska Original PTD#:204-089 Proposed Rig Workover Procedure: 1. MIRU RWO Rig. 2. Pull BPV. Circulate out freeze protect cap from the tubing by pumping down the IA. Circulate out freeze protect cap from the IA by pumping down the tubing. Obtain SITP&SICP, if still seeing pressure at surface, circulate 1.25 TxIA volume to the production packer/tubing tail plug. Obtain SITP & SICP, if still seeing pressure at surface,calculate new KWF&repeat circulation as necessary. Perform a 30-minute flow check on the TxIA to confirm the well is static. 3. Set BPV and perform a 10-minute test in the direction of flow by pressuring up on the IA to 1,000 psig. 4. ND tree,set the blanking plug, NU BOPE,&test BOPE to 250/2,500 psig low/high. ---24 v,o tic f-oL?CG 5. Pull the blanking plug, pull the BPV,screw in landing joint, BOLDS, &unseat the tubing hanger. r a. CONTINGENCY — If the patch wasn't able to be pulled during the pre-rig work, the patch will be attempted to be pulled at this time. The patch needs to be removed to get a tubing cut at 11,866' MD in order to pull the tubing without pulling the packer(tubing threaded into the packer). 6. P/U on the 3-%" tubing, pull free at the pre-rig 3-'/"tubing cut at 11,866' MD,and pull the tubing hanger to the rig floor. 7. Verify the well is static&TOH laying down the 3-Y2" upper completion to the pre-rig tubing cut at 11,866' MD. 8. M/U&TIH w/the 5-%"inner casing string with sealbore extension crossed over to 3-%"tubing with a stacked packer&poor-boy overshot. 9. With the poor-boy overshot over the tubing stub,spot corrosion-inhibited seawater into the IA from above the existing SAB-3 production packer to just above the stacked packer. 10. Fully-locate the poor-boy overshot on the 3-'/2" tubing stub at 11,866' MD, space-out one foot from fully- located,drop the ball&rod,&pressure-up to 2,000 psig to set the stacked packer. Bleed the tubing pressure &pressure-test the IA to 2,500 psig for 5 minutes to verify the packer has set properly. 11. P/U to shear the seal assembly out of the PBR on top of the stacked packer. Sting the seal assembly back into the PBR,space-out seven feet from fully-located, mark the pipe,&lay-down two 5-'/2"casing joints. 12. Space-out with 5-'/"casing pups and M/U the casing hanger&landing joint. 13. Shut-in the annular on the 5-%"casing and reverse-circulate corrosion-inhibited seawater chased by diesel to freeze protect down the 5-'/z"x 7"annulus while taking returns up the 5-%"casing. 14. Open the annular,sting the seal assembly into the PBR, land the 5-'/z"casing hanger,&RILDS. 15. Pressure-test the 5-'/"x 7"annulus to 2,500 psig for 30 minutes while monitoring the 5-'/z"casing for returns. Pressure-test the 5-'/z"casing hanger pack-offs to 4,000 psig. 16. P/U a retrievable bridge plug,TIH to"50' MD,set,&pressure-test from above to 1,000 psig. Release from the bridge plug& L/D the running tool. 17. Perform a 30-minute flow check on the 5-%"casing&5-'/i"x 7"annulus. 18. ND BOPE,install new tubing head,& NU BOPE. Install the test plug&shell-test the BOPE& BOP stack/tubing head break to 250/2,500 psig. 19. P/U&TIH with the bridge plug retrieval tool, release the bridge plug,TOH,& L/D the bridge plug. 20. M/U&TIH w/the new 3-'/2' upper completion to above the SBE at the base of the 5-%"casing. 21. Sting the seal assembly into the SBE until fully-located,space-out seven feet, mark the pipe at surface, & lay- down two tubing joints. 22. Space-out with tubing pups and M/U tubing hanger and landing joint. S'PEP.5 j ED 23. Spot corrosion-inhibited seawater into the 3-'/z"x 5-%"annulus by pumping down the tubing. 24. Sting the seal assembly into the SBE, land the tubing hanger,&RILDS. Page 3 of 4 • • CRU CD2-53 Proposed Rig Workover ConocoPhillips Pull & Replace Tubing, Install Inner Casing String Original PTD#:204-089 Alaska h q r-7 25. Pressure-test the tubing to 3,000 psig&the 3-%"x 5-%"annulus to 2,500 psig. Bleed the IA&then the tubing. Ramp up the IA pressure quickly to shear the SOV. 26. Back-out the landing joint&install BPV. 27. ND BOPE, NU tree, install tree test plug,&pressure test tree. 28. Freeze protect the well through the SOV. 29. Set BPV. 30. RDMO RWO Rig. Proposed Post-Rig Work 1. Pull BPV. 2. Pull the ball&rod and the RHC plug body from the 2.813"X Nipple at 11,532' MD. 3. Install the GLD as planned. 4. Pull the catcher sub on top of the 1.71"RXN plug at 11,941' MD. 5. Pull the 1.71" RXN plug from the 1.71" RN Nipple Reducer at 11,941' MD. 6. Pull the 1.71" RN Nipple Reducer from the 2.81"XN Nipple at 11,941' MD. 7. Reset well house(s)&re-attach flow line(s). 8. Turn well over to operations. Su PEI1SE ED S PERS p EP Page 4 of 4 ,� • `• FMC Alpine Gen I Retrofitted RU CD2 53 w/Additional Tubing Head ConocoPhilli s I - Alpine A-Sand Producer Proposed P&R Tubing & 16"62.5#H-40 WLD,114'MD—I► • I Additional 5-1/2"Casing Scope 34"OD Insulated Jacket ' ' ?•••?' •x; 21-1/2' 12"65.4#X-65 Surface Casing Patch Surface Casing Cement Job '.Y. Welded below starter head during 2012 excavation& Lead 10 7ppg AS Lite. Top Surface removal of conductor Tail 15.8ppg Class G. Top 2894'MD • OA Shoe Squeeze 15.7ppg ArcticSet • • -2296'MD,Camco BP-6i Nipple 2.812"WRDP- 13.2ppg Viscosified Pill Spotted On Top /.'Control Line w/SS Bands to Surface f ::: : ::1 5'/2"Inner Casing String -15.5#L-80 HYD 563 to-2400'MD 1 -17.0#L-80 HYD 513 Below 9-5/8"36#J-55 BTC,3393'MD/2370'TVD-1-110•L- ,,=J 12-'/."Suface Hole TD 3402'MD . I 3-1/2"Upper Completion I -9.3#L-80 HYD 563 to BP-6i Nipple HW Pill 1 -9.3#L-80 EUE-8RD AB-Mod Below Drilling Mud/Spacer 1 Lead:Cement I I Tail Cement 1 Arctic Pack 1 1 Diesel Freeze Protect 4 � -5142'MD,Cam co 1"KBG-2-9 w/DV Seawater I I Brine w/Form Fluids I I %><>Y".10#4041 ;:4 ,Er.' -0--4----9447'MD,Cam co 1' KBG-2-9 w/DV 1 I 1 I Mil 4 -11396'MD,Camco 1"KBG-2-9 w/DCK-3 SOV U I I -41-11—-11458'MD,Baker 80-40 SBE 1 1 1 SFJ—-11531'MD,Camco 2.813"X Nipple i itAli 4 -11583'MD,Camco 1"KBG-2-9 w/DV ,11118 1 I.1 -girt--11649'MD,Baker80-40 PBR I 410111 MO I I Production Casing Cement Job -111 ".-11672'MD,Baker 3-1/2"x 7"FHL Packer Tail 15 8 Target Depth:NO Deeper than 11700'MD ppg Class G, Top 11663'MD I :I I :: 1 Probable Internal Casing Corrosion 1 - :1 11,700'to 11,765'MD - 1 :: : : 1 1 '4'r. i -11816'MD,Camco 2.813"X Nipple w/RHC Pl uy Body Installed for Ball&Rod Pre-Rig Tubing Cut-11866'MD �T-11865'MD,Baker Non-Sealing Overshot villi :i 11891'MD,Baker 7"x 31/2"SAB-3 Packer :: :1 : I I 11941'MD,HES 2.812"XN Nipple :' 1.71"RN Nippl e Reducer Installed w/1.71"RXN Plug : •I I : I11953'MD,Bell Collar WLEG I;: \ \ _ - 4 \\ I 7"26#L-80 BTC-M,12394'MD/7205'TVD \' . ► r 1 8-'/22 Intermediate Hole 7D 12407 MD Date: 22-Jan-20 16 I Drawn By: Danny Kane WNS PROD . CD2-53 ConocoPhillips 41. Well Attributes Max Angle&MD TD laSica incWellbore API/UWI Held Name Wellbore Status Incl(°) MD(kKB) Act Btm(ftKB) conooPl+npr 501032049400 ALPINE PROD 95.66 16,557.78 16,985.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD2-53,1218/2015 6:58'.07 AM SSSV-TROP Last WO: 43.83 7/16/2004 Vertical schematic(actual) Annotation 'Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 12,086.0 6/29/2011 Rev Reason:TUBING PATCH,GLV C/O pproven 12/8/2015 _......_....._.._.__..._( _ HANGER;32.8 -m' is Casing Strings • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(1188) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.052 37.0 114.0 114.0 62.40 H-40 WELDED ii J CasingACE Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURF95/8 8.921 36.7 3.393.7 2.370.7 36.00 J-55 BTC Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(I...Grade Top Thread PRODUCTION 7 6.276 34 4 12,394.3 7,205.3 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(I...Grade Top Thread OPEN HOLE 61/8 12.394.0 16.985.0 7.200.3 -) Tubing Strings Tubing Description SMng Ma...ID(in) Top(kKB) Set Depth(ft..J Set Depth(TVD)(...Wt(15/9) Grade Top Connection CONDUCTOR;37.0-114.0 ' A TUBING 4.5"x3.5" 31/2 2.992 32.8 11,953.fi 7.070.6 9.30 L-80 EUE-mod Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 111 32.8 32.8 0.00 HANGER -FMC TUBING HANGER 4.500 122.5 122.5 0.13 XO Reducing 4.5",ID 3.958,12.68,EUEM,L-80 CROSSOVER TO 3.5' 3.500 y 2,310.9 1,804.3 59.52 SAFETY VLV CAMCO TRM-4E SAFETY VALVE 2.812 SAFETYVLV;2,310,9 '!i I' 11,803.1 6,997.4 58.19 SLEEVE-C BAKER CMPA SLIDING SLEEVE w/'X'PROFILE 2.812 (OPENS DOWN) 11,891.2 7,041.7 61.39 PACKER BAKER SAB-3 PACKER w/MILLOUT EXTENSION 3.875 11,941.2 7,065.0 63.11 NIPPLE HES XN NIPPLE NO GO wl 2.812"POLISH BORE 2.750 11,953.1 7,070.3 63.52 WLEG BELL COLLAR WIRELINE GUIDE 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top net Top(ftKB) (ftKB) (') Dee Com Run Date ID(fn) 11,172.0 6,651.7 56.69 TUBING TOP BAKER KB Packer 511,180'KB(SET 9/25/2015 1.920 SURFACE;36.7-3,393.711 PATCH 10/30/15) MIDDLE BAKER KB Packer 5 11,257'KB(SET 9/25/15) BOTTOM BAKER KB Packer 5 11,788'KB(SET 9/16/15) GAS LIFT;5,126.1 1.71"ID"R"Nipple Profile at 11,800 KB WLEG at 11,810'KB !17-- Stimulations&Treatments Min Top Mae Btm Depth Depth Top(TVD) Btm(TVD) (ftKB) (ftKB) (9KB) (ftKB) Typo Date Com 12.394.0 16.985.0 7.205.2 7,200.3 OPEN HOLE 3/6/2006 Frac job completed with 3080148 behind pipe and GAS LIFT;9,439.4 FRAC 3080548 f0I3i pumped Mandrel Inserts St ati 1.1 Top(TVD) Valve Latch Port Size TRO Run • N Top)ftKB) (ftKB) Make Model OD lin) Sets Type Type (in) (psi) Run Date Com TUBING PATCH;11,172.0 1 5,125.1 3,397-2 CAMCO KBUG 1 GAS LIFT GLV BK-5 0.188 1.872.0 10/31/2015 2 9,439.3 5,701.3 CAMCO KBUG 1 GAS LIFT OV BK 0250 0.0 10/30/2015 GAS LIFT;11,713.5 3 11,713.5 6,948.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/6/2015 Notes:General&Safety End Date Annotation 7/18/2004 NOTE:TREE: FMC 4-1/16 5K-TREE CAP CONNECTION:7"OTIS 9/3/2010 NOTE:View Schematic wl Alaska Schematic9.0 8/29/2011 NOTE:WAIVERED WELL GA x OOA COMMUNICATION SLEEVE-C;11,803.1 I 1 3/1/2012 NOTE:Welded sleeve onto surface csg from bottom of starter head to 21.5'w/X65 12"x 500 wall pipe • PACKER;11,8912 ' NIPPLE;11,941.2 ■ WLEG;11,953.1 ).. • 6r PRODUCTION;34.4-12,394.3- OPEN HOLE FRAC;12,394.0 r OPEN HOLE;12,394.0-16.985.0 ` • • Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Friday, March 18, 2016 9:09 AM To: 'Kane, Danny' Cc: Schwartz, Guy L (DOA) Subject: RE: CPAI CRU CD2-53 - Sundry Request Revision (PTD 204-089, Sundry 316-170) Danny, I've updated the Sundry(316-170)with the requested changes. The Sundry review is in process. Keep me posted on when the rig is expected to move to this well. I will let you know when the sundry has been approved. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppt alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeno@alaska.gov From: Kane, Danny [mailto:Danny.Kane©conocophillips.com] Sent: Thursday, March 17, 2016 4:22 PM To: Loepp, Victoria T(DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: CPAI CRU CD2-53 - Sundry Request Revision (PTD 204-089) Thank you,that will work well. Please give me a call if you'd like to discuss. Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1509 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday, March 17, 2016 4:18 PM To: Kane, Danny< i.Kane@conocophillips.com> Cc:Schwartz, Guy L(DOA)<guy.sch,..,v -t', alaska.gov> Subject: [EXTERNAL]Re: CPAI CRU CD2-53-Sundry Request Revision (PTD 204-089) 1 • I will look at this first thing tomorrow morning- Sent from my iPhone On Mar 17, 2016,at 4:15 PM, Kane, Danny<Danny.Kane@conocophillips.com>wrote: Victoria, I have included Guy in this email because of the urgency of this request. CPAI has started the pre-rig work in preparation for the CD2-53 RWO which I have submitted a 10- 403 sundry request for(I have not yet received it back). During the pre-rig work performed over the past few days,the well has repeatedly fail an MIT-IA pressure test to 2,500 psig—approximately 400psig will bleed off in the first 15 minutes after which another 40-50 psig will bleed off in the next 50 minutes. The tubing,tubing patch, &tubing tail plug do pass a MIT-T to 2,500 psig, so we have isolated the issue to the IA& it appears to be downhole. Because our internal policies require two tested barriers to be exposed to the atmosphere which would allow us to pull & L/D the 17 joints of the 2-3/8"4.6#L-80 TSH511 tubing joints that make up the majority of the tubing patch in this well,we cannot completely pull the patch in its entirety pre- rig. Therefore, I am asking for permission to change the scope of the RWO to add pulling the patch on- rig as well as adding IA diagnostics on-rig using a test packer to determine the IA leak location; assuming the leak is where we suspect it to be,the final well completion will not change. If the final completion design has to change, I'll contact the AOGCC to verify the new completion design is OK to install. I have amended the General Procedure to reflect the requested changes (see attached)and would like permission to amend the submitted sundry as outlined in the new general procedure. As the rig is expected to move at the beginning of next week, please contact me ASAP at this email or by calling 907- 227-6037 at your earliest convenience if you would like to discuss the proposed changes. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1509 Office: +1907 265-6048 Mobile: +1 907 227-6037 danny.kane@conocophillips.com <CRU CD2-53 Sundry - General Procedure REVISION 20160317.pdf5 2 STATE OF ALASKA AIOKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations E Fracture Stimulate E Pull r Operations Shutdown r Performed: Suspend E Perforate E Other Stimulate E Alter Casing 9 r Change Approved Program Plug for Redrill E Perforate New Pool E,, Repair Well I Re-enter Susp Well r.. Other:Tubing Patch F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory n 204-089 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20494-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380075,372097 CRU CD2-53 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 16985 feet Plugs(measured) 11941 true vertical 7200 feet Junk(measured) None Effective Depth measured 16985 feet Packer(measured) 11891 true vertical 7200 feet (true vertical) 7042 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 0 0 SURFACE 3357 9 5/8 3394 2371 0 0 PRODUCTION 12360 7 12394 7205 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: n/a RECEIVED True Vertical Depth: n/a ,..it c OMEri ''w0 9 • wU. NOV 2 4 2015 Tubing(size,grade,MD,and TVD) 3.5, L-80,11954 AOGGC Packers&SSSV(type,MD,and ND) PACKER-BAKER SAB-3 PACKER W/MILLOUT EXTENSION @ 11891 MD and 7042 TVD SAFETY VLV-CAMCO TRM-4E SAFETY VALVE @ 2311 MD and 1804 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): n/a Treatment descriptions including volumes used and final pressure: n/a 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory E Development F Service r', Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil 17,.. Gas I` WDSPL Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG E GINJ r SUSP E SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Mick Davasher@265-6870 Email Mick.J.Davashera(�conocophillips.com Printed Name Mick Davasher Title Sr. Wells Engineer Signature144 yfri--- --_, Phone: 265-6870 Date I —L4- (S Form 10-404 Revised 5/2015 1/77.- (Y" MS)712/1 � � D 0 1 2015 Submit Original Only Well History CD2-53 5010349400 • Page 1 of 9• dips Well History CD2-53 : 501032049400 : 11/20/2015 Date Event 10/31/2015 RAN CHECK SET TO 9439' RKB TO VERIFY OV SET. PULLED DV @ 5125' RKB. REPLACE WITH 3/16" PORT GLV (TRO = 1872). MITT(30 MN) TO 2000 psi. **PASS**. PULL CATCHER @ 11145' SLIV. PULLED 1.71" RX PLUG @ 11773' SLM. COMPLETE. 10/30/2015 SET UPPER PATCH ASSY (OAL = 76.32' LEFT IN HOLE) WITH HES 2.50" DPU SETTING TOOL. TOP OF PATCH @ 11172' RKB W/BAKER KB PACKER AT 11180' (MID ELEMENT). SET AVA CATCHER @ SAME. SET 1/4" OV @ 9439' RKB. IN PROGRESS. 10/20/2015 CMIT-TxIA TO 2000 PSI PASSED. JOB IN PROGRESS 10/20/2015 PULLED 1.71" RXN PLUG @ 11941' RKB. SET 1.71" RX PLUG @ 11788' RKB. IN PROGRESS 10/18/2015 PASSED CMIT-TxIA. TOOK 2 BBLS DSL TO BRING UP TO TEST PRESSURE OF 2000 PSI, TBG LOST 63 PSI @ 15 MIN., 27 PSI @ 30 MIN. IA LOST 66 PSI @ 15 MIN, 27 PSI @ 30 MIN. JOB COMPLETE. 10/17/2015 PULL DV @ 9439' RKB,BOTH PACKING STACK TORN (SEE ATTACHED PHOTO), U- TUBE T X IA TO BALANCE WELLBORE FLUIDS, RIG DOWN TO CLEAR AREA FOR LRS TO PERFORM COMBO MIT- TXIA, MOVE TO CD2-46, WEATHER HOLD DUE TO HIGH WINDS 10/14/2015 EQUILIZE&PULL 1.71" R PLUG @ 11,788' RKB, SET 1.71" RXN PLUG PLUG @ 11,941' RKB, LRS PERFORMED 3 CMIT'S FAILED 3 TIMES WITH DEMINISHING FAILURE RATES. 10/12/2015 HOISTED PDS LDL. DATA SENT FOR PROCESSING. POSSIBLE LEAK LOCATED AT 11255'. 10/11/2015 TAGGED R PLUG @ 11771' SLM w/ 1.75" BAILER. READY FOR E-LINE 10/11/2015 MOBILIZE TO ALPINE AND CHECK OUT EQUIPMENT 10/09/2015 SET KB PACKER TEST TOOL IN PACKER @ 11220' SLM, PERFORMED MIT-T **FAIL**, PULLED TEST TOOL @ SAME. IN PROGRESS 10/08/2015 ATTEMPTED TO MIT TBG TO 2000 PSI BEFORE INSTALLING KB TEST TOOL. BLED IA DOWN TO 50 PSI, PUMPED 0.4 BBLS TO PRESSURE UP TO TEST PRESSURE OF 2000 PSI. @15 MIN TBG LOST 182 PSI AND IA GAINED 78 PSI. @ 30 MIN TBG LOST 115 PSI AND IA GAINED 62 PSI. MIT-T FAILED. JOB IN PROGRESS. 10/07/2015 ATTEMPT COMBO MIT T X IA TO 2000 PSI. **FAILED**, REPEAT TEST 3 TIMES WITH SAME RESULT. SET KB PACKER TOOL @ 11222' SLM AT TOP OF SEAL BORE RECEPTACLE. COMBO MIT T X IA TO 2000 PSI **FAIL**, SAME RESULTS 10/06/2015 VERIFIED FLOWLINE AND AL LINE ARE BLINDED AND AT ZERO PSI. SET SIMM TEST TOOL @ 11222' SLM(TOP OF PATCH). **FAILED MITT TO 1500 PSI**. MAKE STOPS @ 9703', 8483', 3997' & 1997' SLM WITH THE SAME TEST http://akapps.conocophillips.net/WebBert/Well/Report/rptWellTable.aspx?REPORT=..%... 11/20/2015 Well History CD2-53 5010349400 • Page 2 of 9 RESULTS. BLED TBG TO 97 PSI &PRESSURED IA TO 1975. MONITOR OVERNIGHT. IN PROGRESS. 10/05/2015 SET KB PACKER TEST TOOL @ 11255' CTD. MITT TO 2000 PSI. **FAILED**. PULLED KB TEST TOOL. IN PROGRESS. 09/28/2015 RAN 54' -10" DMY DRIFT(45'-6" X 1.5" TS & 1.75" X 9'-4" BAILER)TO 11798' ELMD. NO OBSTRUCTIONS. COMPLETE. 09/26/2015 MIT-T TO 2000 PSI **FAILED 5 ATTEMPTS** 2.3 BBLS REQUIRIED TO ACHIEVE TEST PRESSURE. IA INCREASED WITH EACH MIT-T MIT-IA TO 2000 PSI ***FAILED 4 ATTEMPTS*** 1.1 BBLS REQUIRED TO ACHIEVE TEST PRESSURE, TBG PRESSURE INCREASED THROUGHOUT EACH MIT-IA. CMIT -TxIA TO 2000 PSI **FAILED**, TBG PRESSURE INCREASED THROUGH TEST, U-TUBED TBG TO IA FOR 45 MIN, RE-TEST, CMIT-TxIA 2000 PSI **FAILED**, RDMO, CPA WELLS SUPERVISOR TO ADVISE PLAN FORWARD. JOB IN PROGESS 09/25/2015 SET BAKER KB35 UPPER PACKER ASSEMBLY AT 11,257' MD. MID ELEMENT . PERFORMED PASSING IA PRESSURE TEST TO 2000 PSI WITH LESS THAN 10% LOSS IN 30 MINUTES. ****TURN OVER TO SLICKIINE**** 09/24/2015 RIH WITH 509' OF 2 3/8" LINER, STING INTO SEAL ASSEMBLY @ 11774' CTMD 11788' MD CONFIRMED IT'S STUNG IN. POOH STACK BACK FOR THE NIGHT. ****JOB IN PROGRESS**** 09/23/2015 RIGGED UP AND GOT EVERYTHING READY TO RUN THE 2 3/8 TUBING PATCH. ****JOB IN PROGRESS***** 09/18/2015 PUMPED 325 BBLS BRINE FOLLOWED BY 88 BBLS DSL DOWN TBG. U- TUBED TBG AND IA FOR AN HOUR AS FREEZE PROTECT. TOOK RETURNS TO FLOWLINE OF CD2-52. JOB COMPLETE. 09/18/2015 SET AVA CATCHER ON TOP OF PACKER @ 11750' SLM. PULLED 1" DGLV @ 11713' RKB. PULLED AVA CATCHER @ 11750' SLM. READY FOR CIRC OUT. IN PROGRESS 09/17/2015 ELINE UNIT STAGE EQUIPMENT IN ALPINE CONTAINMENT, TRAVEL BACK TO KUPARUK 09/16/2015 CMIT-TxIA TO 2500 PSI ****PASSED****. PUMPED 30 BBLS TO BRING UP TO TEST PRESSURE. JOB COMPLETE 09/16/2015 SET LOWER KB 35 PACKER AT 11788' USING BAKER#10 SETTING TOOL. LOG CORRELATED TO TUBING DETAIL RECORD DATED 18 JUL 2004. READY FOR LRS TO CMIT. 09/07/2015 SET 1.71" RN PLUG @ 11941' RKB. CMIT-IA TO 2500 psi. **PASS**. PULL 1.71" RN PLUG @ 11941' RKB. COMPLETE. 09/05/2015 RAN 2.5" PUMP BAILER TO TOP OF PLUG @ 11941' RKB. EQUALIZE& PULL 2.81" XN PLUG @ 11941' RKB. SET 1.71" RN NIP REDUCER ON 2.81" XN- LOCK (OAL=25") @ 11941' RKB. ATTEMPT TO SET 1.71" RN PLUG @ SAME. IN PROGRESS. 07/26/2015 TRAVEL FROM ALPINE TO KUPARUK. JOB COMPLETE. 07/25/2015 LOG BAKER HUGHES MVRT MAIN PASS FROM SURFACE TO 11925'. LOG REPEAT PASS OVER INTERVAL OF INTEREST FROM 11925' TO 10900'. LOG REPEAT PASS FROM 11925' TO SURFACE. LOG CORRELATED TO TUBING TAIL RECORD DATED 18-JULY-2004. JOB COMPLETE. http://akapps.conocophillips.net/WebBer/Well/Report/rptWellTable.aspx?REPORT=..%... 11/20/2015 • , WNS PROD CD2-53 ConocoPhillips a Well Attributes Max Angle&MD TD P Alaska Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Blm(ftKB) r_ 00,,,aeps 501032049400 ALPINE PROD 95.66 16,557.78 16,985.0 --. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 002-53,11/24/2015 10.38.40 AM SSSV:TRDP Last WO: 43.83 7/16/2004 vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 12,086.0 6/29/2011 Rev Reason:TUBING PATCH,GLV C/O pproven 11/25/2015 HANGER 328 'ol_ Casing Strings W. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(BOB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ■■ CONDUCTOR 16 15.052 37.0 114.0 114.0 62.40 H-40 WELDED I-�t., Casing Description -00(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread I HAI SURFACE 95/8 8.921 36.7 3,393.7 2,370.7 36.00 J-55 BTC ' Casing Descnplien OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Sat Depth(TVD)...Wt/Len(I...Grade Top Thread +� PRODUCTION 7 6.276 34.4 12,394.3 7,205.3 26.00 L-80 BTCM (�1 'I, Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I..Grade Top Thread ,, , OPEN HOLE 6 1/8 12,394.0 16.985.0 7,200.3 - E Tubing Strings t• Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Iblft) Grade Top Connection CONDUCTOR;37.0-114.0 TUBING 4.5"x3 5" 31/2 2.992 32.8 11,953.6 7,070.6 9.30 L-80 EUE-mod Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 32.8 32.8 0.00 HANGER FMC TUBING HANGER 4.500 • 122.5 122.5 0.13 XO Reducing 4.5",ID 3.958,12.68,EUEM,L-80 CROSSOVER TO 3.5" 3.500 le 2,310.9 1,804.3 59.52 SAFETY VLV CAMCO TRM-4E SAFETY VALVE 2.812 SAFETY VLV;2,310.9 OM} 11,803.1 6,997.4 58.19 SLEEVE-C BAKER CMPA SLIDING SLEEVE w/'X'PROFILE 2.812 (OPENS DOWN) 11,891.2 7,041.7 61.39 PACKER BAKER SAB-3 PACKER w/MILLOUT EXTENSION 3.875 11,941.2 7,065.0 63.11 NIPPLE HES XN NIPPLE NO GO w/2.812"POLISH BORE 2.750 11,953.1 7,070.3 63.52 WLEG BELL COLLAR WIRELINE GUIDE 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top not Top(ftKB) (BOB) (°) Des Com Run Date ID(in) 11,172.0 6,651.7 56.69 TUBING TOP BAKER KP Packer @ 11,180'KB 9/25/2015 1.920 SURFACE;36 73393.7-* • PATCH MIDDLE BAKER KP Packer @ 11,257'KB BOTTOM BAKER KP Packer @ 11,788'KB 1.71"ID"R"Nipple Profile at 11,800 KB s_ WLEG at 11,810'KB GAS LIFT;5,125.1 11,941.2 7,065.0 63.11 PLUG 2.81"XN-LOCK w/1.71"RN-NIP REDUCER 9/5/2015 1.560 (OAL=25")1.56"NO_GO ID Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(TVD) (ftKB) (BOB) (ftKB) (ftKB) Type Date Com GAS LIFT'9436.4 < 12,394.0 16,985.0 7,205.2 7,200.3 OPEN HOLE 3/6/2006 Frac job completed with 308014#behind pipe and FRAC 308054#total pumped Mandrel Inserts St all on Top(ND) Valve Latch Port Size TRO Run R Top(ftKB) (ftKB( Make Model OD(in) Sery Type Type (in) (psi) Run Date Com TUBING PATCH;11,172.0 1 5,125.1 3,397.2 CAMCO KBUG 1 GAS LIFT GLV BK-5 0.188 1,872.0 10/31/2015 2 9,439.3 5,701.3 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 10/30/2015 GAS LIFT;11,713.5 3 11,713.5 6,948.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/6/2015 11,, Notes:General&Safety End Date Annotation II' 7(18/2004 NOTE.TREE:FMC 4-1/165K-TREE CAP CONNECTION: 7"OTIS l9/3/2010 -NOTE:View Schematic w/Alaska Schematic9.0 ' 8/29/201) NOTE:WAIVERED WELL OA x OOA COMMUNICATION SLEEVE-C;11,803.1 11 3/1/2012 NOTE:Welded sleeve onto surface csg from bottom of starter head to 21.5'w/X65 12"x 500 wall pipe PACKER;11,891.2Wi NIPPLE;11,941.21 PLUG;11,941.2 WLEG;11,953.1 i le•e 4 PRODUCTION;34.4-12,394.3- "' OPEN HOLE FRAC;12,394.0 e e a e OPEN HOLE;12,394.0-16,985.0 2_04A _ o.lict • 2Ca0L WELL LOG TRANSMITTAL#902756105 DATA LOGGED k 0/2A/201S + K.BENDER To: Alaska Oil and Gas Conservation Comm. October 23, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED OCT 282015 RE: Packer Setting Record: CD2-53 � Run Date: 9/16/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD2-53 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20494-00 SCANNED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ��✓u� . u�, M���� �y 2O4k-on • • ��30\3 WELL LOG TRANSMITTAL PROACTIVE DIAGNOSTIC SERVICES, INC. To: AOGCC1r7, F: f � �„ DATA LOGGED Makana Bender to/2.72o15 333 West 7th Avenue M.K.BENDER Suite 100 ��� �`S Anchorage, Alaska 99501 1 8 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCANNED , 1) LeakPointTM Survey 12-oCT-15 CD2-53 BL/CD 50-103-20494-00 2) Signed : /'22AZ4IZL11' 6....eoueetDate : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE c, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFIles\Templates\Distribution\Transmittal5heets\Conowphillips_Transmit.docx zoo.-arc) • • zCo t 3 11111 BAKER PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: COMPANY Conoco Phillips Alaska Inc BP Exploration(Alaska)Inc. (mandatory) Petrotechnical Data Center, LR2-1 DATA LOGGED WELL NAME 1M-17; 1D-108;CD2-53;2L-311 900 E. Benson Blvd. et/$/2o16 �l.K.BENDER (mandatory) Anchorage, Alaska 99508 FIELD KUPARUK RIVER UNIT;W.SAK;ALPINE;TARN to acknowledge receipt of this data. (mandatory) COUNTY North Slope LOG TYPE MVRT-WireLine (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: TODAYS DATE: 29-Aug-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Paul Canizares EMAIL: Paul.CanizaresCa�bakerhughes.com (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #01-I'RIN I S #OF COPIES #OF COPIES #OF COPIES 1 ConocoPhillips Alaska Inc. 0 1 RAttn:Ricky Elgaricio „ O ATO 3-344 E ®Ef/ 1SEP G Street Anchorage,AK 99510 0 1 W Ci 2 State of Alaska -AOGCC 0 1 A0GCb Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 I I 3 Chevron/KRU Rep 0 1 Attn:Glenn Fredrick 310 K Street,Suite 406 Anchorage,AK 99501 4 BP Exploration(Alaska)Inc. 0 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 SCANNED MAI 01 `G 2016 Attn:David Douglas 5 DNR-Division of Oil&Gas *** 0 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 ConocoPhillips Alaska Inc. 0 0 I I Attn:Mick Davasher ATO-1490 700 G Street Anchorage,AK 99510 TOTALS FOR THIS PAGE: 0 0 5 0 0 0 TOTALS FOR ALL PAGES: 0 0 5 0 0 0 • 110 Zoe_o� � 2 Za % WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 11, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED°v3/2O15 M.K.BENDER Anchorage, Alaska 99501 FIECEIVRO RE: Patch Setting Record&Leak Detect Logs(x2): CD2-53 Run Date: 6/9/15 - 6/13/15 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD2-53 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20494-00 .5034 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signe `'aL 4L ,.e 4 STATE OF ALASKA • AL. :A OIL AND GAS CONSERVATION CON jSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon r Rug Perforations r Fracture Stimulate r" Pull Tubing r Operations Shutdown r Performed Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r" Other:Scale Inhibition Treatment57 2 Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 204-089 3.Address 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-103-20494-00 7.Property Designation(Lease Number) 8 Well Name and Number: ADL 380075,372097 CRU CD2-53 9.Logs(List logs and submit electronic and printed data per 20AAC25.071) 10.Field/Pool(s): none Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 16985 feet Plugs(measured) 11941 true vertical 7200 feet Junk(measured) none Effective Depth measured 16985 feet Packer(measured) 11891 true vertical 7200 feet (true vertical) 7042 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 3357 9.625 3394 2371 PRODUCTION 12360 7 12394 7205 RECEIVED ,;LI, 2 n 2(315 JUL 10 2015 Perforation depth: Measured depth: open hole completion from 12394' SCANNED True Vertical Depth: from 7205' AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 11954 MD, 7071 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER SAB-3 PACKER W/MILLOUT EXTENSION @ 11891 MD and 7042 TVD SAFETY VLV-CAMCO TRM-4E SAFETY VALVE @ 2311 MD and 1804 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 12394'-16985' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1293 897 352 902 209 Subsequent to operation shut-in 14 Attachments(required per 20 AAC 25 070,25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil Fr— Gas r WDSPL I-- Printed Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r" SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if c 0 Exempt none Contact Kerry Freedman @ 265-6579 Email Kerry.C.Freedman(cr�conocophillips.com Printed Name Ker Fr edman Title Principal Production Engineer Signature Phone:265-6579 Date 1�� , 2 p t S Form 10-404 Revised 5/2015 Submit Original Only CD2-53 Scale Inhibition Treatment 6/11/15 Hybrid Scale Inhibitor Squeeze Job pumped 6/11/15 05:30 to 21:45 hrs. LRS= Little Red Services - Initial pressure TBG/IA/OA—644/405/33 - LRS pumped 167 bbls Diesel/M209/WAW5206 preflush at 1.5 -2 bpm,TBG/IA/OA—0/492/45 - LRS pumped 167 bbls Seawater/SCW3001WC scale inhibitor main treatment at 1.5—2 bpm, TBG/IA/OA—0/619/101 - LRS pumped 1659 bbls Dead Crude/M209 overflush at 2 -3.6 bpm,TBG/IA/OA—539/984/67 Interval treated: 12,394'—16,985' ,;r WNS PROD CD2-53 e Conoc'h1 u s x3'st#, .}, Well Attributes Max Angle&MD TD P YF,"K', Wellbore API/DWI Field Name Wellbore Status ncl C) MD(ttKB) Act Btm(ttKB) Alaska,Inc 45', crrarroltxlliq 501032049400 ALPINE PROD 95 66 16,557 78 16,985 0 .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date CO2-53,7/12015 12 55 23 PM SSSV TRDP Last WO 4383 7/16/2004 Vertical schematic(actual) Annotation Depth(ttKB) End Date Annotation Last Mod By End Date Last Tag RKB 12,086 0 6/29/2011 Rev Reason SET PLUG hipshkf 7/1/2015 HANGER,320 1 011' Casing Strings � � � Casing Description OD(m) ID(n) Top(ttKB) Set Depth(RKB) Set Depth(TVD) Wt/Len(I-Grade Top Thread CONDUCTOR 16 15052 370 1140 1140 6240 H-40 WELDED g Casing Description OD On) ID On) Top(RKB) Set Depth(RKB) Set Depth(TVD) Wt/Len(I Grade Top Thread SURFACE 9 5/8 8 921 36 7 3,393 7 2,370 7 36 00 J-55 BTC ■� Casing Description OD tan) ID(In) Top(RKB) Set Depth(RKB) Set Depth(TVD) WtlLen(I Grade Top Thread I! PRODUCTION 7 6 276 34 4 12,394 3 7,205 3 26 00 L-80 BTCM 1,1 1 Casing Descnphon OD(In) ID(In) Top(ttKB) Set Depth(RKB) Set Depth(ND) Wt/Len(I Grade Top Thread 1J OPEN HOLE 6 1/8 12,394 0 16,985 0 7,200 3 _ Tubing Strings Tubmg Description String Ma ID On) Top(RKB) Set Depth(ft Set Depth(ND)( Wt(INft) Grade Top Connection TUBING 45"x35" 31/2 2992 328 11,9536 7,0706 930 L-80 EUE-mod CONDUCTOR,37 0-114 0 Completion Details Nominal ID Top(ftK8) Top(TVD)(RKB) Top Incl(') Item Des Com lin)32 6 32 8 0 00 HANGER FMC TUBING HANGER 4 500 I122 5 122 5 0 13 XO Reducing 4 5",ID 3 958,12 6#,EUEM,L-80 CROSSOVER TO 3 5" 3 500 2,310 9 1,804 3 59 52 SAFETY VLV CAMCO TRM-4E SAFETY VALVE 2 812 11,803 1 6,997 4 58 19 SLEEVE-C BAKER CMPA SLIDING SLEEVE w/'X'PROFILE 2 812 SAFETY VLV,2,3109 j II (OPENS DOWN) I 11,891 2 7,041 7 61 39 PACKER BAKER SAB-3 PACKER w/MILLOUT EXTENSION 3 875 11,941 2 7,065 0 63 11 NIPPLE HES XN NIPPLE NO GO w/2 812"POLISH BORE 2 750 11,9531 7,0703 6352 WLEG BELL COLLAR WIRELINE GUIDE 3000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(RKB) (ttKB) C) Des Corn Run Date ID(in) 11,941 2 7,065 0 63 11 PLUG 2 81"XXN PLUG 6/24/2015 0 000 Stimulations&Treatments SURFACE 36 7-3 393 7- Mm Top Max Btm Depth Depth Top(TVD) Btm(TVD) (RKB) (ftK8) (RKB) (RKB) Type Date Corn 12,394 0 16,985 0 7,205 2 7,200 3 OPEN HOLE 3/6/2006 Frac lob completed with 308014#behind pipe and FRAC 308054#total pumped GAS LIFT,5 125 1 Mandrel Inserts I St ° tI ^ Top(ND) Valve Latch Port Size TRO Run N Top(RKB) (ftK8) Make Model OD(In) Sery Type Type (In) (psi) Run Date Corn 1 5,1251 3,3972 CAMCO KBUG 1 GAS LIFT DMY BK-5 0 000 00 3/3/2006 I 2 9,439 3 5,701 3 CAMCO KBUG 1 GAS LIFT DMY BK 0 000 0 0 6)6/2015 3 11,713 5 6,948 9 CAMCO KBUG 1 GAS LIFT DMY BK 0 000 0 0 6/6/2015 GAS LIFT,9,439 4 I Notes:General&Safety End Date Annotation I 7/18/2004 NOTE TREE FMC 4-1/16 5K-TREE CAP CONNECTION T'OTIS 9/3/2010 NOTE View Schematic w/Alaska Schematic9 0 II8/29/2011 NOTE WAIVERED WELL OA x OOA COMMUNICATION I3/1/2012 NOTE Welded sleeve onto surface csg from bottom of starter head to 21 5'wl X65 12"x 500 wall pipe GAS LIFT,11,713 5 I I SLEEVE-C 11,8031 - I I L7 PACKER 11 e91 2 I NIPPLE,11,941 2 PLUG 11 941 2 s ifill,, I. WLEG,11,9531 illi PRODUCTION 34 4-12 394 3 '" OPEN HOLE FRAC,12 394 0 4 a OPEN HOLE 12,3940-16,9950 20z-t-0$°y 2.591 WELL LOG TRANSMITTAL DATA LOGGED /t4/2015 M K BENDER To: Alaska Oil and Gas Conservation Comm. June 23, 2015 Attn.: Makana Bender �. 333 West 7th Avenue, Suite 100 fit+E; ' a Anchorage, Alaska 99501 JUN 26 2U13 RE: Multi-Finger Caliper&Leak Detect Log: CD2-53 Run Date: 6/16/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD2-53 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20494-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC @halliburton.com Date: Signed: / ' vQgadsfA-d e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q 0 ~ - 0 ~ ç¡ Well History File Identifier Organizing (done) ~wo-sided ""111111111"1111 o Rescan Needed ""111111111111111 RESCAN ~color Items: o Greyscale Items: DIGITAL DATA ~iskettesJ No.;t o Other, NofType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: o Other: OVERSIZED (Non-Scannable) o Logs of various kinds: NOTES: o Other:: BY: ~ 151 mf 1111111111I111" III Date<6/~ J6b I~ rnp -=3 x 30 = q 0 +:;A Y- = TOTAL PAGES II 4- f l f (Count does not include cover sheet) m P Date: «5 d-8' ó t? 151 1111111111111111111 DaleY¡ I~I Ð0 Project Proofing BY: ~ Scanning Preparation BY: C Maria ) Production Scanning Stage 1 Page Count from Scanned File: II S (Count does include cover sheet) Stage 1 Page Count Matches Number in Scanning pretaration: ~ Date: g/~/6b If NO in stage 1, page(s) discrepancies were found: V YES YES NO 151 mf NO BY: BY: Maria Date: 151 111111111111111111I Scanning is complete at this point unless rescanning is required. ReScanned 11I1111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALAIlt OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other r Pump SC CMT shoe Alter Casing r Pill Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: — ConocoPhillips Alaska, Inc. Development F Exploratory r 204 -089 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r 0 50- 103- 20494 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL03800751ADL0372097 CD2 -53 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 16985 feet Plugs (measured) none true vertical 7200 feet Junk (measured) none Effective Depth measured 16985 feet Packer (measured) 11891 true vertical 7200 feet (true vertucal) 7042 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 3357 12 3394 2371 PRODUCTION 12360 10 12394 7205 OPEN HOLE 4591 6.125 16985 7200 RECEIVED SC Sleeve 22 10 22 22 MAY 072012 Perforation depth: Measured depth: Open hole 12394 - 16985 AOGCC Vertical Depth: Open Hole TVD 7205 - 7200 kd ' MAY 1 8 2012 AOGCC Tubing (size, grade, MD, and TVD) 3.5, L - 80, 11953 MD, 7070 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER SAB -3 PACKER W/ MILLOUT EXTENSION @ 11891 MD and 7042 TVD 12. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA Subsequent to operation NA 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r+ d Service r Stratigraphic r 16. Well Status after work: w Oil r Gas r WDSPL r Daily Report of Well Operations _X GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -140 Contact MJ Loveland Printed Name .,MJ Love! nd `Title WI Proj Supervisor Phone: Date Signature 41 /" ITV) y/ I N -1'/) 1 z �DMS MAY 0 7 ZOi2 Form 10 -404 Revised 11/2011 /?. C/72 -- Submit Original Only • • CD2 -53 DESCRIPTION OF WORK COMPLETED • SUMMARY Date Event Summary 04/14/12 PUMP 32.7 BBLS OF 15.7 PPG ARCTIC SET CEMENT DOWN OA. SPOT 13.7 BBLS OF 11.0 MUD PUSH II SPACER, FOLOWED BY 56.3 BBLS OF 10.8 PPG CaCl2 BRINE (CORROSION INHIBITED -51 DEG FREEZE POINT) 70 BBLS OF DISPLACEMENT AFTER CEMENT. NO FLUIDS ENTERED CELLAR DURING JOB. ALLOW CEMENT TO SET 72 HOURS PRIOR TO TESTING OA 04/18/12 Post cement job MITOA. (Failed) Initial T /I/O= si120/200/560. Strapped conductor © 27', found dirt/sand on bottom. No fluid present. Wrapped 3 of 4 flutes w/ absorb & shrink wrap. Pressured up OA to 1800 psi with .25 bbls of brine for 30 min test. Starting T/I/O= si140/240/1800. 15 min T/I/O= si140/240/1720. 30 min T/I/O= si140/240/1660. Re- pressured OA to 1820 psi and monitor. Starting T/I/O= si140/240/1820.15 min T/I/O= si140/240/1780.30 min T/I/O= si140/240/1780.45 min T/I/O= si140/240/1760. 1 hr T/I/O= si140/240/1740. 1 hr 15 min T/I/O= si140/240/1720. 1 hr 30 min T/I/O= si1401240/1710. 1 hr 45 min T/I/O= si140/240/1700. 2 hr T/I/O= si140/240/1680. 2 hr 15 min T/I/O= si140/240/1660. 2 hr 30 min T/I/O= si140/240/1640. 2 hr 45 min T/I/O= si140/240/1620. 3 hr T/I/O= si140/240/1600. 3 hr 15 min T/I/O= si140/240/1580. 3 hr 30 min T/I/O= si140/240/1540. 3 hr45 min T/I/0= si140/240/1540. 4 hr T/I/O= si140/240/1520. Continue in next cell 04/18/12 Bled OA down to 1200 psi (fluid), monitor 1 hr. Starting T/I/O= si130/220/1200. 15 min T/I/O= si130/220/1200. 30 min T/I/O= si130/220/1180. 45 min T/I/O= si130/220/1180. 1 hr T/I/O= si130/220/1160. Bled OA down to 950 psi (fluid), monitor 1 hr. Starting T/I/O= si130/220/920. 15 min T/I/O= si130/220/920. 30 min T/I/O= si130/220/910.45 min T/I/0= si130/220/910. 1 hr T/I/O= si130/220/900. Conductor was strapped at each 15 min interval to check for fluid. Did not find any trace of fluid. LLR was not obtained due to the small amount of fluid lost. Drilled and tapped another 1/2" hole in conductor on opposite side of catch drum /down spout. Night shift will continue to monitor and record WHPs through out shift. Final T/I/O= si130/220/900. 04/28/12 Initial T /I /O= 150/200/0. Mixed up 3 BBLS of 13.2# WT pill to pump down OA. Pumped for 20 min then shut OA in for 15 min to let settle and check returns. Repeated process until) all 3 BBLS was pumped down hole. Mixed up another 3 BBL batch of 13.5# WATE pill. Pumped 1 BBL with no problems while recieving 10.4# liquid in the return tank. Shut in for 15 min due to returning 13.5# pill. Opened and continued pumping last two BBLS of pill. Pump 1/2 bbl freeze protect. final T /I /0= 150/200/0 I 1 • CD2 -53 DESCRIPTION OF WORK COMPLETED ' SUMMARY 04/30/12 MITOA (Failed), Initial T /I /O= 140/220/170. OA FL @ SF. OA was left @ 0 psi yesterday, built up 170 psi over night. Pressured up OA to 1800 psi with 1 bbl of diesel. Noticed a slight leak out of the flange. Start MITOA, T /I /0= 140/225/1800, 15 min reading T /I /O= 140/225/1760, 30 min reading T /I /O= 140/225/1740, Changed out the crush ring on the OA flange. Repressure OA, Start MITOA, T /I /0= 140/225/1800, 15 min reading T /I /O= 140/225/1775, 30 min reading T /I /O= 140/225/1755, Repressure OA, Start MITOA, T /I /O= 140/225/1800, 15 min reading T /I /O= 140/225/1785, 30 min reading T /I /O= 140/225/1765, 45 min reading T /I /O= 140/225/1745, 60 min reading T /I /0= 140/225/1730. Repressure OA, Start MITOA, T /I /O= 140/225/1800, 15 min reading T /I /0= 140/225/1775, 30 min reading T /I /O= 140/225/1760, 45 min reading T /I /O= 140/225/1745, 60 min reading T /I /O= 140/225/1730. Bleed OA down (15 minute, all diesel) Final T /I /O= 140/225/0. Left top of conductor open and didn't install second down spout. 05 /02 /12INo Liquid in conductor, SC leak sealed. Summary (Pumped SC OA shoe and Gel Pill - Repaired SC leak at surface • SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 MJ Loveland Well Integrity Project Supervisor O ConocoPhillips Alaska, Inc. p • P.O. Box 100360 -- Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2 -53 Sundry Number: 312 -140 a r� c a Dear Ms. Loveland: 5 1 iED AP R G 6112. Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, A -/ Cathy ' . Foerster Chair DATED this I0 day of April, 2012. Encl. • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 April 3, 2012 RECEIVED •.. APR 0 4 ?o Commissioner Dan Seamount AOGCC Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well CD2 -53, PTD 204 -089 for pumping a surface casing cement shoe and pressure activated sealant if needed. Please contact Martin Walters or me at 659 -7043 if you have any questions. Sincerely, Ly R-/( MJ L veland ConocoPhillips Well Integrity Projects Supervisor Enclosures STATE OF ALASKA 0 PS ` /`d/ ` RECEIVED Z • ALA OIL AND GAS CONSERVATION COMNW, ION APR 0 42012 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AO9CC 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell r Change Approve Program r Suspend r Plug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other:Pump SC CMT shoe p • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Conoco Phillips Alaska, Inc. Development r • Exploratory r 204 -089 • 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20494 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No p CD2 -53 • 9. Property Designation (Lease Number): . Field /Pool(s): ADL03800751ADL0372097 Colville River Field / Alpine Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 16985• 7200 • 16985' 7200' none none Casing Length Size MD ND Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 3357 12 3394' 2371' PRODUCTION 12360 10 12394' 7205' OPEN HOLE 4591 6.125 16985' 7200' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Open hole 12394 - 16985 Open Hole TVD 7205 - 7200 3.5 L - 11953 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - BAKER SAB -3 PACKER W/ MILLOUT EXTENSION MD= 11891 ND= 7042 SSSV - Camco TRM-4E 2311 MD, 1804 ND 12. Attachments: Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/6/2012 Oil r--,. Gas r WDSPL r Suspended r 16. Verbal Approval: Date: 4/2/12 WINJ r GINJ r WAG r Abandoned r Commission Representative: Guy Schwartz GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland 1 Printed Name MJ Loveland Title: WI Proj Supervisor Signature % /3// Phone: 659-7043 Commission Use Only Sundry Number: 31 21 i O Conditions of approval: Notify Commission so that a representative may witness tt Plug Integrity r BOP Test r Mechanical IntegrityTest r Location Clearance r Other: Subsequent Form Required: j© .- L.% e l APPROVED BY q Approved by: tom- COMMISSIONER THE COMMISSION Date: 4" l U / �' For viJ J T�2�1 '� + 11-6 »I L " - Submit in Duplicate . •I +� LRIGINAL y 4 .r . + ' • • ConocoPhillips Alaska, Inc. Kuparuk Well CD2 -53 (PTD 204 -089) SUNDRY NOTICE 10 -403 REQUEST 4/2/12 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to pump a cement shoe in the surface casing of Alpine CRU well CD2 -53. A surface casing . cement shoe was not pumped at the time of original completion in 2004. The cement shoe is required in order to pressure test the surface casing and to locate and verify the size of a known surface casing corrosion penetration. If the cement shoe remediation results in a passing MITOA no additional work will immediately planned. If the cement remediation results in a failing MITOA, a pressure activated sealant will be pumped to repair the leak. With approval, the OA cement shoe will require the following general steps: 1. Pump cement designed for a 1000' linear shoe in the OA. 2. Displace cement with freeze protection fluids 3. Wait 48 hrs on cement i/ 4. MITOA to 1800 psi and / or establish LLR. 5. If MITOA fails establish circulation to conductor 6. Pump pressure activated sealant (Seal -Tite) 7. MITOA to 1800 psi 8. Submit 10 -404 to AOGCC. NSK Problem Well Supervisor 4/3/2012 Page 1 of 2 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, April 02, 2012 4:05 PM To: 'NSK Well Integrity Proj' Subject: RE: CD2 -53 (PTD 204 -089) 10 -403 Sundry Approval Request You have verbal approval to pump the SealTite repair as outlined in your email. Please submit sundry as soon as possible. 4- Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: NSK Well Integrity Proj [ mailto :N1878 @conocophillips.com] Sent: Monday, April 02, 2012 4:00 PM To: Schwartz, Guy L (DOA) Subject: FW: CD2 -53 (PTD 204 -089) 10 -403 Sundry Approval Request May have a verbal 10-403 approval for this work. Thank you MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 MJ's Cell (907) 943 -1687 :egrity Proj 02, 2012 3:07 PM L (DOA) (DOA) ; NSK Well Integrity Proj t (PTD 204 -089) 10 -403 Sundry Approval Request Guy, While pressure testing the external surface casing patch on CD2 -53 (204 -089, current Sundry 311 -265) an additional leak was located deeper than can be reached with our excavation methods. This email is a request for 10-403 Sundry approval to pump a surface casing cement shoe and pressure activated sealant (Seal -Tite) to repair the surface casing leak. This work requires support equipment that can only supplied during ice road season which closes in approximately 25 days. Your expedited approval of the 10 -403 is greatly appreciated. Please let me know if I need to send any additional information or whether I need to send an additional hard copy in the mail. Thank you in advance for accelerating the 10-403 process. Regards 4/6/2012 Page 2 of 2 • • MJ MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 MJ's Cell (907) 943 -1687 4/6/2012 t • v • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 p , 0 3 Fif t: 1 March 31, 2012 • r. Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission - 333 West 7 Avenue, Suite 100 as 4 .- 0 $ct Anchorage, AK 99501 I I Commissioner Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., well CD2 -53, PTD 204 -089, Sundry 311 -265 surface casing repair. After repairs were completed tests show that there is additional damage on the surface casing deeper than can be safely reached with an excavation. Please call MJ Loveland or Martin Walters at 659 -7043 if you have any questions. Sincerely, , / /// MJ Loveland ConocoPhillips Well Integrity Projects Supervisor � STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ❑ Repair w ell ❑ Plug Perforations ❑ Stimulate ❑ Other d SC repair Alter Casing ❑ Pull Tubing (j Perforate New Pool ❑ Waiver ❑ Time Extension in Change Approved Program ❑ Operat. Shutdown ❑ Perforate in Re -enter Suspended Well ❑ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ri Exploratory E - 204 -089 3. Address: 6. API Number: Stratigraphic ❑ Service ❑ — 50- 103 - 20494 -00 -' P. O. Box 100360, Anchorage, Alaska 99510 7. Property Designation (Lease Number): 8. Well Name and Number: ADL038007 .- CD2 -53 9. Field /Pool(s): Colville River Field / Alpine Oil Pool 10. Present Well Condition Summary: Total Depth ° measured 16985 feet Plugs (measured) None true vertical 7200 feet Junk (measured) None Effective Depth measured 16985 feet Packer (measured) 11891 true vertical 7200 feet (true vertucal) 7042 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 0 0 SURFACE 3357 12 3394 2371 0 0 PRODUCTION 12360 10 12394 7205 0 0 OPEN HOLE 4591 6.125 16985 7200 0 0 Sleeve 22 10 22 22 i 0 0 g1C� Perforation depth: Measured depth: Open hole 12394 -16985 2 True Vertical Depth: Open Hole TVD 7205 -7200 = � .E:'.. `,.''` _: ,.. Oot . Cormissicn Tubing (size, grade, MD, and TVD) 3.5, L -80, 11953 MD, 7070 TVD ?'t,'kcncrau8 Packers & SSSV (type, MD, and ND) PACKER - BAKER SAB -3 PACKER W /MILLOUT EXTENSION @ 11891 MD and 7042 TVD 11. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory ❑ Development tE, Service ❑ Stratigraphic ❑ X 15. Well Status after work: — Oil WI Gas ❑ WDSPL Daily Report of Well Operations GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -265 Contact MJ Lovel d /Martin Walters Printed Name J Lpv and :. Title Well Integrity Project Supervisor Signature . . 7 Rhone: 659 -7043 Date 3/31/2012 DMS APR 032012 ! � Form 10 -404 Revised 10/2010 2 / 0' '' 5ubmlt Original Only CD2 -53 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/04/12 SET DV @ 11,714' RKB. MITIA @ 2500 PSI. PASSED. PULLED CATCHER @ 11,941' RKB. BLED TBG /IA TO ZERO. COMPLETE. ** *MITIA pass pre TIO= 675/350/110, intiial TI0= 600/2540/120, 15min= 600/2530/120, 30min= 600/2530/120 * ** 02 /15 /12IExcavate to 25' and install shoring system. 02 /20 /12ILocate leak point 19' 5" below starter head. 02127 /12IStart installing external sleeve patch on surface casing from starter head to 21.5' 03/03/12 Finish welding sleeve & NDE passed. Total length of repair 21.5'. RU LRS and pump 3.2 bbls - pressured up to 1050 psi, continue pumping @ 1/2 bbls per mintute pressure leveled off @ 1150 psi, pump 10 bbls diesel - no indications of leaks on SC sleeve or below. Shut down pump - pressure @ 1125 psi - wait 5 minute pressure dropped 100 psi to 1025 psi, bleed to 0 and RD. Insulaters show up to denso wrap and notice fluid in conductor, indicating addditional leak. 03122 /12I Extended excavation to 34' and made several attempts to locate leak with no success. 03 /24 /12IStart replacing conductor. ce '7;:., ' t_; ;` �.?^. sn a` t'� t a a. 1✓ y$ °, T t .j• re Z r; ¢' k x , r and •.t r ! . k "'a` '4 x A r 7- 'k 'e h' ''' 4' 9 'Bs, ' } a' f y r F ti i P - - s * k k . s v a � ' F w z F ^f 3 ' l (+ Ys r 1 •�yz p ,� . '� v ` w R ' _ �s'„ 3 .rs fi ,k ...t `.. V `4 • { x 3 � ` ` O o CLr gy p , 0 n C) I . U • a' ' x-et E x. .. te'' .. 3i�. — w b ', ." v V - R 2 r te. 5 , t ' fi t' i t �M. .� T: r w; 23 7 ... '} K ap R b L �•.d �f ,, ; 1 , I 1111,1 1 I, Je �Er 41 01* 6 2' 12 8 22 9 23 0 231 2 c �3< 3 i a A r -.... '4 • y 9R d ' Iti*C* l e„ , . 11k, 1 > ' ■ " µ:f A' This photo is copy + OConoco Phillips . ConocoPhillips Alask. Y and cannot be releas published without expre , written consent of jai w. _ 3 • zum ALAss 1 , SEAN • PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. 04 0 7 P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2 -53 Sundry Number: 311 -265 � . ' • 5 Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this Z day of September, 2011. Encl. • • . • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 �"` /LJG3 201i August 28, 201 8r uag Cam. C! art 's 4fl ►t Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well CD2 -53, PTD 204 -089 surface casing inspection and repair. Please contact Martin Walters or me at 659 -7043 if you have any questions. Sincerely, / /,/ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures STATE OF ALASKA f� RECEIVED ALASKAW AND GAS CONSERVATION COMMISSI AUG 3 0 201 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Alaska ON & Gas Calk. Gommission 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r ChangAftinfagerogram r Suspend r Plug Fbrforations r Perforate r Pull Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other: SC repair r , 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r . Exploratory r 204 -089 3. Address: Stratgraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20494 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r CD2 -53 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL03800751ADL0372097 • Colville River Field / Alpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 16985 - 7200 , 16985' 7200' None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 3357 12 3394' 2371' PRODUCTION 12360 10 12394' 7205' OPEN HOLE 4591 6.125 16985' 7200' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Open hole 12394 -16985 Open Hole TVD 7205 -7200 3.5 L -80 11953 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER SAB -3 PACKER W /MILLOUT EXTENSION MD= 11891 TVD= 7042 SSSV - Camco TRM -4E 2311 MD, 1804 TVD 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: • Detailed Operations Program r BOP Sketch r Exploratory r Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/1/2011 Oil r . Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correc oto the best of my knowledge. Contact: MJ Loveland /Martin Walters F Printed Name MJ Loveland ,, ,.` Title: Well Integrity Project Supervisor Signature / 7/(lif-rf Phone: Date ">P -f � Commission Use Only Sundry Number:<j I \ ► r, U)6 Conditions of approval: Notify Commission so that a representative may witness ✓✓ v Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: - N().1-°.41 n,j --4ur 4..5 YhXiG • rii o l« - p 0 9.a-c e.4- -sb o4 l«- k f r Q / 'LAX . Subsequent Form Required: / -'10 tie , 41 pe . APPROVED BY / Approved Or OMMISSIONER THE C D t • + Form 10 -403 Revised 1/2010 0 R1G1N A L T--, �•`.`� � mlt in Du plicate � � : ;ii I • . ConocoPhillips Alaska, Inc. Kuparuk Well CD2 -53 (PTD 204 -089) SUNDRY NOTICE 10 -403 APPROVAL REQUEST August 28, 2011 This application for Sundry approval for Kuparuk well CD2 -53 is for the inspection and repair of a surface casing leak. 2CD -53 has started to show visual signs of a surface casing leak. Subsequent diagnostics suggest the leak is approximately 18' below the surface. ConocoPhillips requests approval to excavate, inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with a plug(s) and/or BPV. 2. Remove the floor grate, well house, flow lines, and other equipment from around the wellhead., 3. Remove gravel around well head and excavate up to 25'. 4. Install nitrogen purge equipment for the conductor (and OA if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC Inspector for opportunity to insp t — 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Install anti - corrosion coating as specified by CPAI Corrosion Engineer. 9. Replace the conductor and fill the void with cement and top off with sealant. 10. Backfill as needed with gravel around the wellhead. 11. Remove plug(s) and /or BPV and return the well to injection. 12. File 10 -404 with the AOGCC post repair. / Well Integrity Project Supervisor 8/28/2011 .1,-,-. WNS CD2 -53 ConocoPhillips it Well Attributes ax Angle & MD TD Wellbore APIIUWI Field Name Well Status Inc' (°) MD (RKB) Act Btm (RKB) U410.4fi41 kpa 501032049400 ALPINE PROD 95.66 16,557.78 16,985.0 Comment 925 (ppm) Date Annotation End Date KB - Ord (ft) Rig Release Date "' SSSV: TRDP Last WO: 43.83 7/16/2004 Well Confin - CD2 - 53, 2/25/2o114.49,47 PM Schematic - Actual Annotation Depth (MB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: FORMAT UPDATE Imosbor 2/26 /2011 Casing Strings Casing Description String 0... String ID ... Top (RKB) Set Depth (1... Set Depth (TVD) ... String Wt.. String ... String Top Thrd CONDUCTOR 16 15.052 37.0 114.0 114.0 62.40 H WELDED HANGER, 33 Casing Description String 0... String ID ... Top (RKB) Set Depth (r... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 36.7 3,393.7 2,370.7 36.00 J - 55 BTC - Casing Description String 0... String ID ... Top (RKB) Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 34.4 12,394.3 7,204.2 26.00 L BTCM J Casing Description String 0... String ID ... Top (RKB) Set Depth (t... Set Depth (TVD)... String Wt... String ... String Top Thrd OPEN HOLE 6 1/8 12,394.0 16,985.0 7,200.3 Tubing Strings Tubing Description String 0... String ID ... Top (RKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 4.5'x3.5" 3 1/2 2.992 32.8 11,953.6 7,070.5 9.30 L -80 EUE -mod • Completion Details Top Depth CONDUCTOR, (TVD) Top Inc1 Noml... • 37 -114 Top (RKB) (RKB) ( °) Item Description Comment ID (in) 32.8 32.8 -0.28 HANGER FMC TUBING HANGER 4.500 • • 122.5 122.5 0.13 XO Reducing 4.5 ", ID 3.958, 12.6#, EUEM, L -80 CROSSOVER TO 3.5" 3.500 • I 2,310.9 1,8042 58.92 SAFETY VLV CAMCO TRM-4E SSSV 2.812 11,803.1 6, 997.2 58.19 SLEEVE-C BAKER CMPA SLIDING SLEEVE wPX' PROFILE (CLOSED) 2.812 11,891.2 7,040.0 61.28 PACKER BAKER SAB -3 PACKER w /Millout Extension 3.875 SAFEry VLV, - 1 11,941.2 7,064.8 63.07 NIPPLE HESXN NIPPLE NO GO - 2.750 2,311 1 11,953.1 7,070.3 63.50 WLEG BELL COLLAR WIRELINE GUIDE 3.000 • ) Stimulations & Treatments Bottom Min Top Max !Um Top Depth Depth Depth Depth (TVD) (TVD) (RKB) (RKB) (RKB) MD) Type Date Comment 12,394.0 16,985.0 7,204.1 7,200.3 OPEN HOLE 3/6/2006 Fracjob completed with 308014# behind pipe and FRAC 308054# total pumped Notes: General & Safety SURFACE, End Date Annotation 37 - 3,394 7/18/2004 NOTE: TREE: FMC 4 -1/16 5K - TREE CAP CONNECTION: 7" OTIS fl 9/3/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GAS LIFT, 1 El 5,125 1 1 - GAS LIFT, 9,439 GAS LIFT SLEEVE -C _ 1 , ■ ■ 11,803 1 I PACKER C 11,591 NIPPLE, 11.941 1 a y Mandrel Details WLEG, 11.953 J Ir Top Depth Top Port (TVD) Inc! OD Valve Latch Site TRO Run Stn Top (RKB) (1195) l'1 Make Model (in) Sery Type Type ( (ps1) Run Date Com... 1 5,125.1 3,3972 50.14 CAMCO KBUG 1 GAS LIFT DMY BK-5 0.000 0.0 3/3/2006 2 9,439.4 5,701.4 56.77 CAMCO KBUG 1 GAS LIFT GLV BK-5 0.188 1,765.0 3/16/2006 3 11,713.6 6,947.0 54.90 CAMCO KBUG 1 GAS LIFT OV BK-5 0.250 0.0 3/16/2006 PRODUCTION, 34-12,394 LN, OPEN HOLE FRAC, 12,394 OPEN HOLE, 12.394- 16,985 TD, 18,985 STATE OF ALASKA ALASKA •AND GAS CONSERVATION COMMISSI• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon f Repair well r" Rug Perforations r Stimulate Fro Other r Alter Casing E Pull Tubing [ Perforate New Pool r Waiver E Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r , 204 -089 3. Address: 6. API Number: Stratigraphic r Service r" P. O. Box 100360, Anchorage, Alaska 99510 — 50- 103 - 20494 -00.00 7. Property Desigraatio ,(Lease Number): 8. Well Name and Number: ADL 380075, 372097 • CD2 -53 9. Field /Pool(s): ., Colville River Field / Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 16985 feet Plugs (measured) None true vertical 7200 feet Junk (measured) None Effective Depth measured 16985 feet Packer (measured) 11891 true vertical 7200 feet (true vertucal) 7042 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 3357 9.625 3394 2371 PRODUCTION 12360 7 12394 7205 lH , NEED A , r 6x `i � ,,- i tom . . Perforation depth: Measured depth: open hole completion 12394' 16985' True Vertical Depth: 7205' -7200' ?hy ':.76: tars; 'L,titt°l f;.,1t4 ",NUSiOfif Tubing (size, grade, MD, and TVD) 4.5 x 3.5, L -80, 11953 MD, 7070 TVD - ;1iCiV.,t 446, Packers & SSSV (type, MD, and TVD) PACKER - BAKER SAB -3 PACKER W /MILLOUT EXTENSION @ 11891 MD and 7042 TVD SSSV - CAMCO TRM -4E @ 2311 MD and 1804 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): 12394' - 16985' Treatment descriptions including volumes used and final pressure: see attached summary 12. Representative Daily Average Production or Injection Data ! Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 1392 2085 90 -- 238 Subsequent to operation 1378 1751 125 -- 242 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development rvI - Service r Stratigraphic r 15. Well Status after work: o Oil j✓ Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Dan Kolesar na 263 -4039 Printed Name Dan Kolesar Title WNS Production Optimization Engineer Signature Phone: 263 -4039 Date '. . t( REIMS AUG 0 4 Y•• `( Form 10 -404 Revised 10/2010 Submit Original Only Y • • CD2 -53 (Hybrid) APD # 204 -089 7/16/2011: initial pressure TBG /IA/OA- 900/1000/0; LRS pumped 9 bbls dead crude containing 91gal WAW5206 at 1.5 bpm, 950/1000/0; LRS pumped 96.4 bbls SW and SCW3001WC (605 gal SCW3001WC) at 4 bpm, VAC /1000/0; LRS pumped 9 bbls of dead crude containing 91 gal WAW5206 at 4 bpm, VAC /1000/0; LRS pumped 1163 bbls crude at 4.2 bpm overflush, VAC /1200/0. i :�tt `1 f . - °, WNS • CD2 -53 • Cc� ; 1 Well Attributes Max Angle &_M TD Alaska. fnc. .,- -: -',1,-i-; _ Wellbore APWI Field Name Well Status • Inc! ( °) MD (ftKB) Act Btm (ftKB) cs:�nl,i». r` UU 501032049400 ALPINE I PROD 95 - 66 16,55778 16,985.0 Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date "' SSSV TRDP Last WO: 43 83 7/16/2004 ` — Aa Nd A nota Depth (ftKB) ' End Date [Annotation Last Mod ._ End Date V Last Tag � , — Rev Reason FORMAT UPDATE I I mosbor 2/26/2011 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f -.- Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.052 37.0 114.0 114.0 62.40 H -40 WELDED t HANGER, 33 Casing De scription Siring 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String WI... String . String Top Thrd SURFACE 9 5/8 8.921 36.7 3,393.7 2,370.7 36.00 J BTC Casing Des dptio String 0... String ID ... Top 5tKB) Set Depth (f... Set Depth (TVD) ... Siring Wt... String String Top Thrd v PRODUCTION 7 6.151 34.4 12,394 3 7,204.2 26.00 L BTCM Casing Description String 0... String ID Top (ftKB) Set Depth (8... Set Depth (TVD) ... String Wt... String .. String Top Thrd H:i OPEN HOLE 6 1/8 12,394.0 16,985 0 7,200.3 Tubing Strings Tubing Description String O Str g ID Top (ftKB) Set Depth (f Set Depth (TVD) .. String Wt... String .. String Top Thrd I TUBING 4.5'x35 31/2 I 2992 � _ 3 25 11,9536 70705 1 9 -30 L-80 EUE -moll I Completion Details Top Depth CONDUCTOR, (TVD) Top 1951 Nomi... 37 -114 Top (ftKB) (ftKB) (°) Item Description Comment ID(in) 32.8 32.8 -0.28 HANGER FMC TUBING HANGER 4.500 i 122.5 122.5 0.13 XO Reducing 4.5', ID 3.958, 12.6 #, EUEM, L-80 CROSSOVER TO 3.5" 3.500 2,310.9 1,804.2 58.92 SAFETY VLV CAMCO TRM-4E SSSV 2.812 11,803.1 6,997.2 58.19 SLEEVE -C BAKER CMPA SLIDING SLEEVE w!'X' PROFILE (CLOSED) 2.812 i t 11,891.2 7,040.0 61.28 PACKER BAKER SAB-3 PACKER w/Millout Extension 3.875 SAFETY VLV, _ 11,941.2 7,064.8 63.07 NIPPLE HES XN NIPPLE NO GO 2.750 2,311 11,953.1 7,070.3 63.50 WLEG BELL COLLAR WIRELINE GUIDE 3.000 I I Stimulations & Treatments `"b ` i tt x ni Bottom Min Top Max Btm Top Depth Depth /I ' i Depth Depth (TVD) (TVD) i (ftKB) (NKB) (ftKB) (ftKB) Type Date Comment 1 12,394.0 16,985.0 7,204 -1 7,200.3 OPEN HOLE 3/6/2006 Frac job completed with 308014# behind pipe and FRAC 308054# total pumped Notes: General & Safety SURFACE, _ ! End Date Annotat 37 - 3,394 - 7/18/2004 NOTE: TREE: FMC 4 -1/16 5K - TREE CAP CONNECTION- 7" OTIS 9/3/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GAS LIFT, 5,125 GAS , IFT, ._: -:. ,439 GAS LIFT, 11,714 it it SLEEVE-C, - - 11,903 IF PACKER, ...._.- 11,891 it 1 NIPPLE,11,901 - -- -�. Mandrel Detail , , WLEG, 11,953 - - -'- Top Depth Top i Port (TVD) Intl OD Valve Latch 540 TRO Run Stn Top (ftKB) (ftKB) (`) Make Model (,n) Sony Type type (in) (pal Run Date Con,. 1 5,125.1 3,397.2 50.14 CAMCO KBUG 1 GAS LIFT DMY BK -5 0.000 0.0 3/3/2006 .1 2 9,439.4 5,701.4 56.77 CAMCO KBUG 1 GAS LIFT GLV BK -5 0.188 1,765.0 3/16/2006 3 11,713.6 6,947.0 54.90 CAMCO KBUG 1 GAS LIFT OV BK -5 0.250 0.0 3/16/2006 PRODUOT,3N, 30-12 Vi OPEN HOLE xs>; FRAC, 12,394 " OPEN HOLE, 12,394- 16,985 ;3:,-- ^.7=117_ TD, 16,985 ' - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ~° Repair w ell Plug Fi?rforations ~'" Stimulate Other °" Alter Casing ""` Pull Tubing " Perforate New Pbol ~ Waiver Time Extension Change Approved Program Operat. Shutdown '"" Perforate ~ Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~` Exploratory ~ 204-089 3. Address: Stratigraphic ~"' Service .API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20494-00 7. Property Desigl~tion: 8. Well Name and Number: ` ADL 380075, 372097 CD2-53 Field/Pool(s): Colville River Field /Alpine Oil Pool 10. Present Well Condition Summary: Total Depth measured 16985 feet Plugs (measured) None true vertical 7200 feet Junk (measured) None Effective Depth measured 16985 feet Packer (measured) 11891 true vertical 7200 feet (true vertucal) 7042 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114 114' SURFACE 3358 9.625 3394 2371' PRODUCTION 12358 7 12394 7205' .~ ~; i~ ~ \~~ M ~~ ~ C i <~e ~~.~kkH~G~ MYl~~ ' ~~~ 3 2~1d Perforation depth: Measured depth: open hole completion from 12394 True Vertical Depth: 7205' Alaska ~l~ ~ ~;~5 Cpf1S, Commi~sivey /~enehorage Tubing (size, grade, MD, and TVD) 3.5, L-80, 11954 MD, 7071 TVD Packers &SSSV (type, MD, and TVD) PACKER -BAKER SAB-3 W/MILLOUT EXTENSION @ 11891 MD and 7042 TVD TRDP - CAMCO TRM-4E SSSV @ 2311 MD and 1804 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): I1011e Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2206 2682 74 -- 264 Subsequent to operation 2205 2384 102 -- 291 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory Development Service ~`~`;, 5. Well Status after work: Oil GaS WDSPL Daily Report of Well Operations XXX GSTOR WAG ~" GASINJ WINJ ~ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.o. Exempt: none contact Tim Schneider ~ 265-6859 Printed Name Tim Schneider Title Staff Production Engineer Signature ~'" ~' Phone: 265-6859 Date _. _ ~ ~ ~ ~/ ".~ d ~ ~ ~ 3 3•w Form 10-404 Revised 7/2009 RBDM~ MAR 0 3 2010~~~ Submit Original Only CD2-53: Job pumped 2145 to 450 am 2-7-10. Hybrid squeeze; 10 bbls pre & ,/ post flush crude oil with WAW 5206 (160 gal) @ 2 bpm/800 psi; 87 bbls SW/SCW-3001WC (550 gal) @ 3 bpm/vacuum; 1163 bbls dead crude @ initially 4 bpm reduced to 2.8 bpm/vacuum. Well SI for 20 hrs. after squeeze before returning to production. "~ '~• ALPINE `~ C~nc~coPhill'tPs A1~~Ic~, Inc. .. CD2-~3.~_- __. _ ~_ . ._. -~~ ~ API: 501032049400 WeILType: PROD (0 1 "~~ SSSV Type: TRDP Orig Completion: 7/16/2004 OD:3.500, ID:2.992) Annular Fluid: Last W(O: PRODUCTION '. (0-12394, ---~- - oD:7.oo0, Reference Log: , 36' RKB ___ Ref Log Date: , _ wc26.oo) Last Tag: __._ TD: ', 16985 ftKB Gas Lift andrel/Dummy Valve 1 (5125-5126, OD:5.390) Gas Lift Mandrel/Valve 2 (9439-9440, Gas Lift Mandrel/Valve 3 ;1 n14-1 ms, OD:5.390) SLEEVE-C ;11803-11804, OD:5750) PACKER ,11891-11892, OD:5.970) NIP ;11941-11942, OD:3 750) CD2-53 Angle @ TS;_ deg @ Angle @ TD: 94 deg @ 16985 Rev Reason: FRAC, GLV C/O, 3.500 Or 11954 7070 9.30 L-80 EUE Stimulations & Treatments Interval Date Type Comment 12394 - 16985 3/6/2006 OFE~I HOLE FRAC I Frac job completed with 308014# behind pipe and 308054# total pumped Gas Lift Mandrels/Valves St MD TVD Man Mfr; Man Type i V Mfr i V Type V OD ', Latch Port TRO ~ Date Vlv Run , Cmr 2311 1805 SSSV CAfv1 11803 6997 SLEEVE-C BAKI 11891 7041 PACKER BAK:I 11941 '' 7064 NIP HES 11954 7070 WLEG BELL General Notes Date Note 7/18/2004 TREE: FMC 4-1/16 51< OPEN HOLE FRAC ;12394-16985) OPEN HOLE , ;12394-16985, L_ • • MICROFILMED 03/01/2008 DO NOT PLACE :_= ,. ~~~ ~; ~., ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFicheiCbrPgs_InsertslNticrofilm Marker.doc ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 11, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED APR 21 ¡k.QD 7 ~~,o~q ~()~ Dear Mr. Maunder: Sorry for the inconvenience, however it was observed that a spreadsheet sent to you and dated 3/31/07 was incomplete. Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). It was noticed that Alpine well CD2-404 was unintentionally left out of spreadsheet dated 3/31/07. Please find enclosed updated spreadsheet, and replace. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.l. Loveland at 907-659-7043, if you have any questions. Sincerely, ~.l::~~ ConocoPhillips Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off 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 gal C02-1 205-118 4" na 4" na 2 2/18/2007 C02-2 205-109 6" na 6" na 2.5 2/18/2007 C02-404 206-054 6" na 6" na 1.8 3/22/2007 C02-7 203-187 16" na 16" na 7.5 2/17/2007 C02-9 202-129 22" na 22" na 10.5 2/17/2007 C02-12 203-073 16" na 16" na 7.5 2/17/2007 C02-14 201-177 4" na 4" na 2 2/17/2007 C02-15 201-159 12" na 12" na 5.7 2/17/2007 C02-16 202-144 117" 1.6 4" 4/16/2003 1 3/8/2007 C02-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 C02-18 203-151 36" na 36" na 17 2/17/2007 C02-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 C02-21 204-245 6" na 6" na 2.5 2/18/2007 C02-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 C02-24 201-095 6" na 6" na 1 3/8/2007 C02-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 C02-28 202-217 29" na 29" na 11 3/8/2007 C02-30 203-135 8" na 8" na 3 3/8/2007 C02-31 204-082 15" na 15" na 6 3/8/2007 C02-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 C02-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 C02-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 C02.37 202-211 29" na 29" na 13.8 2/18/2007 C02-38 202-171 18" na 18" na 8.5 2/18/2007 C02-39 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CÐ2<163 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 3/8/2007 CO2-58 203-085 6" na 6" na 1 3/8/2007 CO2-59 204-248 6" na 6" na 1.5 318/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 . . ~ ConocoPhillips Alaska ., P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 M'~ March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 CANNED AP¡~ 0 9 2007 Anchorage, AK 99501 5 ' aðlf-o<ðq Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, L~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off 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 gal C02-1 205-118 4" na 4" na 2 2/18/2007 C02-2 205-1 09 6" na 6" na 2.5 .2/18/2007 C02-7 203-187 16" na 16" na 7.5 2/17/2007 C02-9 202-129 22" na 22" na 10.5 2/17/2007 C02-12 203-073 16" na 16" na 7.5 2/17/2007 C02-14 201-177 4" na 4" na 2 2/17/2007 C02-15 201-159 12" na 12" na 5.7 2/17/2007 C02-16 202-144 11'7" 1.6 4" 4/16/2003 1 3/8/2007 C02-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 C02-18 203-151 36" na 36" na 17 2/17/2007 C02-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 C02-21 204-245 6" na 6" na 2.5 2/18/2007 C02-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 C02-24 201-095 6" na 6" na 1 3/8/2007 C02-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 C02-28 202-217 29" na 29" na 11 3/8/2007 C02-30 203-135 8" na 8" na 3 3/8/2007 C02-31 204-082 15" na 15" na 6 3/8/2007 C02-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 C02-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 C02-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 C02-37 202-211 29" na 29" na 13.8 2/18/2007 C02-38 202-171 18" na 18" na 8.5 2/18/2007 C02-39 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 . 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 3/8/2007 CO2-58 203-085 6" na 6" na 1 3/8/2007 CO2-59 204-248 6" na 6" na 1.5 3/8/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cornm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 29, 2006 RE: MWD Formation Evaluation Logs: CD2-35A, CD2-37, CD2-40_PB1, CD2-53, CD2-54 Ll. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 CD2-35A: U"I-Œ- 9Öd -d-4¿1 ~'-.(3 '?)1) Digital Log Images: 50-103-20256-01 1 CD Rom CD2-37: 9b'd--9\1 r!: tL/3t5'ì Digital Log Images: 50-103-20434-00 SCANNED FEB 0 1 2007 1 CD Rom CD2-40_PB1: LJ:rc...'dO'3-l~(P .p.1L.13~ò I Digital Log Images: 50-103-20464-00, 70 1 CD Rom CD2-53: 'd ()L{ -o1f1 ~ L(3D¡ J Digital Log Images: 50-103-20494-00 1 CD Rom oxc. CD2-54_ L1: V IC- 9c/-I- (}75 ttI43D¡~ ;)6'--1 -&ö~ 11 IL/~3 Digital Log Images: I 50-103-20499-00,60 1 CD Rom 1- ~ A-~ DATA SUBMITTAL COMPLIANCE REPORT 8/2/2006 5' ~) j+, ÑN '-t API ~ 50-103-20494-00-00 Permit to Drill 2040890 Well Name/No. COLVILLE RIV UNIT CD2-53 Operator CONOCOPHILLlPS ALASKA INC MD 16985 /' TVD 7200 / Completion Date 7/18/2004 Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Directional survey~ - Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GRlRes Well Log Information: (data taken from Logs Portion of Master Well Data Maint . Log/ Data Digital Type Med/Frmt ~D Asc R~ ~D Electr Dataset Number Interval Start Stop Log Log Run Scale Media No OH/ CH Received 8/5/2004 8/5/2004 8/5/2004 8/5/2004 9/3/2004 Name Directional Survey Directional Survey Directional Survey Directional Survey Gamma Ray Comments IIFR IIFR MWD MWD MWD, GR, EWR, ASI ROP PWD MWD,GR, EWR, ROP, ASI, PWD ROP DGR EWR plus Graphics Rp./ D -EIS Lis 12640 3365 16919 ~/s ~C Lis 12640 LIS Verification 3357 16985 9/3/2004 13655 Induction/Resistivity 114 16985 Open 2/22/2006 Well Cores/Samples Information: Sample Set Number Comments Interval Start Stop . Name Sent Received ADDITIONAL INFORMf(.tON Well Cored? Y k...> ~N Q)N Daily History Received? Chips Received? ~ Formation Tops ~ Analysis Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 8/2/2006 Permit to Drill 2040890 Well Name/No. COLVILLE RIV UNIT CD2-53 Operator CONOCOPHILLlPS ALASKA INC MD 16985 TVD 7200, ( Completion Date 7/18/2004 Compliance Reviewed By: ~ Completion Status 1-01L Current Status 1-01L Date: ~ 1 API No. 50-103-20494-00-00 UIC N ~ ~)o . . 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: . Kt:tA::1 V a...:U . APR 0 5 Z006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Repair Well 0 Pull Tubing 0 Opera!. ShutdownO P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 36',52' AMSL 8. Property Designation: ADL 380075, 372097 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION OPEN HOLE Perforation depth: Alaska Oil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage o Time Extension 0 o measured true vertical measured true vertical Length 80' 3358' 12358' 4591' 16985' 7200' Size 16" 9-5/8" 7" 6.125" Measured depth: open hole true vertical depth: open hole Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development Q Stratigraphic 0 Stimulate Q Waiver 0 Other Service Re-enter Suspended Well 5. Permit to Drill Number: 204-089 / 306-072 6. API Number: 50-103-20494-00 Exploratory 0 o 9. Well Name and Number: CD2-53 10. Field/Pool(s): Colville River Field / Alpine Oil Pool feet feet feet feet Plugs (measured) Junk (measured) MD TVD Burst Collapse 114' 3394' 12394' 16985' 114' 2371' 7205' 7200' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 11954' MD. Packers & SSSV (type & measured depth) Baker SAB-3 pkr @ 11891' Cameo TRM-4E SSSV @ 2311' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 12394' - 16985' md 13. Treatment descriptions including volumes used and final pressure: see summary attached Representative Daily Average Production or Injection Data Gas-Me! Water-Bbl 1942 0 3500 23 15. Well Class after proposed work: Exploratory 0 Development Q Service 0 16. Well Status after proposed work: OilQ GasO WAG 0 GINJO WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry NU,~~ ~._·7 EX~'l Å Contact Tim Schneider @ 265-6859 E-- / Printed Name : "?r SCh. neider Signature --rt; .JA-,..¿.;;¡¿.. Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Form 10-404 Revised 04/2004 Oil-Bbl 1526 / 4257 / CasinQ Pressure TubinQ Pressure 292 302 WDSPL 0 Title Phone Staff Production Engineer Date y~ Y--D0. Prevared by Sharon AI/suo-Drake 263-4612 RBDMS BFl APR . 5 zona. ~ "\(ç- .4.1> t/." . o'=- (_y~ su:¿ 'fJ/Ø Only " t l \~AL . . CD2-53 Stimulation results: Summary of stimulation job: 3-06-06: Pump frac stages in stair steps; 2,4, & 7 PP A, 2125 bbls total slurry, 119 bbls diesel for freeze protect.. AIR-20.5 BPM, AIP-5433 psi, ISIP-1255 psi. 308,014lbs. 16/30 White Smd~pcr&. , Well test 3/30/06: 4257 bopd, 23 bwpd, 3.35 mmcfpd, 302 psi WHP / TUBING (0-11954, 00:3.500, 10:2.992) 'ROOUCTION (0-12394, 00:7.000, W:26.00) ConocoPhillips AlaSka.. . ALPINE API: 501032049400 SSSV Type: TRDP Well Type: PROD Orig 7/16/2004 Completion: Last W/O: Ref Log Date: 1D: 16985 ftKB Max Hole Angle: 96 deg @ 16558 CD2-53 Angle @ TS: deg @ Angle @ TD: 94 deg @ 16985 Annular Fluid: Reference Log: 36' RKB Last Tag: Last Tag Date: Rev Reason: GLV design Last Update: 12/4/2004 Description Size Top Bottom TVD Wt CONDUCTOR 16.000 0 114 114 62.40 PRODUCTION 7.000 0 12394 7205 26.00 Gas Lift SURFACE 9.625 0 3394 2371 36.00 I andrelNalve 1 OPEN HOLE 6.125 12394 16985 16985 0.00 (5125-5126. Top Bottom TVD Wt Grade 0 11954 7070 9.30 L-80 St MD TVD Man Man Type V Mfr Mfr Gas Lift 1 5125 3397 CAMCO KBUG I andrelNalve 2 9439 5701 CAMCO KBUG 2 (9439-9440. 3 11714 6949 CAMCO KBUG Gas Lift I andrelNalve 3 1714-11715. 005.390) SLEEVE-C 1803-11804. 00:5.750) PACKER 1891-11892. 005.970) NIP 1941-11942. 003.750) OPEN HOLE 12394-16985, 006.125) V Type VOD Latch Port TRO GLV 1.0 BK-5 0.188 1689 GLV 1.0 BK-5 0.188 1718 OV 1.0 BK-5 0.250 0 Description Depth TVD 2311 1805 11803 6997 11891 7041 11941 7064 11954 7070 General Date I Note 7/18/2004 TREE: FMC 4-1/16 5K TREE CAP CONNECTION: 7" OTIS Type SSSV SLEEVE-C PACKER NIP WLEG CAMCO TRM-4E SSSV BAKER CMPA SLIDING SLEEVE - CLOSED SAKER SAB-3 w/MILLOUT EXTENSION HES 'XN' NIPPLE BELL COLLAR WIRELlNE GUIDE Grade H-40 L-80 J-55 Thread WELDED STCM BTC Thread EUE Date Vlv Run Cmnt 11/3/2004 11/3/2004 11/4/2004 ID 2.812 2.812 3.000 2.750 3.000 . . ConocóP'hillips . Tim Schneider Staff Production Engineer Alpine Engineering P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6859 April 4, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for C02-53 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation activity on the Alpine well C02-53. If you have any questions regarding this matter, please contact me at 265-6859. Sincerely, J!lP~ T. Schneider Staff Production Engineer CPAI Alpine Engineering TSS/skad .. .. mm·..·· ~~Aì ~. fAì (êùl(( f$I 'c J IA\ ~~!J~ Qi) .~ ~ Ln1 / AI,ASIiA OIL AND GAS / CONSERVA'DON CO!IDIISSION Ie ~~!Æ~~ FRANK H. MURKOWSKI, GOVERNOR 333 W. ]'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Schneider Staff Production Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Colville River CD2-53 Sundty Number: 306-072 Dear Mr. Schneider: Enclosed is the approved Application for Sundty Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this> decision, or such further time as the Commission grants for good ca1:l8e; shown, a person affected by it may fIle with the Commission an applicati6n< for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this.11day of February, 2006 Encl. . Conoc6Phillips . Tim Schneider Staff Production Engineer Alpine Engineering P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6859 February 24, 2006 REceiVED FEB 2 7 2006 Afaska Oil & Gas Cons Cn.rnn.; . . "..0In88'On Anchorage Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for C02-53 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Alpine well C02-53. If you have any questions regarding this matter, please contact me at 265-6859. Sincerely, /" ~-¡(1L£ T. Schneider Staff Production Engineer CPAI Alpine Engineering TSS/skad h ~!AL .fTs :¿j1J! ç . STATE OF ALASKA Mz... (¡_ ALASKA OIL AND GAS CONSERVATION COMMISSION þJ-J :¡.'\ APPLICATION FOR SUNDRY APPROVAL RECEIVED 20 AAC 25,280 Operational Shutdown D Plug Perforations D Perforate New Pool D 1. Type of Request: D D D Suspend D D D Abandon Alter casing Repair well Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. 0, Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 36'.52' AMSL Pull Tubing 8. Property Designation: ADL 380075, 372097 11. Total depth MD (ft): 16985' Casing CONDUCTOR SURFACE PRODUCTION OPEN HOLE Total Depth TVD (ft): Effective Depth MD (ft): 7200' Length 80' 3358' 12358' 4591' Perforation Depth TVD (ft): open hole March 2, 2006 Date: D waiveFEfèJ2 " 2Lilltkr D o AltskaeØi~& fUs Cons. Commissi m Re-enter Suspended Well AliWhoraoe 5. Permit to Drill Number: 204-089 V 6. API Number: Perforate Stimulate 4. Current Well Class: Development Stratigraphic o D Exploratory D Service D 50-103-20494-00 9. Well Name and Number: CD2-53 10. Field/Pool(s): Colville River Field / Alpine Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): Tubing Size: 3-1/2" Packers and SSSV MD (ft) 11891 ' 2311' 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D Contact: Title: Phone Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Size MD TVD Burst Collapse 16" 114' 114' 9-5/8" 3394' 2371' 7" 12394' 7205' Hf1Ç' 16985' 7200' ~\I~~ ;JI)~ Perforation Depth MD (ft): open hole Packers and SSSV Type: Baker SAB-3 pkr @ Camco TRM-4E SSSV @ 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name . ~ AChn~ider Signature --r- ~(.1¡'hJ2.::fL Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: :~:~~~~Fom (b2D Form 10-403 Revised 7/2005 Tubing Grade: L-80 Tubing MD (ft): 11954' Service D Plugged D WINJ D Abandoned D WDSPL D Tim Schneider @ 265-6859 Staff Production Engineer Date 2 - G «~ I) G, SUndry Number: ..:3o~-C!!J?;;;- RBDMS 8Ft FEE 2 8 2006 '~~IS~~~I;^, I ':..c i \........... APPROVED BY THE COMMISSION Date: Z, '" ~ i-,,(),b Submit in Duplicate TUBING (0-11954. 00:3.500. 10:2.992) 'RODUCTION (0-12394, 00:7.000. W:26.00) Gas lift landrelNalve 1 (5125-5126, ConocoPhillips AlðSk.. , - . ALPINE Well Type: PROD Orig 7/16/2004 Completion: Last W/O: Ref Log Date: lD: 16985 ftKB Max Hole Angle: 96 deg @ 16558 API: 501032049400 SSSV Type: TRDP Annular Fluid: Reference Log: 36' RKB Last Tag: Last Tag Date: Description CONDUCTOR PRODUCTION SURFACE OPEN HOLE Size 3.500 Size 16.000 7.000 9.625 6.125 Bottom 114 12394 3394 16985 TVD 114 7205 2371 16985 Top o o o 12394 Type SSSV SLEEVE-C PACKER NIP WLEG St MD TVD Man Man Type V Mfr Mfr Gas lift 1 5125 3397 CAMCO KBUG I andrelNalve 2 9439 5701 CAMCO KBUG 2 (9439-9440, 3 11714 6949 CAMCO KBUG Depth TVD 2311 1805 11803 6997 11891 7041 11941 7064 11954 7070 GêñêtâlNôtø$ Date I Note 7/18/2004 TREE: FMC 4-1/16 5K TREE CAP CONNECTION: 7" OTIS CAMCO TRM-4E SSSV BAKER CMPA SLIDING SLEEVE - CLOSED BAKER SAB-3 w/MILLOUT EXTENSION HES 'XN' NIPPLE BELL COLLAR WIRELlNE GUIDE CD2-53 Angle @ TS: deg @ Angle @ TD: 94 deg @ 16985 Rev Reason: GL V design Last Update: 12/4/2004 Wt 62.40 26.00 36.00 0.00 Grade H-40 L-BO J-55 Thread WELDED BTCM BTC Gas Lift landrelNalve 3 1714-11715, 00:5.390) SLEEVE-C 1803-11804, 00:5.750) PACKER 1891-11892. OD:5.970) NIP 1941-11942, OD:3.750) OPEN HOLE 2394-16985. OD6.125) Grade L-80 V Type VOD Latch Port TRO GLV 1.0 BK-5 0.188 1689 GLV 1.0 BK-5 0.188 1718 OV 1.0 BK-5 0.250 0 Description Thread EUE Date Vlv Run Cmnt 11/3/2004 11/3/2004 11/4/2004 ID 2.812 2.812 3.000 2.750 3.000 . . Overview: C02-53: A hydraulic fracture treatment will be performed in the open hole horizontal section to establish communication vertically and longitudinally through the Alpine "C" sand. This will increase the wells production rate and reserves. A coil cleanout will only be performed should it be necessary post-frac. Procedure: 1, MIRU seven clean insulated frac tanks with a berm surrounding the tanks that holds the tank volume plus 10%. Load tanks with seawater from the injection system (approximately 2500 bbls are required for the treatment) - 2. Rig up Dowell equipment and stab Tree Saver. (Test tree saver seals to expected pressure using warm diesel to assure seal integrity in tubing hanger). 3. Pressure test surface lines to 9500 psi 4. Pump the 100 bbl Breakdown with Dowell's YF125ST fluid system. Bring pumps up to maximum rate ASAP. 5. Pump the following schedule at 30 BPM with a maximum pressure of 9000 psi, add breaker as per lab results. Maintain 3000 psi on the IA during the treatment. · 300 bbls YF125ST Pad · 240 bbls YF125ST w/2 ppa 16/30 White Sand · 480 bbls YF125ST w/4 ppa 16/30 White Sand · 1000 bbls YF125ST w/7 ppa 16/30 White Sand · Flush with linear YF125ST and freeze protect Total Sand: -310,OOOlbs. 6. Monitor the surface pressure fall-off at the end of the job for 30 min (or until closure is verified) if the well does not screen out. 7. Rig down equipment, (and prep for next well frac after evaluation by Engineering) move off location, FCC if required with slick diesel. . . WELL LOG TRANSMITTAL c?ú4 ~ ð gc¡ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 lÓ{j)55' RE: MWD Formation Evaluation Logs CD2-53, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 CD2-S3 : LAS Data & Digital Log Images: 50-103-20494-00 1 CD Rom ~ ~!?~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAG D GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added D or Final 0 (h)(2) drill rig wash fluids and drill rig domestic waste water 304-361 (h)(3) Other Commission approved substances (include descriptions in block 12) 9/30/2004 Volume (bbls): Number of days disposal occurred Previous 387* 387 totals (bbls): 2004 / 4th 19863 100 0 19963 18 2005/1st 0 0 0 0 0 2005 / 2nd 0 0 0 0 0 2005 / 3rd 5622 100 0 5722 6 Total Ending Volume 25485 200 387* 26072 24 (bbls): 11. Attach: Disposal Performance Data: Pressure VS. Time D Step Rate Test D Other (Explain) D 12. Remarks and Approved Substances Description(s): * Freeze protect, annular flush and injectivity test volumes I hereby certify that the foregoing i rue and correct to the best of my knowledge. Signature: ~- Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader 6. Permit to Drill Number: 7. Well Name: 8. API Number: 204-089 C02-53 50-103-20494-00 9.. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: . 10/3/2004 10/21/2004 C02-54 7/30/2005 C02-02 . 8/4/2005 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. \ c ("¿o Ie. f Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 V~RDMS 8Ft OCT 21 1005 INSTRUCTIONS ON REVERSE Slb~ . . . Submit in Duplicate 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: Previous totals (bbls): 2004 /4th 2005/1st 2005 / 2nd 2005 / 3rd Total Ending Volume (bbls): 19863 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Signature: Printed Name: Form 10-423 Rev. 2/2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAG D GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: o or Final D (h)(2) drill rig wash fluids and drill rig domestic waste water 304-361 (h)(3) Other Commission approved substances (include descriptions in block 12) 9/30/2004 Volume (bbls): Number of days disposal occurred P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added 387* 387 19863 100 0 19963 18 10/3/2004 10/21/2004 CD2-54 0 0 0 0 0 0 0 0 0 0 . 100 387* 20350 Pressure vs. Time D Step Rate Test D Date: Randy Thomas Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 18 6. Permit to Drill Number: 7. Well Name: 8. API Number: 204-089 CD2-53 50-103-20494-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: . Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. ") ('?'" f 0 ~ Phone Number: (907) 265-6830 * Freeze protect, annular flush and injectivity test volumes I hereby certify that the foregoing is e and correct to the best of my knowledge. ~- Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 387* 387 19863 100 0 19963 18 10/3/2004 10/21/2004 CD2-54 0 0 0 0 0 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAG D GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 10, (h)(1) drilling mud, drilling .. cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added o or Final D (h)(2) drill rig wash fluids and drill rig domestic waste water 304-361 (h)(3) Other Commission approved substances (include descriptions in block 12) 9/30/2004 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 2004 / 4th 2005/1st 2005 / 2nd .05/3rd Total Ending Volume (bbls): 100 387* 20350 19863 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Pressure vs. Time D Step Rate Test D * Freeze protect, annular flush and injectivity test volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ Signature: Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 204-089 CD2-53 50-103-20494-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: 18 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. ~Ií~(o~ Phone Number: (907) 265-6830 Submit in Duplicate 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAGD GINJ 0 WINJ 0 WDSPL 0 5a. Sundry number: 5b, Sundry approval date: p, O. Box 100360, Anchorage, Alaska 3. (Check one box only) * Freeze protect, annular flush and injectivity test volumes I hereby certify that the foregoing is true and correct to the best of my knowledge, ~ ~ ~ . 'l \. \.-... "":. Initial Disposal 0 or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2004/4th 19863 2005/1st 2005 / 2nd 2005 / 3rd Total Ending Volume (bbls): 19863 11. Attach: Disposal Performance Data: Other (Explain) 0 12. Remarks and Approved Substances Description(s): Signature: Printed Name: Form 10-423 Rev. 2/2004 o or Final 0 (h)(2) drill rig wash fluids and drill rig domestic waste water 304-361 (h)(3) Other Commission approved substances (include descriptions in block 12) 9/30/2004 Volume (bbls): Number of days disposal occurred 387* 387 100 o 19963 100 387* 20350 Pressure vs. Time 0 Step Rate Test 0 Date: Randy Thomas Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 18 18 6. Permit to Drill Number: 204-089 7. Well Name: CD2-53 8. API Number: 50-103-20494-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: . 1 0/3/2004 1 0/21/2004 CD2-54 . Report is due on the 20th of the month foJ/owing the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. l (? (oS- Phone Number: (907) 265-6830 Submit in Duplicate . ConocÓÁ,illips . G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 September 29,2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED SEP 2 9 2004 Subject: Well Completion Report for C02-53 (APD 204-089) Alaska Oil & Gas Coni'i, Gí.lll¡¡mf:síon Anchorage Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well C02-53. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, /{J..{. ~ G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad ORIGiNAL · STATE OF ALASKA . RECE'VED ALA Oil AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT ANm~004 Gas U Plugged D Abandoned D Suspended D WAG D 1b. Well Class:. .~. C"".. CommissIOn 20AAC 25.105 20AAC 25.110 De~"tO~ bas Ë~W~ratory D WDSPL D No. of Completions _ Other Service D AílChÇ!t~~~raPhic Test D / 12. Permit to Drill Number: 1a. Well Status: Oil 0 GlNJ D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: WINJ D P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 2093' FNL, 1499' FEL, Sec. 2, T11N, R4E, UM At Top Productive Horizon: 472' FSL, 1678' FEL, Sec. 12, T11 N, R4E, UM Total Depth: 3639' FNL, 4302' FEL, Sec. 18, T11 N, R5E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371736 / y- TPI: x- 376707 y- Total Depth: x- 378959 y- 18. Directional Survey: Yes 0 NoU 5974264 .I 5966185 5962038 Zone-4 Zone-4 Zone-4 21. Logs Run: GRlRes 22. 5. Date Comp., Susp., or Aband.: 6. Date Spudded: July 3, 2004 7. Date TD Reached: July 18, 2004 204-089 / 13. API Number: 50-103-20494-00 14. Well Name and Number: CD2-53 ¡ .I July 16, 2004 8. KB Elevation (It): 36.4' RKB /52.3' AMSL 9. Plug Back Depth (MD + TVD): 16985' MD /7200' TVD 10. Total Depth (MD + TVD): J 16985' MD / 7200' TVD Ii 15. Field/Pool(s): Colville River Field Alpine Oil Pool 16. Property Designation: ADL 380075, 372097 11. Depth where SSSV set: SSSV @ 2311' 17. Land Use Permit: ALK N/A 19. Water Depth, if Offshore: N/A 20. Thickness of Permafrost: feet MSL 1930' MD CASING SIZE 16" 9.625" GRADE H-40 J-55 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM 36.4' 114' 36,4' 114' 36.4' 3394' 36.4' 2371' 36.4' 12394' 36,4' 7205' WT. PER FT. 62.5# 36# 26# 7" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): openhole completion from 12394' MD 7205' TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED 42" 12 cu yds Portland III 517 sx AS Lite, 240 sx Class G 140 sx Class G 12.25" 8,5" 24. TUBING RECORD DEPTH SET (MD) 11954' PACKER SET 11891 ' SIZE 3,5" 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) September 3, 2004 Gas Lift Oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF W A TER-BBL CHOKE SIZE IGAS-OIL RATIO 9/3/2004 6 hours 45 min, Test Period --> 577 635 0 70% 880 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 241 psi 936 24-Hour Rate -> 1843 1623 0 not available 27. CORE DATA Submit core chips; if none, state "none". Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). NONE Form 10-407 Revised 12/2003 , Cn"C~'~::?7'O,7ï ~'';J;\'(¡_''- ¡ !~ ~ I r- i\T;' ~. I 7:);~Df! I \/[';"'":'<:1' I' . If j''Ltjl-i.J ~þ . L_~__l RØØlSlBFl ocr 0 6,_ Œav CONTINUED ON REVERSE G GEOLOGIC MARKERS . 29. . FORMATION TESTS 28. NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD2-53 Seabee Form. Nanushak Gamma Ray Shale Kalubik Kuparuk Formation Miluveach Top Alpine D Top Alpine C Base Alpine C TD 3454.5' 6025.5' 11351 ' 11691 ' 11762' 11834.5' 12171 ' 12253.5' 16740' 16985' 2403' 3842' 6749' 6937' 6975' 7014' 7153' 7177' 7217' 7200' N/A RECE\VE . SE? 2, 9 '2.004 0"\ & Gas c.Oí\~· ~\3s\<.a \ Mchorsge 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31 . I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name A . C. Alvord Signature ~-L_{þf( Title: Phone Alpine Drilling Team Leader 2...&,ç -G lLO Date ~lL'1lo:t-- Prepared by Sharon Allsup-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 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated, Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 12/2003 OR\G\ t L ¡.~ . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-53 CD2-53 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 7/2/2004 Rig Release: 7/18/2004 Rig Number: 19 Spud Date: 7/3/2004 End: 7/18/2004 Group: 7/2/2004 18:00 - 18:30 0.50 MOVE MOVE MOVE Move pipe shed - motor & pit complexes 18:30 - 19:30 1.00 MOVE MOVE MOVE Skid back floor - Turn tires - prep to move sub 19:30 - 22:30 3.00 MOVE MOVE MOVE Move sub f/ CD2-31 to CD2-53 - spot over well & level rig - lower feet 22:30 - 23:00 0.50 MOVE MOVE MOVE Skid floor into drilling position 23:00 - 23:30 0,50 MOVE MOVE MOVE Move in pit & motor complex - spot pipe shed 23:30 - 00:00 0.50 MOVE OTHR MOVE Tie rig back to high line power - prep rig floor 7/312004 00:00 - 01 :00 1.00 MOVE RURD MOVE Connect service lines - air - steam - water - electric. 01 :00 - 03:00 2,00 MOVE RURD MOVE Rig accepted @ 0100 hrs. Nipple up riser and flowline - take on spud mud into pits. Move BHA componets up to rig floor. 03:00 - 06:15 3,25 MOVE RURD MOVE Lay down 1 flex collar, Mu 7 3/4" jars and stand back in derrick. MU BHA #1 set ako @ 1.5 scribe tools and initialize MWD. Fill conductor - check for leaks. 06:15 - 06:30 0.25 MOVE RURD MOVE Held Pre-Spud meeting with rig team. 06:30 - 07:00 0.50 MOVE RURD MOVE MU 8" flex collars - pressure test mud line to 3500 psi. Clean out conductor from 110' to 114', 07:00 - 10:45 3,75 DRILL DRLG SURFAC Drill 121/4" hole from 114't0435', ran gyro surveys @ 94', 181',273', 363'. ADT= 1.32 hrs ART- 0.18 AST-1.14 PUW 105 SOW 105 - 420 gpm @ 740 psi. WOB 15/30K 10:45-11:15 0.50 DRILL OTHR SURFAC Falling behind on build, approaching restriction (CD2-52) discuss options, contact Team Leader. 11:15-13:45 2,50 DRILL TRIP SURFAC POOH, set motor ako to 2.12 degree - scribe tools and orientate UBHO sleeve. RIH to 435' - run gyro survey for orientation. 13:45 - 16:45 3.00 DRILL DRLG SURFAC Drill 12 1/4" hole from 435' to 703' MD- 695' TVD, ADT =1.58 hrs ART - 0.02 AST - 1.56 PUW 110K SOW 110K ROTWT 110K 500 gpm @ 1210 psi WOB 20/30K 30 rpm 16:45 - 17:00 0.25 DRILL CIRC SURFAC Circ for trip - 500 gpm /1210 psi /30 rpm 17:00 - 18:00 1.00 DRILL TRIP SURFAC POOH, set motor ako to 1.5 degree - scribe tools and orientate UBHO sleeve. 18:00 - 19:00 1.00 DRILL TRIP SURFAC RIH to 620' - wash down to 703 - No fill 19:00 - 00:00 5.00 DRILL DRLG SURFAC Gyro @ 703' - Drill 12 1/4" hole f/703' to 1072' MD - 1057' TVD ADT - 2.38 hrs. = ART - 0 hrs. AST - 2.38 hrs. WOB - 25/35 k RPM - 0 GPM - 420 @ 1450 psi St. wt. - PU 110 So 100 Rot 100 7/4/2004 00:00 - 12:00 12.00 DRILL DRLG SURFAC Drill 12 1/4" hole f/1072' to 2690' MD - 2002' TVD ADT - 7,8 hrs. = ART - 5.5 hrs. AST - 2.3 hrs. WOB - 20/25 k RPM - 80 GPM - 650 @ 2400 psi St. wt. - PU 130 So 110 Rot 120 Torque on/off 900017000 ftllbs 12:00 - 19:45 7.75 DRILL DRLG SURFAC Drill 12 1/4" hole from 2690' to 3402' MD 2375' TVD ADT - 6.06 hrs. = ART - 5.57 hrs. AST.49 hrs. WOB 25/35 RPM 80 GPM 650 @ 2450 psi St. wt. - PU 135 SO 115 Rot -125 Torque on/off btm. - 9500/8000 ft. Ibs. 19:45 - 20:30 0,75 DRILL CIRC SURFAC Circulate hole clean for wiper trip - flow check - static 20:30 - 22:30 2.00 DRILL WIPR SURFAC Wiper trip f/ 3402' to 2219' - pumping & back reaming - 600 gpm @ 1980 psi w/ 70 rpm - Observed increased torque & hole started taking fluid between 2314' to 2219' - shut down & monitor well - well flowing- (lost approx. 55 to 60 bbls) 22:30 - 23:00 0.50 DRILL TRIP SURFAC RIH f/2219' to 3402' - Monitor well - static after 5 mins. 23:00 - 00:00 1.00 DRILL CIRC SURFAC Circulate @ 200 gpm @ 400 psi - stage up pumps to 400 gpm - well Printed: 8/19/2004 8:46:48 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-53 CD2-53 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 7/2/2004 Rig Release: 7/18/2004 Rig Number: 19 Spud Date: 7/3/2004 End: 7/18/2004 Group: 7/4/2004 23:00 - 00:00 1,00 DRILL CIRC SURFAC apears to be stable (mix &pump 35 bbls - 20 #/bbl LCM) 7/5/2004 00:00 - 01 :00 1.00 DRILL CIRC SURFAC Pumped 35 bbls of 20 ppb LCM pill- increased rate to 450 gpm /1310 psi /50 rpm and circ hole clean. 01 :00 - 06:00 5,00 DRILL TRIP SURFAC Flow check well, static. POOH on trip tank from 3402' to 2400', no problems. Backream from 2400' to 1168' - 400 gpm /1050 psi / 50 rpm, 06:00 - 07:30 1.50 DRILL TRIP SURFAC Backreamed slowly from 1168' to 997' to clean up hole / 500 gpm / 1300 psi/50 rpm - had large amount of drill cuttings back across shakers. Pump out to 880', orientate tools highside. Flow check well, static, 07:30 - 08:30 1.00 DRILL TRIP SURFAC POOH on trip tank - standing back hwdp from 880' to 170' - hole took proper fill. 08:30 - 11 :30 3.00 DRILL PULD SURFAC Lay down jars - (2) 8" flex dc's - ubho- TM - HCIM - DM - xo- stab - fs - motor and bit. Clear tools from rig floor. Clean up trip mess. 11 :30 - 13:00 1.50 CASE RURD SURFAC RU to run 9 5/8" casing. 13:00 - 13:15 0.25 CASE SFTY SURFAC Held Pre-Job safety and Opts meeting. 13:15 - 15:30 2.25 CASE RUNC SURFAC Run 9 5/8" casing - FS - 2 joints - FC - 2 jts ( Baker-Ioc 1 st four joints - circ and check floats) all joints 9 5/8",36#, J-55, BTC - Continue to run casing 1430'. 35 joints total. 15:30 - 16:00 0.50 CASE CIRC SURFAC Stage pumps up to 5 bpm - circ 1 pipe volume - FCP 280 psi. PUW 115K SOW 107K 16:00 - 17:00 1.00 CASE RUNC SURFAC Continue to run 95/8" casing to 2505' - 61 jts. total 17:00 - 17:30 0.50 CASE CIRC SURFAC Break circulation & stage pumps up to 5 BPM & Circulate bottoms up 390 psi - PU wt -135 SO wt. 110 17:30 - 18:45 1,25 CASE RUNC SURFAC Continue running 9 5/8" casing f/ 2505' to 3355' ( 82 jts. total) PU hanger & landing jt. & land casing w/ shoe @ 3394' & FC @ 3312' - st wt. 175 PU 120 SO 18:45 - 19:15 0.50 CASE RURD SURFAC RU casing equipment & fill up tool - RU cmt head & lines 19:15 - 21:00 1.75 CEMENTCIRC SURFAC Circulate & condition mud & hole for cmt job - 5 bbls/min @ 320 psi - No losses 21 :00 - 23:30 2.50 CEMENT PUMP SURFAC PJSM - Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/ nut plug for marker - Pressure test lines to 2600 psi - Dropped btm plug - Mixed & pumped 50 bbls MudPushXL 10.5 ppg - 5.9 BPM @ 230 psi - Mix & pump lead slurry (ASL) @ 10.7 ppg -7.5 BPM @ 220 psi - Observed nut plug marker @ shakers w/ 385 bbls lead pumped - pumped down tub (410 bbls total pumped) - switch to tail slurry (G w/ .30% D065, .20% D046, 1 % S002) @ 15.8 ppg - 4.5 BPM @ 210 psi - Dropped top plug w/ 20 bbls water f/ Dowell - Switch to rig pumps & displace w/ 9.6 ppg mud @ 7 BPM @ 430 to 550 psi - Observed cement to surface w/ 90 bbls of displacement away - Observed returns decrease w/175.5 bbls away - slowed pump to 5 BPM @ 530 psi - slowed pump to 3.5 BPM w/ 200 bbls of displacement - Observed slight returns for last 36 bbls of displacement - Bumped plug w/1 000 psi - CIP @ 2315 hrs. Check floats - floats didn't hold - Pressure up to 1000 psi & shut in cmt head. Annulus was standing full after shutting down - Approx. 90 bbls cmt returns to surface 23:30 - 00:00 0.50 CEMENTOTHR SURFAC Cement head shut in - clean up floor 7/6/2004 00:00 - 01 :30 1.50 CEMENTOTHR SURFAC Pressured up and held 1000 PSI (Floats not holding). 01 :30 - 02:00 0,50 CASE MIT SURFAC Tested casing to 2500 PSI for 30 Min. 02:00 - 03:00 1.00 CASE RURD SURFAC Rigged down casing and cement equipment. Printed: 8/19/2004 8:46:48 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C02-53 C02-53 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 7/2/2004 Rig Release: 7/18/2004 Rig Number: 19 Spud Date: 7/3/2004 End: 7/18/2004 Group: 7/6/2004 03:00 - 04:00 1,00 CASE NUND SURFAC Nippled down riser. 04:00 - 06:30 2.50 CASE NUND SURFAC Installed Uni head and nippled up BOP. 06:30 - 13:45 7.25 WELCTL BOPE SURFAC Set test plug and tested BOP. Annular tested 250/3500, Rams, Kill and choke lines, choke valves, top drive valves, and floor valves tested 250/5000 PSI. Tested closing unit. Pulled test plug and installed wear bushing. 13:45 - 17:45 4.00 DRILL PULD SURFAC Picked up and stood back 2580' of 4" drill pipe. 17:45 - 21 :30 3.75 DRILL PULD SURFAC Picked up and tested Geo pilot BHA. 21 :30 - 00:00 2,50 DRILL TRIP SURFAC RIH picking up 4" drill pipe to 3140'. 7/7/2004 00:00 - 01 :30 1.50 RIGMNT RSRV SURFAC Slip and cut drilling line - service top drive 01:30 - 02:15 0.75 DRILL REAM SURFAC Wash down from 3140' tag cement @ 3307'. 02:15 - 05:45 3.50 CEMENT DSHO SURFAC Drill out shoe track FC @ 3312', FS @ 3394', firm cement in shoe track. Drill 20' of new hole to 3422'. 600 gpm / 2750 psi / 70 rpm 05:45 - 06:15 0.50 DRILL CIRC SURFAC Circ hole clean for PIT 600 gpm /2500 psi /70 rpm 06:15 - 07:00 0.75 CEMENT LOT SURFAC RU and perform PIT - LO at 16.0 ppg EMW. RD and blow down lines. 07:00 - 12:00 5,00 DRILL DRLG SURFAC Drill 8 1/2" hole from 3422' to 4073' MD - 2753' TVD. ADT - 3.3 hrs. WOB 5/8 RPM 120 GPM 625 @ 2000 psi St. wt. - PU 150 SO 100 Rot - 120 Torque on/off btm. - 9500/8000 ft. Ibs. 12:00 - 00:00 12.00 DRILL DRLG SURFAC Drill 8 1/2" hole from 4073' to 5601' MD - 3650' TVD. ADT - 7.4 hrs. WOB 10/25 RPM 80/180 GPM 500/655 @ 2300 psi St. wt. - PU 180 SO 110 Rot - 128 Torque on/off btm, - 10500/9500 ft. Ibs. 7/8/2004 00:00 - 02:30 2,50 DRILL DRLG INTRM1 Drill from 5601' to 5888' MD - 3783' TVD ADT - 1.7 hrs. WOB 10/20 RPM 130 GPM 500 @ 2100 psi St. wt. - PU 180 SO 110 Rot - 130 Torque on/off btm. - 11000/10000 ft. Ibs. 02:30 - 05:00 2.50 DRILL OTHR INTRM1 Picked up after drilling a stand down - hole packed off - lost 25 bbls of mud. Pull up to 5730' and establish circulation and circ BU 420 gpm / 1660 psi /100 rpm, Wash and ream from 5730' to 5888' - 650 gpm /3510 psi /150 rpm with heavy cuttings back across shakers. 05:00 - 12:00 7.00 DRILL DRLG INTRM1 Drill from 5888' to 6440' MD - 4036' TVD ADT - 5.0 hrs. WOB 10/22 RPM 100/140 GPM 615 @ 3200 psi St. wt. - PU 175 SO 115 Rot -135 Torque on/off btm. - 12000/11000 ft, Ibs. 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill from 6440' to 8084' MD - 4948' TVD ADT - 7.5.0 hrs. WOB 10/22 RPM 140/160 GPM 650 @ 3370 psi St. wt. - PU 235 SO 115 Rot - 148 Torque on/off btm. - 14000/12500 ft. Ibs. 7/9/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drill from 8084' to 9707' MD - 5850' TVD ADT - 8.0 hrs, WOB 15/25 RPM 160 GPM 650 @ 3550 psi St. wt. - PU 250 SO 120 Rot -165 Torque on/off btm, - 16500/15500 ft. Ibs. 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill from 9707' to 11,250' MD - 6696' TVD ADT -7.3 hrs. Printed: 8/19/2004 8:46:48 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-53 CD2-53 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 7/2/2004 Rig Release: 7/18/2004 Rig Number: 19 Spud Date: 7/3/2004 End: 7/18/2004 Group: 7/9/2004 12:00 - 00:00 12.00 DRILL DRLG INTRM1 WOB 20/25 RPM 160 GPM 650 @ 3950 psi St. wt. - PU 240 SO 130 Rot - 175 Torque on/off btm, - 17000/16000 ft. Ibs. 7/10/2004 00:00 - 02:45 2.75 DRILL DRLG INTRM1 Drill from 11250' to 11611' MD - 6895' TVD ADT - 1,8 hrs, WOB 20/25 RPM 140/160 GPM 610 @ 3810 psi St. wt. - PU 240 SO 140 Rot - 185 Torque on/off btm. - 15500/13500 ft, Ibs, 02:45 - 04:30 1.75 DRILL OTHR INTRM1 Hole packed off while drilling ahead @ 11611 '- lost 20 bblss of mud - Pulled up to 11450' and established circulation - staged pumps up to 600 gpm /3680 psi /140 rpm . CBU, wash down from 11450' to 11611'. 04:30 -11:15 6.75 DRILL DRLG INTRM1 Drill from 11611' to 12150' MD -7147' TVD ADT - 4.0 hrs. WOB 15/22 RPM 150 GPM 600 @ 3980 psi St. wt. - PU 255 SO 138 Rot - 185 Torque on/off btm. - 17,000/16,000 ft. Ibs. 11:15-13:15 2.00 RIGMNT RGRP INTRM1 Observed loss of standpipe pressure - located surface leak - washout in mudline just below mud pit fIIoor. Set back one stand - Rig up hoses to circ hole - circ hole with 8,0 bpm /2400 psi / 30 rpm Welder repaired washout on mud line - pressure test line to 4000 psi - RIH. 13:15 - 16:00 2.75 DRILL DRLG INTRM1 Drill from 12150' to 12407' MD - 7207' TVD ADT - 1.6 hrs. WOB 12/20 RPM 150 GPM 584 @ 3950 psi St. wt. - PU 255 SO 135 Rot - 180 Torque on/off btm. - 18,000/16,000 ft. Ibs. 16:00 - 17:45 1.75 DRILL CIRC INTRM1 Pumped sweep and circulated hole clean. 17:45 - 19:45 2.00 DRILL WIPR INTRM1 Backreamed out of hole to 11,070'. 19:45 - 20:30 0.75 DRILL WIPR INTRM1 RIH to 12350'. Washed to 12407'. 20:30 - 22:30 2.00 DRILL CIRC INTRM1 Pumped sweep and circulated while raising mud weight to 9.8 PPG. 22:30 - 00:00 1.50 DRILL TRIP INTRM1 POOH with pump spotting pill from 12407' to 11606'. 7/11/2004 00:00 - 01 :45 1.75 DRILL TRIP INTRM1 Pump out from 11606' to 11520' spotting lubricant pill - POOH on trip tank to 9134', hole in good condition. Monitor well, static. 01 :45 - 02:00 0.25 DRILL TRIP INTRM1 Pump dry job - blow down Top Drive, 02:00 - 07:30 5.50 DRILL TRIP INTRM1 POOH from 9134' to 3374', (wiped through tight spots @ 6840',5272' and 5209'), Monitor well 10 min, static. POOH to BHA - stand back hwdp and Jars. 07:30 - 10:00 2.50 DRILL PULD INTRM1 LD BHA : 3 nm flex collars, fs, MWD collars, service and LD Geopilot and bit. Clear tools from rig floor, 10:00 - 11 :45 1.75 CASE RURD INTRM1 Pull wear bushing - change top pipe rams to 7" - RU to run 7" casing, 11 :45 - 12:30 0.75 WELCTL BOPE INTRM1 Set test plug and joint - test 7" rams 205/5000 psi. LD test joint and plug. 12:30 - 13:15 0.75 CASE RURD INTRM1 Install thin wall wear bushing and RU to run casing. 13:15 - 13:30 0,25 CASE SFTY INTRM1 Held Pre-job Safety and Opts meeting with crew. 13:30 - 18:00 4.50 CASE RUNC INTRM1 Run 7" 26# L-80 BTCM as follows: FS - 2 jts. - FC - 122 jts, to 5401'- (Baker Loc 1 st four connections - pump through string on jt. #4 to check floats) install straight blade centralizers on first 14 jts. 18:00 - 19:00 1,00 CASE CIRC INTRM1 Broke Circulation and CBU. 19:00 - 21 :15 2.25 CASE RUNC INTRM1 Run 7" 26# L-80 BTCM 71 jts. to 8212'. 21 :15 - 21 :45 0.50 CASE CIRC INTRM1 Broke Circulation and CBU. 21 :45 - 00:00 2.25 CASE RUNC INTRM1 Run 7" 26# L-80 BTCM 65 jts. to 10945'. 7/12/2004 00:00-01:15 1,25 CASE CIRC INTRM1 Stage pumps up to 4 bpm and CBU - FCP 570 psi. PUW 310K SOW Printed: 8/19/2004 8:46:48 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-53 CD2-53 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 7/2/2004 Rig Release: 7/18/2004 Rig Number: 19 Spud Date: 7/3/2004 End: 7/18/2004 Group: 7/12/2004 00:00 - 01:15 01 :15 - 03:00 03:00 - 03:30 03:30 - 05:30 05:30 - 07:30 07:30 - 08:15 08:15 - 08:45 08:45 - 09:45 09:45 - 15:00 7/13/2004 15:00 - 15:30 15:30 - 17:45 17:45 - 22:15 22:15 - 00:00 00:00 - 01 :00 01 :00 - 02:00 02:00 - 04:15 04:15 - 04:30 04:30 - 05:45 05:45 - 06:30 06:30 - 08:30 08:30 - 12:00 12:00 - 00:00 7/14/2004 00:00 - 12:00 1.25 CASE CIRC INTRM1 145K. 1.75 CASE RUNC INTRM1 Run 7" casing f/10945' to 12351' (293 jts, total) MU landing joint and FMC fluted hanger and land casing with float shoe @ 12394' and Float collar @ 12307'. 0.50 CASE OTHR INTRM1 2,00 CEMENTCIRC INTRM1 2.00 CEMENT PUMP INTRM1 0.75 CASE MIT 0.50 CASE RURD 1.00 CASE PTCH 5.25 WELCTL BOPE 0.50 DRILL RIRD 2.25 DRILL PULD 4.50 DRILL PULD 1.75 DRILL TRIP 1.00 DRILL TRIP 1.00 RIGMNT RSRV 2.25 CEMENT DSHO 0.25 DRILL DRLG 1,25 DRILL CIRC 0.75 CEMENT FIT 2.00 DRILL CIRC 3.50 DRILL DRLH INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 PROD PROD 12.00 DRILL DRLH PROD 12,00 DRILL DRLH PROD LD fill up tool - blow down Top Drive - MU cement head and lines. Staged pumps up to 7 bpm - ccirc and cond mud for cementing - reduced YP to < 20, FCP @ 840 psi full returns throughout. Reciprocated pipe PUW 350K SOW 140K (initial) began lossing slack off wt., landed casing @ 0400 hrs, PJSM, Cement 7" casing as follows: Pumped 5 bbls CW-100 - Test cement lines to 3500 psi - Pumped 15 bbls CW-100 - Pumped 50 bbls Mud PushXL @ 12.5 ppg @ 5 bbls/min. - Dropped btm plug - Mixed & pumped 30.2 bbls slurry (G w/ D46 0,2%, D65 0.3%, B155 0.07%, D167 0.4%) @ 15.8 ppg /5,5 bbls/min /375 psi Dropped top plug w/ 20 bbls water f/ Dowell - switched to rig pumps & displaced w/ 9.8 ppg mud @ 7 bbls/min / 690 psi for first 396 bbls of dispalcement - slowed pumps to 6 bbls/min @ 650 to 800 psi for 49 bbls - slowed rate to 3.5 bpm last 5 bbls pumped final pressure 630 psi - bumped plugs to 1130 psi - total displacment 450 bbls - calc, 450.1 bbls. - CIP @ 0715 hrs. - floats held - Full returns during job. Test casing to 3500 psi for 30 min. Rigged down Casing and cementing tools. Installed and tested packoff on casing hanger to 5000 psi. Changed rams and set test plug. Tested BOP. Annular tested 250/3500. Rams, Kill and choke lines, choke valves, top drive valves, and floor valves tested 250/5000 PSI. Tested closing unit. Pulled test plug and installed wear bushing. Witinessed by Chuck Scheve from State. Rigged up bales and elevators. Pick up BHA and RIH. Pick up and RIH 4" DP to 5623'. RIH with stands to 9919'. RIH to 12,120' filling pipe every 2000', Slipped and cut drilling line. RIH to 12188' Cleaned out CementStringer. Drilled Float collar and shoe track. Cleaned out rat hole to 12407'. Drilled from 12407' to 12427'. CBU. Rigged up and did FIT to 12,5 PPG EMW, Changed mud system to 8.4 PPG MOBM. Drill from 12427' to 12593' MD - 7217' TVD ART - .59 Hrs, AST 1.33 Hrs. WOB 5/8 RPM 90 GPM 220 @ 2740 psi St. wt. - PU 260 SO 127 Rot - 175 Torque on/off btm, - 16,000/15,500 ft. Ibs, Drill from 12593' to 13549' MD - 7218' TVD ART - 6.49 Hrs, AST 1,67 Hrs. WOB 5/10 RPM 100 GPM 220 @ 2820 psi St. wt, - PU 260 SO 125 Rot - 175 Torque on/off btm. - 17,000/16,000 ft. Ibs. Drill from 13549' to 14316' MD - 7217' TVD ART -7.09 Hrs. AST 2.12 Hrs. Printed: 8/19/2004 8:46:48 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-53 CD2-53 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 7/2/2004 Rig Release: 7/18/2004 Rig Number: 19 Spud Date: 7/3/2004 End: 7/18/2004 Group: 7/14/2004 00:00 - 12:00 12.00 DRILL DRLH PROD WOB 5/10 RPM 100 GPM 220 @ 2880 psi St. wt. - PU 275 SO 120 Rot - 175 Torque on/off btm. - 17,000/17,000 ft. Ibs. 12:00 - 00:00 12.00 DRILL DRLH PROD Drill from 14316' to 15172' MD -7184' TVD ART - 5.16 Hrs. AST 2.73 Hrs. WOB 8/10 RPM 70 GPM 223 @ 3000 psi St. wt. - PU 265 SO 115 Rot - 170 Torque on/off btm. - 16,000/15,500 ft. Ibs. 7/15/2004 00:00 - 12:00 12.00 DRILL DRLH PROD Drill from 15172' to 15996' MD -7219' TVD ART - 5.65 Hrs. AST .94 Hrs. WOB 6/10 RPM 100 GPM 224 @ 3110 psi St. wt. - PU 290 SO 118 Rot - 174 Torque on/off btm. - 17,500/17,500 ft. Ibs. 12:00 - 00:00 12.00 DRILL DRLH PROD Drill from 15996' to 16698' MD - 7213' TVD ART - 5.24 Hrs. AST 3.24 Hrs. WOB 8/10 RPM 80 GPM 206 @ 3000 psi St. wt. - PU 285 SO 112 Rot - 170 Torque on/off btm, - 20,000/18,000 ft. Ibs. 7/16/2004 00:00 - 03:45 3.75 DRILL DRLH PROD Drill from 16698' to 16985' MD - 7201' TVD ART - 1.4 Hrs. AST 0 Hrs. WOB 6/10 RPM 75 GPM 220 @ 2960 psi St. wt, - PU 300 SO 105 Rot - 170 Torque on/off btm. - 18,000/18,000 ft. Ibs. 03:45 - 06:30 2.75 DRILL CIRC PROD Circulated and raised MW to 8.7 PPG. 06:30 - 17:00 10.50 DRILL TRIP PROD POOH with pump @ 3 BPM to 12390'. 17:00 - 18:00 1.00 RIGMNT RSRV PROD Changed swivel packing. 18:00 - 19:30 1.50 DRILL CIRC PROD CBU and monitored well. 19:30 - 20:00 0.50 DRILL TRIP PROD Tried to POOH with out pump. Continued POOH with pump to 12,150'. 20:00 - 22:00 2.00 WAlTON EQIP PROD Lost Hi Line power. Monitored well while waiting for power to be restored. 22:00 - 00:00 2.00 DRILL TRIP PROD Continued POOH with pump @ 2.5 BPM. 7/17/2004 00:00 - 06:45 6.75 DRILL TRIP PROD POOH to 9442' with pump. Continue POOH to 375' on trip tank. 06:45 - 08:45 2.00 DRILL PULD PROD Laid down BHA. 08:45 - 09:15 0.50 CMPL TN RURD PROD Pulled wear bushing. 09:15 - 09:45 0.50 CMPL TN RURD PROD Rigged up to run tubing. 09:45 - 20:30 10.75 CMPLTN RUNT PROD Picked up and ran 305 Jts. 3.5" 9,3# L 80 tubing BTCM, 20:30 - 21 :30 1.00 CMPL TN RURD PROD Rigged up and made up SSSV. 21 :30 - 00:00 2.50 CMPL TN RUNT PROD Picked up and ran 70 Jts. 3.5" 9.3# L 80 tubing BTCM. 7/18/2004 00:00 - 02:45 2.75 CMPLTN RUNT CMPL TN Picked up and ran 28 Jts. 3.5" 9.3# L 80 tubing BTCM. + 2 JTS. 4.5" ./ 12.6# I 80 BTM tubing. Made up tubing hanger and landing joint. Landed tubing. 02:45 - 03:30 0.75 CMPLTN OTHR CMPL TN Ran in lock down screws and installed 2 way check. Tested hanger to 5000 PSI. 03:30 - 04:30 1.00 CMPLTN OTHR CMPL TN Picked up wash tool and washed stack. 04:30 - 08:30 4.00 CMPL TN NUND CMPL TN Nippled down BOP and removed all rams, 08:30 - 10:30 2.00 CMPL TN NUND CMPL TN Connected control line and nippled up tree. 10:30 - 11 :30 1,00 CMPLTN NUND CMPL TN Attempted to test tree. 2 way check not holding. Changed out valve and tested tree to 5000 PSI. Pulled check valve. 11 :30 - 16:30 5.00 CMPL TN CIRC CMPL TN Rigged up and tested lines and displaced well with 20 Bbls. M oil followed by 430 Bbls. diesel. 16:30 - 19:00 2.50 CMPL TN PCKR CMPL TN Dropped ball/rod. Pressure test lines to 4000 psi - pressure up on tbg to 3500 psi to set packer & test tbg for 30 mins.- Bleed off pressure to 600 psi - pressure up on annulus to 3500 psi & test for 30 mins. - bleed off Printed: 8/19/2004 8:46:48 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-53 CD2-53 ROT - DRILLING Doyon Drilling Inc Doyon 19 Start: 7/2/2004 Rig Release: 7/18/2004 Rig Number: 19 Spud Date: 7/3/2004 End: 7/18/2004 Group: 7/18/2004 16:30 - 19:00 2,50 CMPL TN PCKR CMPL TN pressure - vaccume out lines - RD lines & squeeze maniflod 19:00 - 00:00 Released rig @ 1900 Hrs. 7/18/04. 5.00 RIGMNT OTHR DEMOB Set back pressure valve and secured well. Laid down drill pipe from derreck. Printed: 8/19/2004 8:46:48 AM e e 31-Jul-04 AOGCC .-Robin ne::l~on 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well CD2-53 ~ O~ -o~1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 16,985.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Signed W ð¿w Date (~ ~~, Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) . Halliburton Sperry-Sun Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-53 16 July, 2004 Job No. AKZZ3143996, Surveyed: Survey Report 27 July, 2004 . Your Ref: API 501032049400 <- Surface Coordinates: 5974264.07 N, 371736.31 E '(70020' 16.5184" N, 151002' 26.7240" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Survey Ref: svy417 Surface Coordinates relative to Project H Reference: 974264.07 N, 128263.69 W (Grid) Surface Coordinates relative to Structure: 178.49 S, 21.88 E (True) Kelly Bushing Elevation: 52. 33ft above Mean Sea Level Kelly Bushing Elevation: 52.33ft above Project V Reference Kelly Bushing Elevation: 52. 33ft above Structure Sr-=-ï'ï'Y-SUI'1 DFtIL,L,ING ~.eFtVIc:·é~ A Halliburton Company Halliburton Sperry-Sun Survey Report for Alpine CO-2 - CO2-53 Your Ref: API 501032049400 Job No. AKZZ3143996, Surveyed: 16 July, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0,000 -52,33 0,00 0,00 N 0,00 E 5974264,07 N 371736,31 E 0,00 CB-SS-Gyro 94.00 0.000 0.000 41.67 94.00 0.00 N 0.00 E 5974264.07 N 371736,31 E 0.000 0.00 181.00 0.400 49,000 128.67 181.00 0.20N 0.23 E 5974264,27 N 371736.54 E 0.460 -0.05 273.00 1.500 83,000 220,66 272.99 0.56N 1.67 E 5974264.60 N 371737.99 E 1,293 0.40 363.00 2,250 118,000 310,61 362.94 0,13 S 4.40 E 5974263,87 N 371740.70 E 1 .484 2.42 . 452.00 5.750 140.000 399.38 451,71 4.37 S 8.81 E 5974259.55 N 371745,04 E 4.224 8.34 542.00 10.000 141,000 488,51 540,84 13,90 S 16,63 E 5974249.89 N 371752.69 E 4.724 20,56 631,00 15,300 142.000 575.32 627.65 29.17 S 28.73 E 5974234.42 N 371764,53 E 5.960 39.90 719.00 19.800 146.000 659.21 711.54 50,68 S 44.22 E 5974212.64 N 371779.65 E 5,291 66.35 MWD+IIFR+MS+SAG 806,12 19.090 148.560 741.36 793.69 75.07 S 59.90 E 5974187.98 N 371794,92 E 1.273 95,34 834.52 19.620 148.110 768.16 820.49 83,08 S 64.84 E 5974179,89 N 371799,72 E 1.939 104.75 929,52 21.710 146.660 857.04 909,37 111.31 S 82,93 E 5974151.36 N 371817,32 E 2.265 138,27 1024.87 26.470 147.280 944,06 996.39 143.94 S 104,12 E 5974118.37 N 371837,95 E 4,999 177,17 1120.01 31.040 149.400 1027.45 1079.78 182.91 S 128,08 E 5974079,00 N 371861.24 E 4,921 222,92 1214.87 37.480 149.240 1105,81 1158.14 228.81 S 155.32 E 5974032.64 N 371887.69 E 6,790 276.28 1309.70 40.960 146.050 1179.27 1231.60 279.41 S 187.44 E 5973981.50 N 371918.95 E 4.241 336.21 1404.79 43.760 144,060 1249.53 1301.86 331.90 S 224.16 E 5973928.39 N 371954.76 E 3.264 400.16 1499.91 49,340 144.240 1314.92 1367.25 387.85 S 264.58 E 5973871.75 N 371994,22 E 5.868 469.00 1595.00 56,060 146.610 1372.52 1424.85 450.13 S 307.42 E 5973808.75 N 372035.99 E 7,339 544.50 1690,64 57,350 147.350 1425.02 1477.35 517.16 S 350.98 E 5973740.98 N 372078,39 E 1 .496 624.42 1785,98 55.530 147.300 1477.72 1530,05 584,03 S 393,87 E 5973673.39 N 372120,13 E 1.909 703,85 1881.08 54.860 144.580 1532,01 1584.34 648.72 S 437,59 E 5973607.96 N 372162.74 E 2.452 781,85 . 1976.50 58.540 143.370 1584,39 1636,72 713,19 S 484,50 E 5973542.69 N 372208.54 E 4.000 861.36 2071.50 60.180 143.040 1632,80 1685.13 778.64 S 533.45 E 5973476.42 N 372256.37 E 1.752 942.76 2166.84 60,180 144,130 1680.21 1732.54 845.21 S 582.56 E 5973409.02 N 372304.32 E 0.992 1025.19 2261.68 60.300 144.770 1727.29 1779.62 912,19S 630,42 E 5973341,23 N 372351.04 E 0.599 1107,34 2357.11 58.800 145,860 1775.65 1827,98 979,83 S 677.24 E 5973272,80 N 372396.69 E 1,855 1189.48 2452.66 58.540 146.010 1825.34 1877.67 1047.44 S 722.96 E 5973204.41 N 372441.25 E 0.303 1271.03 2547.53 58.460 145.780 1874.90 1927.23 1114.42 S 768.32 E 5973136,67 N 372485.45 E 0.223 1351,85 2642.88 58.790 145.300 1924,55 1976.88 1181.54 S 814,38 E 5973068.77 N 372530.36 E 0.552 1433,16 2738.01 59,370 144.790 1973.43 2025.76 1248.43 S 861.14 E 5973001.09 N 372575.97 E 0,764 1514.63 2833.46 58.640 145.780 2022.58 2074,91 1315,68 S 907,73 E 5972933,05 N 372621.41 E 1.173 1596,33 2928.73 59.300 145.880 2071.69 2124.02 1383.23 S 953,58 E 5972864.73 N 372666.10 E 0.699 1677.89 3024.12 57,890 146.060 2121.40 2173.73 1450.70 S 999.15 E 5972796.49 N 372710,50 E 1 .487 1759,24 3118.90 57.360 146.460 2172,15 2224.48 1517.26 S 1043,61 E 5972729.18 N 372753.81 E 0,663 1839.23 27 July, 2004·14:55 Page 2 of 8 OrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-53 Your Ref: API 501032049400 Job No. AKZZ3143996, Surveyed: 16 July, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3214.04 57.500 146.270 2223.37 2275.70 1584.02 S 1088,02 E 5972661,67 N 372797,07 E 0.224 1919.36 3309.52 58.130 146.540 2274,22 2326.55 1651.33S 1132.73 E 5972593.61 N 372840.63 E 0,702 2000,12 3352.60 58.650 145.440 2296.80 2349.13 1681,74 S 1153.25 E 5972562.85 N 372860.63 E 2.487 2036,78 3470,26 57,840 144.820 2358.73 2411.06 1763.82 S 1210.45 E 5972479.80 N 372916.41 E 0.821 2136,67 3565,77 56,910 144.840 2410.22 2462.55 1829,58 S 1256,78 E 5972413,26 N 372961,61 E 0.974 2216.96 . 3661.52 56.370 145.380 2462.87 2515.20 1895.17S 1302.53 E 5972346.89 N 373006.23 E 0,735 2296.80 3756,78 55,750 145.740 2516.06 2568.39 1960.35 S 1347,22 E 5972280,96 N 373049,80 E 0.722 2375.74 3852,34 54.710 146.040 2570.55 2622.88 2025.34 S 1391.24E 5972215.23 N 373092.70 E 1.118 2454,16 3947.64 53.980 146.410 2626,10 2678.43 2089,71 S 1434,29 E 5972150.14 N 373134,65 E 0.828 2531.55 4043.34 53.360 146.990 2682.80 2735.13 2154.14 S 1476,62 E 5972084,98 N 373175,87 E 0.811 2608.61 4138,96 52,800 147.530 2740.24 2792.57 2218.44 S 1517,96 E 5972019.99 N 373216,11 E 0.739 2685.04 4234.85 52.980 148,000 2798.09 2850.42 2283.13 S 1558.75 E 5971954.61 N 373255.78 E 0.434 2761.51 4330.05 52.880 147.830 2855.48 2907.81 2347.49 S 1599,10 E 5971889,58 N 373295,02 E 0.177 2837.47 4425.70 53.040 149.410 2913,10 2965.43 2412.66 S 1638.85 E 5971823,73 N 373333.66 E 1,329 2913.81 4521,33 52.820 149.650 2970.74 3023.07 2478.43 S 1677.55 E 5971757,31 N 373371.22 E 0.305 2990,10 4616,79 52.170 151.100 3028.86 3081.19 2544.25 S 1714,98 E 5971690.85 N 373407,52 E 1.384 3065.77 4712.27 53.910 150.860 3086.27 3138.60 2610,96 S 1751.99E 5971623.52 N 373443.39 E 1.833 3141.98 4807.93 51.560 152.540 3144.19 3196.52 2677.98 S 1788.10 E 5971555,90 N 373478.34 E 2.826 3217.97 4903.12 50.690 156.580 3203,95 3256.28 2744,87 S 1819,93 E 5971488.47 N 373509,03 E 3.428 3291.62 4998.49 50,920 158.020 3264.22 3316.55 2813.05 S 1848.45 E 5971419,81 N 373536,38 E 1.195 3364.62 5093,89 50.270 160.700 3324.79 3377.12 2882.02 S 1874.44E 5971350.41 N 373561.18 E 2.275 3436.97 5189,62 49.880 161.370 3386.23 3438.56 2951.45 S 1898.30 E 5971280.59 N 373583.85 E 0.674 3508,58 . 5285,06 55.260 156.450 3444.23 3496.56 3022,05 S 1925,66 E 5971209,52 N 373609,99 E 6.964 3583.04 5380.52 58.440 154,310 3496.43 3548,76 3094.68 S 1958.97 E 5971136.33 N 373642.06 E 3,823 3662.35 5476,22 60.950 149.750 3544.74 3597.07 3167.60 S 1997,74 E 5971062,76 N 373679,57 E 4.878 3744.76 5571.19 61,860 148.430 3590.19 3642.52 3239,14 S 2040.57 E 5970990.50 N 373721,18 E 1.552 3828.14 5667,18 63.930 148.890 3633.93 3686.26 3312.12 S 2085.01 E 5970916.78 N 373764.36 E 2,198 3913.58 5762.42 63.730 149,140 3675.93 3728.26 3385.39 S 2129.02 E 5970842.75 N 373807.11 E 0.316 3999,05 5857.81 64.060 149.670 3717.90 3770.23 3459.13 S 2172.61 E 5970768.28 N 373849.44 E 0,607 4084.69 5953.26 64.900 149.190 3759,03 3811,36 3533.29 S 2216.42 E 5970693.38 N 373891.97 E 0.990 4170.81 6048.58 65,370 147.820 3799.11 3851 .44 3607,03 S 2261,60 E 5970618.88 N 373935,89 E 1.394 4257.29 6144.06 63.100 146.990 3840.61 3892.94 3679.47 S 2307,92 E 5970545,66 N 373980,95 E 2.503 4343,26 6239.33 59.720 146.530 3886.19 3938.52 3749.43 S 2353.76 E 5970474.92 N 374025.59 E 3.573 4426.87 6334.78 57.350 146.720 3936.01 3988.34 3817.42 S 2398.55 E 5970406.19 N 374069.21 E 2.489 4508.24 6430.35 56.290 146.790 3988.31 4040,64 3884.31 S 2442.40 E 5970338.55 N 374111.91 E 1.111 4588.20 27 July, 2004 - 14:55 Page 3 of 8 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CO-2 - CO2-53 Your Ref: API 501032049400 Job No. AKZZ3143996, Surveyed: 16 July, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6526.03 55.570 146.750 4041.91 4094,24 3950.61 S 2485.83 E 5970271 ,52 N 374154,20 E 0,753 4667.43 6621.83 55.250 146.740 4096.30 4148,63 4016.56 S 2529.08 E 5970204.84 N 374196.31 E 0.334 4746,26 6717.45 55.720 145.840 4150.48 4202.81 4082.10 S 2572.80 E 5970138.56 N 374238.91 E 0.918 4825.00 6813.33 55.170 146.260 4204.86 4257.19 4147.60 S 2616.90 E 5970072,32 N 374281,89 E 0.678 4903.90 6908,60 55.420 146.330 4259.11 4311.44 4212.76 S 2660.37 E 5970006.43 N 374324.23 E 0.269 4982.17 . 7004.34 55.880 146.630 4313.13 4365.46 4278.65 S 2704,01 E 5969939.79 N 374366.74 E 0,546 5061,17 7100,23 56,530 146,870 4366.46 4418.79 4345.30 S 2747.71 E 5969872.41 N 374409.29 E 0.709 5140.83 7194.93 57.120 146.390 4418.28 4470.61 4411 .49 S 2791.31 E 5969805.48 N 374451.75 E 0,754 5220.06 7290.36 57.470 145.480 4469,85 4522,18 4478.01 S 2836.28 E 5969738.20 N 374495,58 E 0,882 5300.29 7386,02 57.270 144.180 4521 .43 4573.76 4543,86 S 2882.69 E 5969671.56 N 374540.85 E 1.163 5380.70 7481.67 56.470 143,770 4573,70 4626,03 4608.65 S 2929.79 E 5969605,99 N 374586,85 E 0.910 5460.56 7577,20 56.300 144.070 4626,59 4678,92 4672,94 S 2976.65 E 5969540.90 N 374632.59 E 0,316 5539.88 7672.94 56.230 144.620 4679.76 4732.09 4737,63 S 3023.06 E 5969475.42 N 374677.89 E 0.483 5619,31 7768.58 56.430 145.060 4732,78 4785.11 4802,71 S 3068.89 E 5969409.57 N 374722.60 E 0.436 5698,75 7864.07 56.660 145.290 4785.43 4837.76 4868.11 S 3114,39E 5969343.40 N 374766.97 E 0,314 5778.30 7959.98 56.440 145,590 4838.29 4890.62 4934.01 S 3159.78 E 5969276,73 N 374811,24 E 0,347 5858.22 8055.30 56.690 145.650 4890.81 4943.14 4999,66 S 3204,70 E 5969210.33 N 374855.02 E 0,267 5937.68 8150.76 56,750 146.050 4943.19 4995,52 5065.70 S 3249.50 E 5969143.53 N 374898.69 E 0,356 6017.41 8246.20 56,970 146,530 4995,37 5047.70 5132.18 S 3293.85 E 5969076,30 N 374941,89 E 0.480 6097.27 8341,32 56,740 146.690 5047,38 5099,71 5198.68 S 3337.68 E 5969009.06 N 374984.58 E 0.280 6176.88 8436,91 56.350 147,570 5100,08 5152.41 5265.66 S 3380.97 E 5968941.35 N 375026.71 E 0.870 6256.61 . 8532,52 56.550 147.700 5152,92 5205,25 5332.97 S 3423.62 E 5968873.32 N 375068.21 E 0.238 6336,29 8627.58 57.030 148.060 5204,98 5257,31 5400.33 S 3465.91 E 5968805.25 N 375109,34 E 0.596 6415.82 8723.01 57.030 147.670 5256.91 5309.24 5468,12 S 3508.49 E 5968736.74 N 375150.76 E 0.343 6495,88 8818.45 57.060 147.960 5308.83 5361.16 5535,90 S 3551,15 E 5968668,24 N 375192,25 E 0,257 6575.96 8913,54 56.820 148.320 5360,71 5413.04 5603,59 S 3593.22 E 5968599.84 N 375233.15 E 0.405 6655.65 9008.85 56.610 148,950 5413.01 5465.34 5671.62 S 3634,69 E 5968531.11 N 375273.45 E 0,595 6735,33 9104.11 56.540 149.060 5465.49 5517,82 5739,77 S 3675.63 E 5968462.27 N 375313.22 E 0,121 6814,82 9199.61 56.820 148.760 5517,95 5570.28 5808.11 S 3716,84 E 5968393.24 N 375353,26 E 0,394 6894.62 9295.38 56,980 147,830 5570.25 5622.58 5876.36 S 3759,00 E 5968324.27 N 375394.25 E 0,830 6974,85 9391,12 56.920 146.900 5622.46 5674,79 5943,94 S 3802.28 E 5968255.96 N 375436.36 E 0.817 7055,08 9486.52 56,600 146,780 5674.75 5727.08 6010.74 S 3845.92 E 5968188.43 N 375478.86 E 0,352 7134.85 9581,94 56.240 146.420 5727,53 5779.86 6077,10 S 3889,68 E 5968121.32 N 375521.47 E 0.491 7214.31 9677.42 56,370 146,310 5780.50 5832.83 6143.24 S 3933,68 E 5968054.44 N 375564,34 E 0.167 7293.70 9772,93 56.330 146.800 5833.42 5885.75 6209,58 S 3977.50 E 5967987.36 N 375607.02 E 0.429 7373.17 27 July, 2004 - 14:55 Page 4 of 8 OrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CO-2 - CO2-53 Your Ref: API 501032049400 Job No. AKZZ3143996, Surveyed: 16 July, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9868.47 55.850 147.170 5886.73 5939.06 6276.07 S 4020.70 E 5967920,14 N 375649.07 E 0.596 7452.43 9963.78 56,840 147,090 5939.55 5991.88 6342,70 S 4063.76 E 5967852,79 N 375690.99 E 1.041 7531.75 10059.32 57.260 147.270 5991.51 6043.84 6410,08 S 4107.21 E 5967784.68 N 375733,28 E 0.467 7611.91 10154.93 57.270 146.410 6043.21 6095.54 6477.40 S 4151.20 E 5967716.61 N 375776.11 E 0.757 7692.30 10250.08 57.200 146.220 6094.71 6147.04 6543,98 S 4195.58 E 5967649.28 N 375819,34 E 0.183 7772.26 . 10345.51 56.740 146.110 6146.72 6199,05 6610.44 S 4240.13 E 5967582,07 N 375862.75 E 0.492 7852.21 10440.75 56,390 146,190 6199.20 6251.53 6676.45 S 4284.40 E 5967515.32 N 375905,88 E 0.374 7931.63 10536.53 56.560 147.150 6252.10 6304.43 6743.16 S 4328.27 E 5967447.86 N 375948.61 E 0,854 8011.45 10631.76 56.670 147.850 6304.50 6356.83 6810.22 S 4370.99 E 5967380.08 N 375990.18 E 0,625 8090.95 10726.95 56.970 148.120 6356,60 6408,93 6877.77 S 4413.23 E 5967311,81 N 376031,25 E 0.395 8170.62 10822.51 57.630 147.370 6408.22 6460.55 6945,78 S 4456.15 E 5967243.09 N 376073,00 E 0.956 8251.03 10917.80 57.550 147.790 6459.30 6511.63 7013.68 S 4499.28 E 5967174.45 N 376114.96 E 0.381 8331.47 11013,11 56.510 148.280 6511,16 6563.49 7081.52 S 4541.61 E 5967105,90 N 376156,13 E 1,173 8411.43 11107,76 56.130 147.880 6563.65 6615.98 7148.37 S 4583.25 E 5967038,35 N 376196.62 E 0.534 8490.19 11204.05 56.960 148,190 6616.73 6669.06 7216,53 S 4625,78 E 5966969.48 N 376237.98 E 0.903 8570,52 11299.45 57.080 147.520 6668,66 6720.99 7284.29 S 4668.36 E 5966901,00 N 376279,39 E 0.602 8650.55 11395.15 56,510 147.670 6721.07 6773.40 7351.89 S 4711.27 E 5966832.67 N 376321.14 E 0.610 8730.61 11490,06 56,320 148,060 6773,58 6825.91 7418.84 S 4753.33 E 5966765.01 N 376362.05 E 0,397 8809,68 11584.67 56.820 147.390 6825,70 6878.03 7485.60 S 4795.49 E 5966697.54 N 376403.06 E 0.793 8888.63 11681.08 56.620 147.370 6878.60 6930.93 7553.48 S 4838.94 E 5966628.92 N 376445.34 E 0.208 8969,22 11776.26 57.200 147.920 6930.56 6982.89 7620,85 S 4881.61 E 5966560.84 N 376486.86 E 0.778 9048.95 . 11872.38 60,740 149,390 6980.11 7032.44 7691.19 S 4924.43 E 5966489.78 N 376528.47 E 3.909 9131.30 11967.69 64.020 149,690 7024.29 7076.62 7763.97 S 4967,24 E 5966416.27 N 376570.02 E 3.453 9215.72 12061.42 67.390 148.550 7062.85 7115.18 7837.27 S 5011.08 E 5966342.23 N 376612.61 E 3.762 9301.13 12157.63 71.360 147.620 7096.73 7149.06 7913.68 S 5058,68 E 5966265.02 N 376658,89 E 4,224 9391,15 12253.20 75.420 148.140 7124.04 7176.37 7991.23 S 5107.36 E 5966186.64 N 376706.24 E 4.280 9482,71 12348.45 79,090 151.210 7145.06 7197.39 8071.41 S 5154,24 E 5966105.68 N 376751.74 E 4,972 9575,56 12374,39 80.480 151.960 7149.66 7201.99 8093.86 S 5166.39 E 5966083.02 N 376763.50 E 6.067 9601.05 12452.86 84.470 151.160 7159.93 7212.26 8162.25 S 5203.43 E 5966014.01 N 376799.37 E 5.184 9678.70 12548,60 88.740 150,010 7165,60 7217,93 8245.48 S 5250.36 E 5965929.99 N 376844,86 E 4.618 9774.18 12644.38 88.620 149.240 7167.81 7220.14 8328,09 S 5298,78 E 5965846.56 N 376891.86 E 0.813 9869,91 12740,07 87,320 149.430 7171.20 7223.53 8410.35 S 5347.55 E 5965763.48 N 376939,22 E 1,373 9965.52 12835.53 89.170 148.040 7174.12 7226.45 8491,90 S 5397.07 E 5965681.09 N 376987.34 E 2.424 10060.93 12929.32 90,790 147.510 7174.15 7226.48 8571 ,24 S 5447,08 E 5965600.91 N 377035.98 E 1,817 10154,71 13026,75 90.490 146,850 7173,07 7225.40 8653.11 S 5499.88 E 5965518,15 N 377087.38 E 0,744 10252,11 27 July, 2004 - 14:55 Page 5 of 8 Oril/Quest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CO-2 - CO2-53 Your Ref: API 501032049400 Job No. AKZZ3143996, Surveyed: 16 July, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastin9s Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 13122,27 90.220 146,870 7172.47 7224.80 8733,09 S 5552.10 E 5965437.28 N 377138.22 E 0.283 10347.60 13217,83 91,640 149.110 7170.92 7223.25 8814.11S 5602.74 E 5965355.42 N 377187.47 E 2.775 10443.13 13312.81 91,040 148.960 7168,70 7221.03 8895,53 S 5651.60 E 5965273.17 N 377234.93 E 0,651 10538.08 13408.45 90.650 148.920 7167.29 7219.62 8977.45 S 5700.94 E 5965190.42 N 377282.86 E 0.410 10633.70 13504.13 89.930 148.720 7166.81 7219.14 9059,30 S 5750.47 E 5965107.73 N 377330,98 E 0.781 10729,38 . 13599,18 89.560 148.500 7167.23 7219.56 9140.44 S 5799.98 E 5965025.76 N 377379.10 E 0.453 10824.43 13694.75 89.050 148.430 7168.39 7220.72 9221.89 S 5849,96 E 5964943.46 N 377427.68 E 0.539 10919.99 13790.13 89.910 149.530 7169.26 7221.59 9303.63 S 5899.11 E 5964860.90 N 377475.42 E 1 .464 11015.36 13886.08 89.550 149.710 7169.71 7222,04 9386.40 S 5947.64 E 5964777.31 N 377522.52 E 0.419 11111,28 13981.27 90,840 151.210 7169.38 7221.71 9469,21 S 5994,56 E 5964693.71 N 377568,03 E 2,078 11206.40 14076.87 90,050 150.530 7168,64 7220,97 9552.72 S 6041.10 E 5964609.42 N 377613.13 E 1.090 11301.90 14172,24 91.150 151.440 7167.64 7219.97 9636,11 S 6087,35 E 5964525,25 N 377657,95 E 1 .497 11397.16 14267.59 91.160 151.000 7165.72 7218.05 9719.66 S 6133.25 E 5964440.92 N 377702.41 E 0.461 11492.37 14360.55 90,900 151,380 7164,05 7216.38 9801.10S 6178.04 E 5964358.72 N 377745.80 E 0.495 11585,20 14458,58 91.580 153.070 7161.93 7214,26 9887,82 S 6223.71 E 5964271.24 N 377789,98 E 1.858 11682.98 14553.76 91.530 152.070 7159.34 7211.67 9972,26 S 6267.54 E 5964186.06 N 377832.36 E 1,052 11777.87 14649.49 90.980 152.690 7157.25 7209,58 10057.06 S 6311.91 E 5964100.51 N 377875.27 E 0.866 11873,33 14744.97 91.890 153,090 7154.86 7207.19 10142,03 S 6355.41 E 5964014.82 N 377917.31 E 1,041 11968.48 14840.66 91.580 152,640 7151.96 7204.29 10227.14 S 6399.03 E 5963928.97 N 377959.47 E 0,571 12063,83 14936.10 90.420 152,550 7150,29 7202.62 10311,86S 6442.95 E 5963843.51 N 378001.94 E 1,219 12158,99 15031.82 93,700 152,080 7146,85 7199,18 10396.55 S 6487.39 E 5963758.07 N 378044,92 E 3.462 12254.40 15126.84 93.430 151.670 7140.95 7193.28 10480.19 S 6532.09 E 5963673,68 N 378088,19 E 0.516 12349.06 . 15222.35 88,740 150,170 7139,14 7191.47 10563,62 S 6578.49 E 5963589.47 N 378133.15 E 5.155 12444.42 15317.79 89.440 151.320 7140.65 7192.98 10646.87 S 6625.13 E 5963505.43 N 378178.35 E 1.410 12539.77 15413.09 88,860 150.590 7142,07 7194.40 10730.18 S 6671.39 E 5963421.35 N 378223.18 E 0,978 12634,95 15508.71 87.460 151.950 7145.14 7197.47 10813.98 S 6717,33 E 5963336.77 N 378267,68 E 2.041 12730.40 15603.56 87.440 152.320 7149.36 7201.69 10897.75 S 6761.61 E 5963252.26 N 378310.53 E 0,390 12824,94 15699,20 87.320 152.240 7153,73 7206.06 10982.32 S 6806.05 E 5963166.93 N 378353.52 E 0,151 12920.26 15794.66 89,170 153,960 7156,65 7208.98 11067.41 S 6849.22 E 5963081.12 N 378395.22 E 2,646 13015,34 15890.27 87.090 152.430 7159.77 7212.10 11152,69 S 6892,31 E 5962995,12 N 378436,84 E 2.700 13110.54 15985.35 86.950 153.640 7164,72 7217,05 11237,32 S 6935.36 E 5962909.76 N 378478.45 E 1.279 13205.17 16081,07 86.520 151.760 7170.17 7222.50 11322.24 S 6979.19 E 5962824,11 N 378520.81 E 2.012 13300.46 16176.57 86.330 151.850 7176.12 7228.45 11406.24 S 7024.22 E 5962739.35 N 378564.40 E 0.220 13395,60 16271 .92 85.960 151.650 7182.53 7234,86 11490.04 S 7069.25 E 5962654.79 N 378607.99 E 0.441 13490.56 16367.76 88.200 150,680 7187.42 7239.75 11573,89 S 7115.41 E 5962570,17 N 378652,71 E 2.546 13586.15 27 July, 2004·14:55 Page 6 of 8 OrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-53 Your Ref: API 501032049400 Job No. AKZZ3143996, Surveyed: 16 July, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastin9s Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 16463.05 92.210 149.590 7187.07 7239.40 11656.50 S 7162.85 E 5962486.75 N 378698,73 E 4.361 13681.38 16557.76 95.660 149,760 7180.58 7232.91 11738.05 S 7210,55 E 5962404.40 N 378745.03 E 3.647 13775.82 16653.54 94.930 149,310 7171.74 7224.07 11820.25 S 7258,91 E 5962321.38 N 378791.97 E 0.894 13871,17 16748.96 94.670 148,890 7163.75 7216.08 11901.84 S 7307,74 E 5962238.97 N 378839.40 E 0.516 13966,25 16844.12 93,820 148,190 7156.71 7209.04 11982,79 S 7357,26 E 5962157.19 N 378887.53 E 1,156 14061,14 . 16938,86 93,510 147,980 7150,65 7202.98 12063,04 S 7407,25 E 5962076,09 N 378936.14 E 0,395 14155.69 v 16985,00 93.510 147,980 7147.83 .... 7200.16 12102,09 S 7431.67 E 5962036.63 N 378959.88 E 0.000 14201,74 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB=52.33' above MSL. Northings and Eastings are relative to SHL Sec2-T11 N-R4E. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4, The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from SHL Sec2-T11 N-R4E and calculated along an Azimuth of 148.337° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 16985,OOft., The Bottom Hole Displacement is 14201.77ft., in the Direction of 148.447° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment . 16985,00 7200.16 12102.09 S 7431,67 E Projected Survey 27 July, 2004 - 14:55 Page 70f8 DrillQuest 3.03.06.002 Alaska North Slope Survey tool program for CD?-53 Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 719,00 0.00 711 .54 27 July, 2004 - 14:55 To Measured Vertical Depth Depth (ft) (ft) 719.00 16985,00 711.54 7200.16 Halliburton Sperry-Sun Survey Report for Alpine CO-2 - C02-53 Your Ref: API 501032049400 Job No. AKZZ3143996, Surveyed: 16 July, 2004 North Slope, Alaska Survey Tool Description CB-SS-Gyro MWD+IIFR+MS+SAG . . Page 8 of 8 OrillQuest 3.03.06.002 e e 31-Jul-04 AOGCC ~ "I neasQA-"" 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD253 MWD ;)..0'4-081 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 16,985.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date G N-; ~'\ /7/ 1 ~JI Signed ~. U41h/f Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment(s) Halliburton Sperry-Sun Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-53 MWD )0'1-0YC( Job No. AKMW3143996, Surveyed: 16 July, 2004 Survey Report 27 July, 2004 Your Ref: API 501032049400 Surface Coordinates: 5974264.07 N, 371736.31 E (70020' 16.51848 N, 151002' 26.72408 W) Grid Coordinate System:NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 974264.07 N, 128263.69 W (Grid) Surface Coordinates relative to Structure: 178.49 S, 21.88 E (True) Kelly Bushing Elevation: 52.33ft above Mean Sea Level Kelly Bushing Elevation: 52. 33ft above Project V Reference Kelly Bushing Elevation: 52. 33ft above Structure ~ SpE!ï'f""Y-SU:" DRII-I-ING SERVIces A Halliburton Company ~ .' . . Survey Ref: svy418 Halliburton Sperry-Sun Survey Report for Alpine CO-2 - C02-53 MWO Your Ref: API 501032049400 Job No. AKMW3143996, Surveyed: 16 July, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northin9s Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -52.33 0.00 0.00 N 0.00 E 5974264.07 N 371736.31 E 0.00 CB-SS-Gyro 94.00 0.000 0.000 41.67 94.00 0.00 N 0.00 E 5974264.07 N 371736.31 E 0.000 0.00 181.00 0.400 49.000 128.67 181.00 0.20 N 0.23 E 5974264.27 N 371736,54 E 0.460 -0.05 273.00 1.500 83.000 220.66 272.99 0.56N 1.67 E 5974264.60 N 371737.99 E 1.293 0.40 363.00 2.250 118.000 310.61 362.94 0.13 S 4.40E 5974263.87 N 371740.70 E 1 .484 2.42 452.00 5.750 140.000 399.38 451 .71 4.37 S 8.81 E 5974259.55 N 371745.04 E 4.224 8.34 . 542.00 10.000 141,000 488.51 540.84 13,90 S 16.63 E 5974249,89 N 371752.69 E 4.724 20.56 631.00 15.300 142.000 575.32 627.65 29.17 S 28,73 E 5974234.42 N 371764.53 E 5.960 39.90 719.00 19.800 146.000 659.21 711,54 50.68 S 44.22 E 5974212.64 N 371779.65 E 5.291 66.35 MWD Magnetic 806.12 19.280 148.810 741.31 793,64 75.22 S 59.92 E 5974187,84 N 371794.93 E 1.233 95.48 834,52 19.810 148,230 768,08 820.41 83.32 S 64.88 E 5974179.65 N 371799.75 E 1.987 104,98 929.52 21.950 146.700 856,83 909.16 111.85 S 83.11 E 5974150.81 N 371817.49 E 2.324 138.83 1024.87 26.700 147.540 943.69 996.02 144.84 S 104.40 E 5974117.46 N 371838.22 E 4.995 178,08 1120.01 31.270 149.790 1026.90 1079.23 184.24 S 128,31 E 5974077.67 N 371861.45 E 4.937 224.16 1214.87 37.720 148.770 1105.04 1157.37 230.37 S 155.77 E 5974031,06 N 371888.12 E 6.826 277,85 1309.70 41.200 146.560 1178,25 1230,58 281.26 S 188.03 E 5973979.64 N 371919.50 E 3,957 338.10 1404.79 44.020 144.420 1248.23 1300,56 334.28 S 224,52 E 5973926,00 N 371955.08 E 3.334 402.38 1499.91 49.590 143.850 1313.31 1365.64 390.44 S 265.15 E 5973869,15 N 371994.74 E 5.872 471.51 1595.00 56.320 146.260 1370.57 1422,90 452.65 S 308,53 E 5973806.21 N 372037.05 E 7.360 547,23 1690.64 57,630 147.980 1422.69 1475.02 519.99 S 352.05 E 5973738.13 N 372079.42 E 2.037 627.39 1785.98 55.810 148.100 1475.01 1527.34 587.61 S 394.24 E 5973669.80 N 372120.44 E 1.912 707.09 1881.08 55.140 145.180 1528.91 1581,24 653.05 S 437.31 E 5973603.64 N 372162.39 E 2.626 785.40 . 1976.50 58.820 143.770 1580,90 1633.23 718,14S 483,81 E 5973537,76 N 372207.76 E 4.051 865.20 2071.50 60.450 143.070 1628.93 1681.26 783.95 S 532.66 E 5973471,12 N 372255.48 E 1.830 946.87 2166.84 60.460 143.410 1675.94 1728,27 850.40 S 582.30 E 5973403,83 N 372303.98 E 0.310 1029.48 2261.68 60.580 145.180 1722,62 1774,95 917.44 S 630.48 E 5973335.98 N 372351.00 E 1.630 1111 .83 2357.11 59.090 145.320 1770.57 1822.90 985.23 S 677.50 E 5973267.39 N 372396.86 E 1.566 1194.22 2452.66 58.820 146.410 1819.84 1872.17 1052.99 S 723.44 E 5973198.86 N 372441.63 E 1.017 1276,00 2547.53 58,740 145.640 1869.02 1921.35 1120.27 S 768.78 E 5973130.81 N 372485.82 E 0.699 1357,07 2642.88 59.080 145.750 1918,26 1970,59 1187.72 S 814.80 E 5973062.59 N 372530.67 E 0.370 1438.63 2738.01 59.650 145,070 1966.73 2019.06 1255.10S 861,27 E 5972994.42 N 372575.98 E 0.859 1520.38 2833.46 58.930 145.740 2015.48 2067.81 1322.65 S 907.86 E 5972926.08 N 372621.42 E 0.966 1602.33 2928.73 59.580 146.220 2064,18 2116.51 1390.52 S 953.67 E 5972857.44 N 372666.06 E 0,808 1684.14 3024.12 58.170 145.700 2113.49 2165.82 1458.18S 999,38 E 5972789.00 N 372710.60 E 1.550 1765.73 3118.90 57.650 146.570 2163.84 2216.17 1524,86 S 1044.12 E 5972721.57 N 372754.20 E 0.952 1845.97 27 July, 2004 - 14:15 Page 2 of 8 OrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-53 MWD Your Ref: API 501032049400 Job No. AKMW3143996, Surveyed: 16 July, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3214.04 57.780 146.130 2214.66 2266.99 1591.81 S 1088.69 E 5972653,87 N 372797.62 E 0.414 1926.35 3309.52 58.410 145.930 2265.12 2317.45 1659.03 S 1133.98E 5972585.88 N 372841.75 E 0.683 2007.34 3352.60 58.940 145.340 2287.52 2339.85 1689.41 S 1154,76 E 5972555.16 N 372862,00 E 1.698 2044,10 3470.26 57.840 144.180 2349.19 2401.52 1771.25S 1212.57 E 5972472.34 N 372918.40 E 1.257 2144.10 3565,77 56.910 144.820 2400.68 2453.01 1836.74 S 1259.28 E 5972406.06 N 372963.99 E 1,125 2224,36 . 3661.52 56.380 145.540 2453.32 2505.65 1902.39 S 1304.95 E 5972339.64 N 373008,53 E 0.837 2304.22 3756.78 55.760 145.910 2506,50 2558.83 1967.70 S 1349.46 E 5972273.57 N 373051.91 E 0.726 2383.17 3852.34 54.710 145.670 2560.99 2613.32 2032.62 S 1393.59 E 5972207.91 N 373094.93 E 1.118 2461.60 3947.64 53.980 145.960 2616.54 2668.87 2096.68 S 1437,10E 5972143.12 N 373137,34 E 0.805 2538.96 4043.34 53.360 146.880 2673.23 2725.56 2160.91 S 1479.75 E 5972078.17 N 373178,88 E 1.010 2616.01 4138.96 52.810 147,740 2730.67 2783.00 2225,25 S 1521,04E 5972013.13 N 373219.06 E 0.921 2692.45 4234.85 52.980 147.680 2788.51 2840.84 2289,90 S 1561.89 E 5971947.79 N 373258.80 E 0.184 2768.92 4330.05 52.880 148.220 2845.90 2898.23 2354.28 S 1602,20 E 5971882,73 N 373298.01 E 0.465 2844,87 4425.70 53.040 149.880 2903,52 2955.85 2419.75 S 1641 .46 E 5971816.59 N 373336,14 E 1.395 2921.21 4521.33 52.820 149.990 2961.16 3013.49 2485.79 S 1679.69 E 5971749,91 N 373373.23 E 0.248 2997.49 4616.79 52.170 151.430 3019.28 3071.61 2551.83 S 1716.74E 5971683,25 N 373409.15 E 1,377 3073.15 4712.27 53.900 150.930 3076.70 3129,03 2618.67 S 1753.52 E 5971615.79 N 373444.78 E 1.860 3149.34 4807.93 51,570 152.880 3134.62 3186,95 2685.81 S 1789.38 E 5971548.05 N 373479.49 E 2.926 3225,31 4903.12 50.690 156.560 3194.37 3246.70 2752.79 S 1821.03 E 5971480.53 N 373509.99 E 3.148 3298.94 4998.49 50.920 158.390 3254.64 3306.97 2821,06 S 1849.34 E 5971411.79 N 373537.13 E 1.507 3371.91 5093,89 50,280 160,900 3315.20 3367.53 2890.16 S 1874,99 E 5971342.26 N 373561,59 E 2.141 3444.19 5189.62 49.890 161.740 3376,63 3428,96 2959.72 S 1898.51 E 5971272.31 N 373583.91 E 0.787 3515.73 . 5285.06 55.240 156,730 3434.64 3486,97 3030.47 S 1925.46 E 5971201.11 N 373609.65 E 6.983 3590.11 5380,52 58.430 154,630 3486.86 3539.19 3103.26 S 1958.39 E 5971127,76 N 373641.33 E 3.815 3669,35 5476.22 60.930 150.260 3535.19 3587.52 3176.45 S 1996,62 E 5971053.93 N 373678.31 E 4,728 3751,71 5571.19 61,860 148.800 3580.66 3632,99 3248.31 S 2038,90 E 5970981.36 N 373719.35 E 1.667 3835.07 5667.18 63,920 149.140 3624.40 3676.73 3321.52 S 2082.94 E 5970907.40 N 373762,14 E 2,169 3920,50 5762.42 63.740 149.550 3666.40 3718.73 3395.05 S 2126.53 E 5970833.14 N 373804.45 E 0.430 4005.96 5857.81 64.060 149,620 3708.37 3760.70 3468,93 S 2169.89 E 5970758.53 N 373846.55 E 0.342 4091.60 5953.26 64.890 149.770 3749.50 3801.83 3543,29 S 2213.36 E 5970683.44 N 373888.74 E 0.881 4177.71 6048.58 65.370 147,830 3789.59 3841.92 3617.26 S 2258.16 E 5970608.72 N 373932.26 E 1.914 4264.19 6144.06 63.110 147,170 3831.08 3883.41 3689.78 S 2304.35 E 5970535.41 N 373977.21 E 2.447 4350.16 6239.33 59.730 146.500 3876,65 3928.98 3759.81 S 2350,10 E 5970464.62 N 374021,76 E 3.601 4433,78 6334.78 57.370 146.470 3926.45 3978.78 3827.69 S 2395.06 E 5970395.97 N 374065.55 E 2.473 4515.16 6430.35 56.300 147.010 3978.73 4031.06 3894,59 S 2438.94 E 5970328.34 N 374108.28 E 1.215 4595.13 27 July, 2004·14:15 Page 3 of 8 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-53 MWD Your Ref: API 501032049400 Job No. AKMW3143996, Surveyed: 16 July, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6526,03 55.570 147.040 4032.32 4084.65 3961.08 S 2482,08 E 5970261.12 N 374150.27 E 0.763 4674.37 6621.83 55.250 147.200 4086.71 4139.04 4027.31 S 2524.89 E 5970194.16 N 374191.95 E 0.361 4753.22 6717.45 55.720 146.370 4140.89 4193.22 4093.22 S 2568.05 E 5970127.52 N 374233.97 E 0.868 4831,98 6813.33 55.180 146.710 4195.27 4247.60 4159.11 S 2611.59 E 5970060.90 N 374276.38 E 0,634 4910.91 6908.60 55.420 146,940 4249.50 4301.83 4224.66 S 2654.45 E 5969994.62 N 374318.11 E 0.321 4989.21 . 7004.34 55.880 146.890 4303.52 4355.85 4290.89 S 2697.60 E 5969927.66 N 374360,12 E 0.482 5068.22 7100.23 56.530 147.500 4356.86 4409.19 4357.87 S 2740.77 E 5969859.96 N 374402.14 E 0.860 5147.90 7194.93 57,110 146.600 4408.69 4461.02 4424.38 S 2783.88 E 5969792.72 N 374444.11 E 1.004 5227.13 7290.36 57.470 145.530 4460.26 4512.59 4491.00 S 2828.71 E 5969725.35 N 374487.79 E 1.016 5307.36 7386.02 57.270 144.300 4511.84 4564.17 4556.92 S 2875.01 E 5969658.64 N 374532.96 E 1.103 5387.78 7481.67 56.480 143.570 4564.11 4616.44 4621,67 S 2922.17 E 5969593.09 N 374579.00 E 1.044 5467.65 7577.20 56.300 144.010 4616.99 4669,32 4685.86 S 2969.17 E 5969528.10 N 374624.89 E 0.427 5546.96 7672,94 56.230 144.010 4670,16 4722.49 4750.29 S 3015.96 E 5969462.89 N 374670.57 E 0.073 5626.35 7768.58 56.430 144,750 4723.18 4775.51 4814.99 S 3062.31 E 5969397.41 N 374715,81 E 0.677 5705.75 7864.07 56.660 144.860 4775,82 4828.15 4880.09 S 3108,23 E 5969331.52 N 374760.61 E 0,259 5785.27 7959.98 56.440 145.340 4828.69 4881.02 4945.72 S 3154.02 E 5969265.12 N 374805,27 E 0.476 5865.17 8055.30 56.690 145.630 4881,21 4933.54 5011.27 S 3199,09 E 5969198.81 N 374849.21 E 0.365 5944.61 8150.76 56.750 146.350 4933.59 4985,92 5077.42 S 3243.73 E 5969131.91 N 374892.71 E 0.634 6024.35 8246.20 56.970 146,710 4985.77 5038.10 5144.08 S 3287,80 E 5969064.50 N 374935.64 E 0,391 6104.23 8341,32 56.740 146.790 5037.78 5090.11 5210.69 S 3331.47 E 5968997.16 N 374978.16 E 0.252 6183.84 8436.91 56,350 147.830 5090.47 5142.80 5277.81 S 3374,54 E 5968929.31 N 375020.08 E 0.995 6263.58 8532.52 56.550 147.990 5143.31 5195.64 5345.31 S 3416.87 E 5968861.09 N 375061.25 E 0.251 6343.26 . 8627.58 57,030 148.320 5195.38 5247,71 5412.88 S 3458,83 E 5968792.82 N 375102.05 E 0.583 6422.79 8723.01 57.030 148.170 5247.31 5299.64 5480.95 S 3500.97 E 5968724.04 N 375143,02 E 0,132 6502.85 8818.45 57.060 148.780 5299.23 5351.56 5549.22 S 3542.84 E 5968655.07 N 375183.72 E 0.537 6582.93 8913,54 56.820 148.940 5351,10 5403.43 5617.43S 3584.06 E 5968586.16 N 375223.76 E 0.289 6662.62 9008,85 56.610 149,560 5403.41 5455,74 5685,90 S 3624.79 E 5968517.00 N 375263.32 E 0,587 6742,29 9104.11 56.540 149.190 5455,88 5508,21 5754.31 S 3665,29 E 5968447.90 N 375302.64 E 0.332 6821.78 9199.61 56.820 148.830 5508.34 5560.67 5822.72 S 3706.38 E 5968378.80 N 375342.55 E 0.430 6901.58 9295.38 56.980 147.740 5560.64 5612.97 5890.97 S 3748.56 E 5968309.84 N 375383,55 E 0,968 6981,80 9391.12 56.920 146.890 5612,86 5665,19 5958.51 S 3791.89 E 5968241.57 N 375425.73 E 0.747 7062.04 9486.52 56.600 147.150 5665.15 5717.48 6025.44 S 3835.33 E 5968173.90 N 375468.01 E 0.406 7141.81 9581.94 56.240 146.530 5717,93 5770,26 6091.99 S 3878.81 E 5968106.62 N 375510.35 E 0.660 7221.27 9677.42 56.370 146.390 5770.90 5823.23 6158.21 S 3922.70 E 5968039.67 N 375553.10 E 0.183 7300,67 9772.93 56,330 146.570 5823,82 5876.15 6224.49 S 3966.61 E 5967972.64 N 375595.87 E 0.162 7380.14 27 July, 2004 - 14:15 Page 4 of 8 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-53 MWD Your Ref: API 501032049400 Job No. AKMW3143996, Surveyed: 16 July, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9868.47 55.850 147.360 5877,12 5929.45 6290,96 S 4009.83 E 5967905.44 N 375637.95 E 0.850 7459.40 9963.78 56.840 147.150 5929.94 5982.27 6357.69 S 4052.74 E 5967837.99 N 375679.71 E 1.055 7538.72 10059.32 57.260 147,630 5981.91 6034.24 6425.22 S 4095.95 E 5967769.73 N 375721.76 E 0.609 7618.88 10154.93 57.270 146.570 6033.61 6085.94 6492.75 S 4139.63 E 5967701.47 N 375764.28 E 0.933 7699.29 10250.08 57.200 146.500 6085.11 6137.44 6559.49 S 4183.75 E 5967633.97 N 375807.25 E 0.096 7779.26 . 10345.51 56.740 146.370 6137,12 6189.45 6626.16 S 4227,99 E 5967566,56 N 375850,34 E 0.495 7859.22 10440.75 56.400 146.170 6189.59 6241.92 6692.26 S 4272.12 E 5967499,71 N 375893.34 E 0.398 7938.65 10536.53 56.560 147.550 6242.49 6294,82 6759.12S 4315.77 E 5967432.12 N 375935.84 E 1.213 8018.47 10631.76 56,670 148.140 6294.89 6347,22 6826.44 S 4358.09 E 5967364.08 N 375977.00 E 0.530 8097,99 10726.95 56.970 147.560 6346.98 6399.31 6893.89 S 4400.49 E 5967295.91 N 376018,23 E 0.599 8177.65 10822.51 57.630 147.290 6398.61 6450,94 6961.66 S 4443.78 E 5967227.42 N 376060.37 E 0,730 8258.06 10917.80 57.550 148.030 6449.68 6502.01 7029.63 S 4486,82 E 5967158.73 N 376102.23 E 0.661 8338.50 11013.11 56.520 148,550 6501 .54 6553,87 7097.65 S 4528.85 E 5967089.99 N 376143.09 E 1.174 8418.46 11107.76 56,130 147.700 6554,02 6606.35 7164.54 S 4570.44 E 5967022.40 N 376183.54 E 0.853 8497.23 11204.05 56.960 148.470 6607.11 6659.44 7232,73 S 4612.91 E 5966953.49 N 376224.83 E 1,090 8577 .56 11299.45 57.080 147,160 6659,04 6711,37 7300.46 S 4655,54 E 5966885.05 N 376266.29 E 1,159 8657.58 11395.15 56.520 147.830 6711.44 6763.77 7367.99 S 4698,57 E 5966816.79 N 376308.16 E 0,828 8737,65 11490.06 56.320 148.250 6763.94 6816,27 7435.08 S 4740.42 E 5966749.00 N 376348,86 E 0.425 8816.72 11584.67 56.820 148.250 6816.06 6868.39 7502.22 S 4781.97 E 5966681,15 N 376389.26 E 0.528 8895.68 11681.08 56,620 147.760 6868.96 6921.29 7570.57 S 4824,68 E 5966612.08 N 376430.79 E 0.473 8976.27 11776.26 57,200 148.350 6920.93 6973.26 7638.24 S 4866.87 E 5966543,70 N 376471.81 E 0.801 9056.02 11872.38 60,730 149.740 6970.47 7022,80 7708.87 S 4909,21 E 5966472.36 N 376512.94 E 3.876 9138,35 . 11967,69 64.000 150.490 7014.68 7067.01 7782.07 S 4951.27 E 5966398.45 N 376553.74 E 3.501 9222.74 12061.42 67.370 148,280 7053.27 7105.60 7855,55 S 4994.77 E 5966324,23 N 376595.98 E 4.188 9308.12 12157.63 71.340 147.240 7087.19 7139.52 7931.68 S 5042.80 E 5966247,30 N 376642.70 E 4.248 9398,13 12253.20 75.400 147.780 7114.53 7166.86 8008,90 S 5091.98 E 5966169,24 N 376690.55 E 4.283 9489.67 12348.45 79,070 150.570 7135,58 7187,91 8088.66 S 5139,55 E 5966088.68 N 376736,75 E 4.796 9582.53 12374.39 80,450 152.250 7140.19 7192,52 8111.08 S 5151.76 E 5966066.06 N 376748,58 E 8,302 9608.02 12452.86 84.440 152.470 7150.50 7202,83 8179.97 S 5187,84 E 5965996.55 N 376783,48 E 5.092 9685,60 12548.60 88.700 152.900 7156.23 7208.56 8264.87 S 5231.69 E 5965910.92 N 376825.86 E 4.472 9780.87 12644.38 88.580 151.520 7158.50 7210,83 8349.57 S 5276.33 E 5965825.47 N 376869,05 E 1 .446 9876.40 12740.07 87.290 151.780 7161.95 7214.28 8433.73 S 5321.74 E 5965740,54 N 376913,01 E 1.375 9971.87 12835.53 89.140 150,220 7164.93 7217.26 8517.18S 5367.99 E 5965656.32 N 376957.83 E 2.534 10067.17 12929.32 90.930 147.270 7164.87 7217.20 8597.34 S 5416.65 E 5965575.34 N 377005.11 E 3.679 10160.95 13026.75 90.620 147.610 7163,55 7215.88 8679.45 S 5469.08 E 5965492,34 N 377056.13 E 0.472 10258.36 27 July, 2004 - 14:15 Page 5 of 8 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-53 MWD Your Ref: API 501032049400 Job No. AKMW3143996, Surveyed: 16 July, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 13122.27 90,190 147.060 7162.87 7215.20 8759.86 S 5520,63 E 5965411.06 N 377106.30 E 0.731 10353,86 13217.83 91.610 150.420 7161.37 7213.70 8841,52 S 5570.20 E 5965328.56 N 377154.47 E 3.817 10449.39 13312.81 91.170 147.210 7159.07 7211.40 8922.74 S 5619.36 E 5965246.51 N 377202.23 E 3.410 10544,32 13408.45 90.620 150,210 7157,57 7209.90 9004.45 S 5669.03 E 5965163.97 N 377250.49 E 3.189 10639.94 13504.13 90,060 148.920 7157.01 7209.34 9086.95 S 5717.49 E 5965080.66 N 377297.53 E 1.4 70 10735,59 . 13599.18 89,690 148.980 7157.21 7209.54 9168.38 S 5766.52 E 5964998.40 N 377345.16 E 0.394 10830.64 13694.75 89.010 148.320 7158.30 7210.63 9249.99 S 5816.23 E 5964915.95 N 377393.47 E 0.992 10926.20 13790.13 89.880 149.820 7159.22 7211.55 9331.80 S 5865,25 E 5964833.31 N 377441.09 E 1.818 11021.56 13886.08 89.690 150.130 7159.58 7211.91 9414.87 S 5913.26 E 5964749.43 N 377487.67 E 0.379 11117,47 13981.27 90.800 151.540 7159.18 7211.51 9497.99 S 5959.65 E 5964665.53 N 377532,63 E 1.885 11212,57 14076,87 90.190 151.660 7158.35 7210.68 9582.08 S 6005.12 E 5964580.68 N 377576.65 E 0.650 11308.01 14172.24 91,110 152.840 7157.27 7209.60 9666.4 7 S 6049.52 E 5964495.54 N 377619.60 E 1.569 11403.15 14267.59 91.300 152.170 7155.26 7207.59 9751,03 S 6093.53 E 5964410.23 N 377662.16 E 0.730 11498,22 14360.55 90.860 151.650 7153.51 7205.84 9833.03 S 6137.29 E 5964327.50 N 377704.51 E 0.733 11590.99 14458.58 91.540 153.360 7151.46 7203.79 9919.96 S 6182.54 E 5964239.81 N 377748.27 E 1.877 11688.73 14553.76 91,670 153,230 7148.79 7201.12 10004.96 S 6225.30 E 5964154.09 N 377789.56 E 0.193 11783.52 14649.49 91.110 152.650 7146.47 7198.80 10090.18 S 6268.83 E 5964068.14 N 377831,63 E 0.842 11878.91 14744.97 91.850 154.910 7144.00 7196.33 10175.80 S 6311.00 E 5963981.81 N 377872,33 E 2,490 11973,92 14840.66 91.540 154.200 7141.17 7193.50 10262.17 S 6352.10 E 5963894.75 N 377911.94 E 0.809 12069.01 14936,10 90.560 152.460 7139.42 7191,75 10347.44 S 6394.92 E 5963808.76 N 377953.31 E 2.092 12164.06 15031.82 93.830 152,350 7135.76 7188,09 10432,20 S 6439.23 E 5963723.26 N 377996.15 E 3.418 12259.46 15126,84 93.400 152.550 7129,77 7182,10 10516.27 S 6483.09 E 5963638.44 N 378038.57 E 0.499 12354.05 . 15222.35 88,700 149.960 7128.02 7180.35 10599.97 S 6529.00 E 5963553,97 N 378083,04 E 5.618 12449.38 15317.79 89.570 151,880 7129.46 7181.79 10683.36 S 6575.37 E 5963469.80 N 378127,98 E 2.208 12544.71 15413.09 88.830 152.780 7130.79 7183.12 10767.76 S 6619.62 E 5963384.66 N 378170.78 E 1.223 12639.76 15508.71 87.590 153,530 7133.77 7186,10 10853,03 S 6662.78 E 5963298.67 N 378212.48 E 1.515 12735.00 15603.56 87.410 153.480 7137.91 7190.24 10937.83 S 6705.06 E 5963213.15 N 378253.30 E 0,197 12829,37 15699,20 87.280 152.310 7142,34 7194.67 11022,88 S 6748.58 E 5963127.37 N 378295.36 E 1.230 12924.61 15794.66 89.140 153.640 7145.32 7197.65 11107.87 S 6791.94 E 5963041.65 N 378337.25 E 2.395 13019.70 15890.27 87.220 154.010 7148.36 7200.69 11193.62 S 6834,09 E 5962955.19 N 378377.93 E 2.045 13114.82 15985.35 86.910 153.130 7153.23 7205.56 11278.65 S 6876.35 E 5962869.45 N 378418.74 E 0.980 13209.38 16081.07 86.480 151.580 7158.75 7211.08 11363.30 S 6920,69 E 5962784,05 N 378461.62 E 1.678 13304.70 16176.57 86.290 153.410 7164.77 7217.10 11447.84 S 6964.70 E 5962698.78 N 378504.18 E 1.923 13399.76 16271.92 85,920 151.850 7171.25 7223,58 11532,31 S 7008.44 E 5962613.56 N 378546.46 E 1.678 13494.62 16367.76 88.330 150.540 7176.05 7228.38 11616.18 S 7054.55 E 5962528.92 N 378591.14 E 2.861 13590.21 27 July, 2004 - 14:15 Page 60f8 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-53 MWD Your Ref: API 501032049400 Job No. AKMW3143996, Surveyed: 16 July, 2004 North Slope, Alaska Alaska North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DDft) 16463.05 92.350 148.910 7175.49 7227.82 11698.45 S 7102.58 E 5962445.84 N 378637.75 E 4.552 13685.44 16557.76 95.630 150.210 7168.90 7221.23 11779.90 S 7150.44 E 5962363.59 N 378684.21 E 3.724 13779.89 16653.54 95.060 148.490 7159.98 7212.31 11861.93S 7199.06 E 5962280.73 N 378731.42 E 1.884 13875.23 16748.96 94.630 148.950 7151.92 7204.25 11943.19 S 7248.42 E 5962198.64 N 378779.39 E 0.659 13970.31 16844.12 93.950 149.920 7144.80 7197.13 12024.90 S 7296.68 E 5962116.12 N 378826.24 E 1.243 14065.18 . 16938.86 93.640 147.360 7138.53 7190.86 12105.61 S 7345.87 E 5962034.58 N 378874.04 E 2.716 14159.71 16985.00 93.640 147.360 7135.60 7187.93 12144.39 S 7370,71 E 5961995,38 N 378898,21 E 0.000 14205.75 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North, Vertical depths are relative to RKB=52.33' above MSL. Northings and Eastings are relative to SHL Sec2-T11 N-R4E. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from SHL Sec2-T11 N-R4E and calculated along an Azimuth of 148.337° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 16985.00fl., The Bottom Hole Displacement is 14206.11f1., in the Direction of 148.745° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 16985.00 7187,93 12144.39 S 7370.71 E Projected Survey . 27 July, 2004 - 14:15 Page 7 of 8 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Alpine CD-2 - CD2-53 MWD Your Ref: API 501032049400 Job No. AKMW3143996, Surveyed: 16 July, 2004 North Slope, Alaska Alaska North Slope Survey tool program for CD2-53 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 719,00 0.00 719.00 711.54 16985.00 711.54 CB-SS-Gyro 7187.93 MWD Magnetic . . 27 July, 2004 - 14:15 Page 8 of 8 DrillQuest 3.03.06.002 ~~:~~ e lDJ !Æ e ~ FRANK H. MURKOWSKI, GOVERNOR A T,A.fi11iA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska P.O. Box 100360 Anchorage, Alaska 99510-0360 ~j)Jt;~l}lff? Re: Colville River CD2-53 Sundry Number: 3ú4-361 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. Approval of this request does not authorize disposal of drilling waste in a volume greater than 35, 000 barrels through the annulus of a single well or to use that well for disposal purposes for a period longer than one year. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested BY ORDER OF THE COMMISSION DATED this~ day of September, 2004 Ene!. CD2-53 Annular Disposal Processing Request e e Subject: CD2-53 Annular Disposal Processing Request From: "Kuenzler, Zane A" <Zane.A.Kuenzler@conocophillips.com> Date: Thu, 30 Sep 2004 11 :05:37 -0800 To: tom_maunder@admin.state.ak.us CC: "Alvord, Chip" <Chip.Alvord@conocophillips.com>, "Johnson, Vern" <Vern.Johnson@conocophillips.com> Mr. Maunder, As per our discussion this morning, ConocoPhillips requests that a permit for annular disposal be issued on CD2-53 posthaste. This request is necessitated due to the fact that next well planned for annular injection, CD2-20, showed higher than expected injection pressure in the preliminary pumping operations. Therefore CD2-20 is no longer consider a candidate for annular disposal as the 9-5/8" shoe integrity could be jeopardized. The package for CD2-53 is complete with all associated engineering calculations and addendums attached. Any assistance your office can provide in expediting the permitting in this instance is greatly appreciated. Should you have any questions or concerns in this matter please contact me at the numbers listed below. Best Regards, Zane Kuenzler Alpine Drilling Engineer ConocoPhillips Alaska, Inc. 907-265-1308 Office 907-240-5499 Cell I of 1 9/30/2004 11:15 AM e e Note to File C02-53 (204-089...304-361) Colville River Unit (Alpine) ConocoPhillips Alaska, Inc Phillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. Returns were initially good, however the quality diminished with no returns for the last 38 bbls displacement. Approximately 90 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 96% XS of the calculated hole volume. --On the initial leak off test, it was not possible to pump into the well at 16.0 EMW. The pressure declined during the observation period to about13.5EMW. The initial leak off indicates that the surface casing shoe is well cemented. --No problems are reported drilling the intermediate hole. The 7" casing was run and successfully cemented. The 7" was reciprocated through the initial stages of the job. --An injectivity test down 9-5/8" x 7" annulus was conducted. Pressure steadily increases until the break at 14.1 EMW. Pump in was steady at 13.8 EMW. Ouring the observation period, the pressure declined to 13.0 EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. --CPA provided a listing of all surface casing shoes within % mile of C02-53. There are a total of 7 wells within % mile of the surface shoe. The nearest well is C02-57 about 400' distant. C02-57 has not been approved for AO, however the surface casing cementing operations were evaluated in the review of C02-27 There are 3 other wells between 600' - 1000' away with 1 of the wells having been approved for AO. The other 2 wells surface casing cementing operations has been evaluated. The remaining wells are in excess of 1000' distant. An examination of the files did not reveal any problem that would preclude granting CPA's request for C02-53. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. ft~ rrrv¿~~ Tom Maunder, PE Sr. Petroleum Engineer September 30,2004 G:\cornrnon\tommaunder\Well Infonnation\By Subject\Annular Disposal\040930--CD2- 53.doc . . Conoc~Phillips ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 29, 2004 RE EI\/E SEP 2 92004 Alaska Oil and Gas Conservation Commission 333 West 7m Avenue, Suite 100 Anchorage, Alaska 99501-3539 Þ.laska Oil & Cons. Commission Anchorage Re: Application for Sundry Approval for Annular Disposal of Drillin2 Waste on well CD2-53 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD2-53 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD2-53 approximately October 10,2004. Please find attached form 1O-403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD2 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within 1.4 mile radius (no new wells) !,~~~i.l&-fegafdiUg,~~~I~~Il~D~IJ~~,~!:!~_~.~_~e radius should be on file at t~0~" / The initial annular LOT (14.1 ppg) and occurred at a low:~~~~ivalent mud-weigh~~~~n the casing Sh~:"-~'~~ ( test (16.0 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone '__ provided we do not injecl with sustained surface pressures that will cause pressures at the surface shoe to ----bd~s of the shoe FIT/LOT. .__------- ----,--- - '---. __O~___,.~____ ---.-"-'-- If you have any questions or require further information, please contact Vem Johnson at 265-6081, or Chip Alvord at 265-6120. :7rely, /~~ /~- Vern Johnson Drilling Engineer or ('& 7/0 <¡ cc: CD2-53 Well File Chip Alvord Nancy Lambert Sharon Allsup-Drake ATO-1700 Anadarko ATO-1530 ConocoPhillips Alaska Þ e STATE OF ALASKA -. ~",> ~O ALASKA OIL AND GAS CONSERVATION COMMISSI~E~ ANNULAR DISPOSAL APPLICATION SEP 2 92004 20 AAC 25.080 , > n I' os CUI\\ml&SIQ 3. Permit t0Á\'å'$k8 Oi\ & Gas uO > Number: 204-089 Anchorage 4. API Number: 1. Operator Name: 50-1 03-20494-00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska C02-53 6. Field: Colville River Field 7. Publicly recorded wells a) All wells within one-quarter mile: CD2-39, CD2-51, CD2-58, CD2-52, CD2-27, CD2-57 (see attached summary) 8. Stratigraphic description: a) Interval exposed to open annulus: Torok and Seabee formation, shale, siltstone and sandstone b) water wells within one mile: b) Waste receiving zone: Sand layers in the Colville group C-30 in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier 9. Depth to base of permafrost: approximately 2055' MD 11600' TVD 10. Hydrocarbon zones above waste receiving zone: None 11. Previous volume disposed in annulus and date: None 14. Estimated volume to be disposed with this request: 12. Estimated slurry density: densities range from diesel to 12#/gal 15. Fluids to be disposed: 13. Maximum anticipated pressure at shoe: 1972 PSI 35,000 bbls. 16. Estimated start date: 1( to - 10 - 0 'f Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. 17. Attachments: Well Schematic (Include MD and TVD) 0 Cement Bond Log (if required) D FIT Records w/LOT Graph 0 Surf. Casing Cementing Data o Other o Summary of wells and surface casino shoe locations 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: þL~ Title: ~ Ù,~ r~~Jµ- Printed Name: Chip Alvord Phone Number: 265-6120 Date: c¡: (.1.'t lO4- LOT review and approval: ~~ ~ G{ ~U Approval number: 3D t/ - 3¿, I Conditions of approval: Commission Use Only ~ Ii"'~ \ \~"-'-~. ~I \é\ \Sì W ~r-- \<> o.ç ,~S ~ag() - "id ~ \iØIIS BFL Dateq(~hr:/ St:ffV~ Approved . COMMISSIONER OR\G\NAL BY ORDER OF THE COMMISSION Form 10-403AD Rev. 9/2003 INSTRUCTIONS ON REVERSE Submit in Duplicate e e Annular Disposal Transmittal Form 1. Designation of the well or wells to receive drilling wastes. 2. The depth to the base of freshwater aquifers and permafrost, if present. 3. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. 4. A list of all publicly recorded wells within one- quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. CD2-53 There are no USDW aquifers in the Colville River Unit. Estimated base of Permafrost = 1600' TVD (RKB) The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier. Calculated water salinities of the Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/l. (Ref. AOGCC Conservation Order No. 443, March 15, 1999) See attached map indicating wells within 1/4 mile. There are no water wells within 1 mile. 5. Identify the types and maximum volume of waste to Types of waste may be drilling mud, drilling cuttings, be disposed of and the estimated density of the waste reserve pit fluids, cement-contaminated drilling mud, slurry. completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6. Description of any waste sought to be determined as drilling waste under h (3) of this section 7. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operation and calculations showing how this value was determined. 8. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation. 9. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations. 10. Any additional data required by the Commission to NA confirm containment of drilling wastes. Cement rinsate Maximum anticipated pressure at casing shoe during disposal operations is 1972 psi. See attached calculation page. See attached cementing reports, LOT/FIT reports, and casing reports. See attached casing summary sheet and calculation page. Well Date en .5 '" ~ U Q Q Q r..: CD2-53 9/2912004 '" '" ~ ~ en en ~~ e e Pressure Calculations for Annular Disposal 2,370 TVD Assumptions Maximum injection pressure of Maximum density of the injection fluid is Pore pressure at the 9 5/8" casing shoe is Gas Gradient is Header Pressure 1,500 12 0.4525 0.11 2,000 pSI ppg psi/ft psi/ft pSI TOC Est. @ 11,663' MD 6,921' TVD Maximum Fluid Densitv to Burst Surface Casing Pburst85% = PHydrostatic + P Applied - PFormation 2,992 = ( 2,370 * 0.052 * MW max ) + 1500 - (0.4525 * 2,370) MW max 20.8 ppg 4 1/2"Tbg 7 ,209 TVD Surface Casing String Size 9.625 in Weight 36 ppf Grade J 55 PburstlOO% 3,520 pSI Pburst85% 2,992 psi Depth of Shoe 2,370 ft FITILOT @ Shoe 16 ppg or 1,972 psi FITILOT for Annulus 14.1 ppg Max Surf. Pressure 1,500 psi Maximum Fluid Densitv to Collapse 2nd Casing String P collapse85% = PHydrostatic + P Applied - P GasGradient - PHeader 4,599 = ( 6,921 * 0.052 '" MWmax ) + 1,500 - ( 0.1100 * 6,921) - 2,000 MW max 16.3 ppg 2nd Casing String Size 7 in Weight 26 ppf Grade L 80 P collapse 100% 5,410 psi Pcollapse85% 4,599 psi Top of Cement 6,921 ft Gas Gradient 0.11 psi/ft Max Surf. Pressu 1,500 pSI Header Press 2,000 psi Maximum Allowable Pressure at Surface Casing Shoe P max allowable = Shoe TVD Depth * .052 * Shoe FIT/LOT P max allowable = P max allowable = 2,370 * .052 * 16 1,972 psi e e ~/ ConocoPhillips Jt Number Jts 3 to 82 Jts 1 to 2 Casing Detail 95/8" Surface Casinq Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKB to Landing Ring FMC Gen V Hanger 80 Jts 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Collar 2 Jts 9-5/8" 36# J-55 BTC Csg Ray Oil Tools "Silver Bullet" Float Shoe TD 12 1/4" Surface Hole RUN TOTAL 47 BOWSPRING CENTRALlZERS- 1 per jt on Jt #1 - #12 (stop ring on Jt #1 & 2) and over collars on jts# 14, 16, 18, 20, 22, 24, 26, 28, 30, 32,34,36,38,40,42,44,46,48,50,52,54,56,58,60,62 64, 64, 66, 68,70,72,74,76,78, 80. 85 joints in the pipe shed. Run 82 joints -3 - joints stay out Use Best-o-Life 2000 pipe dope Remarks: Up Wt - 175 k Dn Wt - 120 k Block Wt - 75k Supervisor: D. Burley / D. Mickey Well: Date: LENGTH 36.70 2.18 3273.40 1.49 77.62 2.35 CD2-53 7/5/2004 DEPTH TOPS 36.70 38.88 3312.28 3313.77 r-3391.39 \. 3393.74 "--~_._._-~ 3402.00 - e legal Well Name: C02-53 Common Well Name: C02-53 Event Name: ROT - DRilLING Primary Hole Size: 12.250 (in) TMD Set: 3,394 (It) Date Set: 7/5/2004 Csg Type: Surface Casing Csg Size: 9.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger Rot Time Start: Rec Time Start:21 :00 Report #: Start: 1 7/2/2004 Spud Date: 7/3/2004 Report Date: 7/5/2004 End: 7/18/2004 Squeeze Open Hole Hole Size: SO TMD: (It) SO Date: SO Type: Cmtd. Csg: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: SO TMD: SO Date: Cmtd. Csg: Hole Size: Top Set: (It) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Cementer: Steve Doughton Pipe Movement: Reciprocating Time End: Time End: 10:45 RPM: SPM: Init Torque: (It-Ibf) Stroke Length: 25.0 (It) Avg Torque: (ft-lbf) Max Torque: (It-Ibf) Drag Up: 150,000 (Ibs) Drag Down: 110,000 (Ibs) Type: Cement Casing Volume Excess 'Yo: 53.00 Meas. From: 90 Time Circ Prior To Cementing: 175.00 Mud Circ Rate: 210 (gpm) Mud Circ Press: 320 (psi) Start Mix Cmt: 21: 14 Start Slurry Displ: 21: 15 Start Displ: 22:26 End Pumping: 23:15 End Pump Date: 7/5/2004 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 7.00 (bbl/min) 3.50 (bbl/min) Y 610 (psi) 1 ,000 (psi) 10 (min) N Returns: 80 Total Mud Lost: (þ,Q1), Cmt Vol to SUrfC~~.~~.~~)./) Ann Flow Alter: N Mixing Method: Density Meas By: densometer Mu Type: Spud Mud Density: 9.6 (ppg) Visc: 65 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Mud PVIYP: 25 (cp)/19 (lb/100lt2) Gels 10 sec: 4 (lb/100ft2) Gels 10 min: 10 (lb/100lt2) Bottom Hole Static Temperature: (OF) Density: 9.6 (ppg) Volume: 236.00 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (It) Water Source: Test Data Thickening Time: Free Water: ('Yo) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Stage No: 1 1 of To: (It) Description: Biozan water w/nut plugt Cmt Vol: 40.0 (bbl) Density: 8.30 (ppg) Slurry Vol: (sk) Water Vol: (bbl) Class: Yield: (lt3/sk) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: Per flush Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 9/29/2004 11:16:19AM e e Legal Well Name: C02-53 Common Well Name: C02-53 Event Name: ROT - DRILLING Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Slurry Data (' , Fluid Type: ! LEAD / Slurry Interval\2,a94:ð'O (ft)To: (ft) Water Source: lake Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Slurry Data Fluid Type: TAIL Slurry Interval: 3,394.00 (ft)To: Water Source: lake Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Report #: Start: 1 7/2/2004 Spud Date: 7/3/2004 Report Date: 7/5/2004 End: 7/18/2004 To: (ft) Description: MUD PUSH XL Class: Cmt Vol: 50.0 (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Description: AS Lite v:: Cmt Vol: ,410.0 (bbl) Density: 10.70 (ppg) Slurry VoIS17 (s~~ Water Vol: 255.0 (bbl) ./'" Temp (OF) (OF) Pressure (psi) (psi) Class: j....~., Yield{ 4.45 (~k) '.~~...-~ Other Vol: 0 Purpose: FILLER CEM Mix Water: 20.70 (gal) Foam Job: N ,." Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Stage No: 1 Slurr ./ Description: 2,894.00 (ft) Cmt Vol:/?ÀO{?bl) Slur~1240 (s~) 1/ ¡ ; ~ Temperature: ('~j' Temperature: (OF) Temperature: (OF) Density: 15.80 (ppg) Water Vol: 29.0 (bbl) Class;"ß... . Yi¢t 1 ,17 (JW$k) O~V6(Ö' Purpose: SHOE INTEG Mix Water: 5.10 (gal) Foam Job: N Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Printed: 9/29/2004 11:16:19AM e e Legal Well Name: C02-53 Common Well Name: C02-53 Event Name: ROT - DRILLING Report #: Start: 1 7/2/2004 Spud Date: 7/3/2004 Report Date: 7/5/2004 End: 7/18/2004 Shoe Test Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation tion Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: PJSM - Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/ nut plug for marker - Pressure test lines to 2600 psi - Dropped btm plug - Mixed & pumped 50 bbls MudPushXL 1ò':5PP'9= 5.9 BPM @ 230 psi - Mix & pump lead slurry (ASL) @ 10.7 ppg -7,5 BPM @ 220 psi - Observed nut pl~~ker @ shakers w/385 bbls lead pumped - pumped down tub (410 bbls total pumped) - switch to tail slurry (G w/ .30% D065, .20% D046, 1 % S002) @ 15.8 ppg - 4.5 BPM @ 210 psi - Dropped top plug w/ 20 bbls water f/ Dowell - Switch to rig pumps & displace w/ 9.6 ppg mud @ 7 BPM @ 430 to 550 psi - Observed cement to surface w/90 bbls of displacement away - Observed returns decrease w/175.5 bbls away - slowed pump to 5 BPM @ 530 psi - slowed pump to 3.5 BPM w/200 bbls of displacement - Observed slight returns for last 36 bbls of displacement - Bumped plug w/1000 psi - CIP @ 2315 hrs. Check floats - floats didn't hold - Pressure up to 1000 psi & shut in cmt head. Annulus was standinQlürrãfrer shutting down - Approx. 90 bbls cmt returns to surface "O\0~<L "> ~ \,),'("\~<::.0 ~() 50 . ?- s%~ L-{15 ~s- -50 ~O C\'O \\(:~') .\cl, \ \µ 0.. \-«, '" 4 '-C(~~-\ ~ S-..)ç\C1.c...~ Printed: 9/29/2004 11:16:19AM e e 1 REPT NO. 1 DATE 4 7/5/2004 ICUM.TANGO CUM INTANG WI MUD o CUM COST WI MUD 751,142 I JOB NUMBER I EVENT CODE 124 HRS PROG TMD 1 TVD I DFS CD2-53 ODR 3,402.0 2,375.0 3.00 SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Burley / Mickey Doyon Drilling Inc 19 ALPINE 17,323.0 0 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD WELL NAME NU BOPE DATE OF LAST SAFETY MEETING DAILY TOTAL 302,982 o 24 HR FORECAST Test BOPE - MU 8 1/2" BHA - RIH - FIT - Drill 8 1/2" hole LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF LAST SURVEY: DATE TMD INC AZIM I LAST CASING 7/4/2004 3,352.60 58.650 145.440 9.625 (in) @ 3,394.0 (It) DENSITY(ppg) I 9.60 I PP I ECD I I MUD DATAl DAILY COST I Fvl PVNPI GELS I WLJHTHP I FC/T.SOL OILJW/ ATJ o/oSO.a2ln2d1M8 .8BT I P8h1.8P/M 65 25/19 4/10 6.4/ 21 BHA NO. I 3 BHA WT. BELOW JARS 10035303 I NEXT CASING 7.000 (in) @ 12,496.0 (ft) o I CUM COST I Pf/Mf CI I 6cOa I 0.01/0 I AFE STRING WT. UP BHA I HOLE CONDITIONS STRING WT. DN I STRING WT. ROT ITEM DESCRIPTION NO JTS 1 1 1 1 1 1 1 1 1 1 1 1 24 Bit Mud Motor Sub - Float Stabilizer Crossover - Non Mag MWD MWD MWD Sub - Bottom Hole Orienting Drill Collar - Non Mag Drill Collar - Non Mag Jars Drill Pipe - Heavy Wgt LENGTH 1.00 31.10 2.47 5.92 2.44 9.17 8.70 9.90 2.75 31.03 31.03 34.57 716.37 BIT/RUN I 1 rr2 / 3 I TYPE MX-C1 BITS I SERIALNO. JETSORTFA 5048918 18/16/16/12/1 SIZE I MANUF. '12.250 HTC 0.0, 12.250 8.000 8.000 8.150 8.140 8.020 8.020 8.090 8.000 2.812 8.062 7.500 5.000 TORQUE / UNITS I.D, 4.500 5.000 2.870 2.875 2.875 3.500 1.920 1.900 2.875 2.875 2.880 2.750 3.000 AUTH. LAST BOP PRES TEST H2S o I LIME I ES BIT NO. I 1 rr2 BHA LENGTH 886.45 CONN SIZE CONN TYPE DEPTH IN DATE IN I I-O-D-L-B-G-O-R 703.0 7/3/200~ 1-1-NO-A-E-I-NO-TD BIT / RUN WOB BIT OPERATIONS RPM I GPM I PRESS I P BIT I HRS I 24Hr DIST j 24Hr ROP j CUM HRS I CUM DEPTH I CUM ROP OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 01:00 1.00 DRILL P CIRC SURFAC Pumped 35 bbls of 20 ppb LCM pill - increased rate to 450 gpm /1310 psi /50 rpm and circ hole clean. 01:00 06:00 5.00 DRILL P TRIP SURFAC Flow check well, static. POOH on trip tank from 3402' to 2400', no problems. Backream from 2400' to 1168' - 400 gpm /1050 psi / 50 rpm. 06:00 07:30 1.50 DRILL P TRIP SURFAC Backreamed slowly from 1168' to 997' to clean up hole / 500 gpm /1300 psi/ 50 rpm - had large amount of drill cuttings back across shakers. Pump out to 880', orientate tools highs ide. Flow check well, static. 07:30 08:30 1.00 DRILL P TRIP SURFAC POOH on trip tank - standing back hwdp from 880' to 170' - hole took proper fill. 08:30 11:30 3.00 DRILL P PULD SURFAC Lay down jars - (2) 8" flex dc's - ubho- TM - HCIM - DM - xo- stab - fs - motor and bit. Clear tools from rig floor. Clean up trip mess. Printed: 9/29/2004 11 :15:07 AM e e CD2-53 1 JOB NUMBER I EVE~TDC~DE 124 HRS PROG ITMD TVD IDFS 3,402.0 2,375.0 3.00 1 REPT NO. 1 DATE 4 7/5/2004 OPERATIONS SUMMAR¥ PHASE DESCRIPTION SURFAC RU to run 9 5/8" casing. SURFAC Held Pre-Job safety and Opts meeting. SURFAC Run 95/8" casing - FS - 2 joints - FC - 2 jts ( Baker-Ioc 1st four joints - circ and check floats) all joints 9 5/8",36#, J-55, BTC - Continue to run casing 1430'. 35 joints total. SURFAC Stage pumps up to 5 bpm - circ 1 pipe volume - FCP 280 psi. PUW 115K SOW 107K SURFAC Continue to run 9 5/8" casing to 2505' - 61 jts. total SURFAC Break circulation & stage pumps up to 5 BPM & Circulate bottoms up 390 psi - PU wt - 135 SO wt. 110 SURFAC Continue running 9 5/8" casing f/2505' to 3355' ( 82 jts. total) PU hanger & landing jt. & land casing wI shoe @ 3394' & FC @ 3312' - st wt. 175 PU 120 SO SURFAC RU casing equipment & fill up tool - RU cmt head & lines SURFAC Circulate & condition mud & hole for cmt job - 5 bbls/min @ 320 psi - No losses SURFAC PJSM - Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water wI nut plug for marker - Pressure test lines to 2600 psi - Dropped btm plug - Mixed & pumped 50 bbls MudPushXL 10.5 ppg - 5.9 BPM @ 230 psi - Mix & pump lead slurry (ASL) @ 10.7 ppg - 7.5 BPM @ 220 psi - Observed nut plug marker @ shakers wI 385 bbls lead pumped - pumped down tub (410 bbls total pumped) - switch to tail slurry (G wI .30% D065, .20% D046, 1 % S002) @ 15.8 ppg - 4,5 BPM @ 210 psi - Dropped top plug wI 20 bbls water fl Dowell - Switch to rig pumps & displace wI 9.6 ppg mud @ 7 BPM @ 430 to 550 psi - Observed cement to surface wI 90 bbls of displacement away - Observed returns decrease wI 175.5 bbls away - slowed pump to 5 BPM @ 530 psi - slowed pump to 3.5 BPM wI 200 bbls of displacement - Observed slight returns for last 36 bbls of displacement - Bumped plug wI 1000 psi - CIP @ 2315 hrs. Check floats - floats didn't hold - Pressure up to 1000 psi & shut in cmt head. Annulus was standing full after shutting down - Approx. 90 bbls cmt returns to surface OTHR SURFAC Cement head shut in - clean up floor WELL NAME FROM TO HOURS CODE TROUBLE SUB 11 :30 13:00 1.50 CASE P RURD 13:00 13:15 0.25 CASE P SFTY 13:15 15:30 2.25 CASE P RUNC 15:30 16:00 0.50 CASE P CIRC 16:00 17:00 1.00 CASE P RUNC 17:00 17:30 0.50 CASE P CIRC 17:30 18:45 1.25 CASE P RUNC 18:45 19:15 0.50 CASE P RURD 19:15 21:00 1.75 CEMENT P CIRC 21:00 23:30 2.50 CEMENT P PUMP 23:30 00:00 0.50 CEMENT TEQIP 24 HR SUMMARY: POOH - LD BHA - RU and run 82 jts of 9 5/8" casing - Circ - Cmt casing COMPANY ConocoPhillips Company Fairweather E&P Service Doyon Drilling Inc Arctic Catering Inc. Dowell SERVICE ITEM USAGE 518 300 Fuel Water, Drilling UNITS gals bbls PERSONNEL DATA NO. HOURS COMPANY 1 Halliburton - Sperry-Sun 1 Halliburton - Sperry-Sun 26 M-I Drilling Fluids 5 Swaco 2 FMC Corporation Wellhe SERVICE NO, HOURS 1 2 3 4 1 MATERIALS I CONSUMPTION ON HAND ITEM 5,120 Water, Potable -3,190 Fuel USAGE 120 ON HAND -360 UNITS bbls gals Printed: 9/29/2004 11 :15:07 AM e e GD2-53 I JOB NUMBER I EVE;TDC~DE 124 HRS PROG ITMD ITVD IDFS 3,402.0 2,375.0 3.00 I REPT ~O. I DATE 7/5/2004 WELL NAME CD2-36 CD2-53 869 3.5 1490 Printed: 9/29/2004 11:15:07 AM Well Neme: Drilling Supervisor: I Type of Test: 1 OpenholeTest LOT/FIT Hole Size: 8-1/2" v I RKB-CHF: I CesintI Size and Description: Casin9 Test Mud Weight: Mud 10 min Gel: Test Pressure: Rotating Weight: BlocksITop Drive Weight: Estimates for Test: ,PRESSURE INTEGRITY TEST CONOCOPHILLlPS Alaska, Inc. Date: I I #2 Mud Pump I. r Pumping down annulus and DP, . Casin9 Shoe Depth I I Hole Depth 1Ft-MOl I 19-5/8" 36#/Ft J-55 BTC I Ri9: ppg Lb/100 Ft2 psi Lbs Lbs 2.5 bbls .Pressure InteqritvTest Mud Weight ppg Mud 10 min Gel: Lb/100 Ft2 Rotating Weight: Lbs Blocksffop Drive Weight: Lbs Desired PIT EMW: ppg Estimates for Test: 1048 psi 1 bbls Iv ·L EMW = Leak-off Pressure + Mud Weight :::::: 800 9 5 0.052 x TVD 0.052 x 2370 + . EMW at 3394 Ft-MD (2370 Ft-TVD) = 16.0 ppg 3000 2500 . 2000 w a: ::Þ en 1500.. en w a: Il. 1000 500 ' ~'+ 0... _ o ~CASING TEST Comments: / ...:.J - "þilll1 /" / fI''f' 2 3 Barrels PIT 15 Second Shut-in Pressure, psi 600 - Lost 50 psi during test, held 98% of test pressure. 4 0 5 10 15 20 25 30 Shut-In time, Minutes o PIT Point -LEAK-OFF TEST I Volume Input 1..- Strokes .. Volume/Stroke Bbls/Strk .. Casin£ Test Pumping Shut-in Strks psi Min vf Volume Pumped 3.0 Bbls Pump Rate: Strk/min ------1 .. Pressure Integrity Test Pumpin~ Shut-in Strks si Min o 1 2 3 4 5 6 7 8 9 10 15 20 25 30 Volume Bled Back JBbls Volume Pumped 1.6 Bbls o 0.25 0.5 1 1.5 2 2.5 3 3.5 4 4.5 5 5.5 6 6.5 7 7.5 8 8.5 9 9.5 10 Volume Bled Back tBbls e e Conocó'Phillips Casing Detail 7" Casing Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKB to Landing Ring FMC Gen V Hanger Jts 3 to 293 291 Jts 7" 26# L-80 BTCM Csg Davis Lynch Float Collar Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg Ray Oil Tools "Silver Bullet" Float Shoe TD 81/2" Hole Total Centralizers: 54 Straight blade centralizer one per jt on jts # 1-14 Straight blade centralizer one per jt on jts. # 214, 215, 216 Straight blade centralizer one every other joint Joints # 218 thru joint # 290 300 joints in shed - 293 total jts. to run Last 7 jts. out Use JET LUBE Run & Seal pipe dope Remarks: Up Wt - 350 k On Wt - 140 k Block Wt - 75k Supervisor: D. Burley / L. Hill Well: Date: LENGTH 34.37 2.36 12270.41 1.31 83.76 2.13 C02-53 7/11/2004 DEPTH TOPS 34.37 36.73 12307.14 12308.45 12392.21 12394.34 12407.00 e Legal Well Name: C02-53 Common Well Name: C02-53 Event Name: ROT - DRILLING Primary Hole Size: 8.500 (in) TMD Set: 12,394 (ft) Date Set: 7/12/2004 Csg Type: Production Casing Csg Size: 7.000 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Rot Time Start: Rec Time Start: Time End: Time End: Type: Cement Casing Volume Excess %: 40.00 Meas. From: 0 Time Circ Prior To Cementing: 2.00 Mud Circ Rate: 284 (gpm) Mud Circ Press: 840 (psi) Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Cmtd. Csg: e Report #: Start: Spud Date: 7/3/2004 Report Date: 7/12/2004 End: 7/18/2004 2 7/2/2004 Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Cementer: Steve Daughton Pipe Movement: No movement RPM: SPM: Init Torque: Stroke Length: (ft-Ibf) (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Max Torque: (ft-Ibf) Drag Down: (Ibs) Stage No: 1 of 1 Start Mix Cmt: 05:57 Start Slurry Displ: 05:58 Start Displ: 06:05 End Pumping: 07:14 End Pump Date: 7/12/2004 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.75 (bbl/min) 7.10 (bbl/min) Y 630 (psi) 1 ,130 (psi) 2 (min) Y Ann Flow After: N Mixing Method: Density Meas By: Press scal Type: Non-Disp. LS Density: 9.8 (ppg) Visc: 40 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Mud Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: lake Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Mud PVNP: 8 (cp)/18 (lb/100ft2) Gels 10 sec: 6 (lb/100ft2) Gels 10 min: 7 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.8 (ppg) Volume: 470.00 (bbl) Stage No: 1 Slur To: (ft) Description: CW100 Cmt Vol: 20.0 (bbl) Slurry Vol: (sk) Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Purpose: Chemical was Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Printed: 9/29/2004 11 :16:40 AM e e 3 Legal Well Name: C02-53 Common Welll\Jame: C02-53 Event Name: ROT - DRILLING Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Slurry Data Fluid Type: TAIL Slurry Interval: 12,394.00 (ft)o: Water Source: lake water Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Trade Name D-65 B-155 D-46 D-167 Report #: Start: Spud Date: 7/3/2004 Report Date: 7/12/2004 End: 7/18/2004 2 7/2/2004 Stage No: 1 Slurr 3 To: (ft) Description: MUDPUSH XL Class: Cmt Vol: 50.0 (bbl) Density: 12.50 (ppg) Yield: (fP/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Pressure (psi) (psi) Temp (OF) (OF) Description: 11 ,663.00 (ft~mt Vol: 30.2 (bbl) Slurry Vol:140 (sk) Class: G Density: 15.80 (ppg) Yield: 1.16 (ft3/sk) Water Vol: 17.0 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: 5.09 (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Stage No: 1 Slurry No: 3 of 3 - A Type DISPERSANT retarder DEFOAMER Fluid loss Units Concentration 0.30 %BWOC 0.07 %BWOC 0.20 %BWOC 0.40 %BWOC Printed: 9/29/2004 11 :16:40 AM e e legal Well Name: Common Well Name: Event Name: C02-53 C02-53 ROT - DRilLING Report #: Start: 2 7/2/2004 Spud Date: Report Date: End: 7/3/2004 7/12/2004 7/18/2004 Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: 12.50 (ppge) Tool: N Open Hole: (It) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (It) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Staged pumps up to 7 bpm - ccirc and cond mud for cementing - reduced YP to < 20, FCP @ 840 psi full returns throughout. Reciprocated pipe PUW 350K SOW 140K (initial) began lossing slack off wt., landed casing @ 0400 hrs. PJSM. "------, Cement 7" casing as follows: Pumped 5 bbls CW-100 - Test cement lines to 3500 psi - Pumped 15 bbls CW-100 - Pumped 50 bbls Mud PushXL @ 12.5 ppg @ 5 bbls/min. - Dropped btm plug - Mixed & pumped 30.2 bbls slurry (G wI D46 0.2%, D65 0.3%, B155 0.07%, D167 0.4%) @ 15.8 ppg I 5.5 bbls/min I 375 psi Dropped top plug wI 20 bbls water fl Dowell - switched to rig pumps & displaced wI 9.8 ppg mud @ 7 bbls/min 1690 psi for first 396 bbls of dispalcement - slowed pumps to 6 bbls/min @ 650 to 800 psi for 49 bbls - slowed rate to 3.5 bpm last 5 bbls pumped final pressure 630 psi - bumped plugs to 1130 psi - total displacment 450 bbls - calc. 450.1 bbls. - CI P @ 0715 hrs. - floats held - Full returns during job. Printed: 9/29/2004 11: 16:40 AM e e DATE OF LAST SAFETY MEETING DAILY TOTAL Drill 6 1/8" horizontal hole 7/12/2004 431,863 I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE FINE SAND 15.98 10035303 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING 7/10/2004 12,374.39 80.478 151.960 7.000 (in) @ 12,394.0 (ft) 3.500 (in) @ 11,952.0 (ft) DENSITY(ppg) I 9.80 I PP I IECDI IMUD DATA! DAILYCOST I 0 I CUMCOST I :; I :~7: I G7~~S I ~~:':P I F~~SOL I OIU;AT I o/~~~~~~:T I P;;; 1.~~~f5 CI I 2~~ I BHA NO. I 5 I BHA I HOLE CONDITIONS ¡ BHA WT. BELOW JARS I STRING WT, UP STRING WT. DN I STRING WT. ROT TORQUE I UNITS ITEM DESCRIPTION NO JTS LENGTH O.D. I.D. 1 0.75 6.125 2.250 1 32.81 4.974 2.794 1 1.55 4.625 2.250 1 5.53 4.790 2.256 1 8.54 4.750 2.250 1 24.48 4.750 1.250 1 10.87 4.700 1.250 1 11.04 4.750 2.250 3 93.34 4.700 2.250 1.18 4.770 2.625 91.95 3.500 2.060 32.46 4.750 2.000 61.31 3.500 2.063 WELL NAME SUPERVISOR Burley IHill CURRENT STATUS 24 HR FORECAST LITHOLOGY Bit Motor Sub - Float 6" Stab MWD MWD MWD MWD NM Flex DC's Crossover 3 X HWDP Jar DNT 2 X HWDP B~~I RUN 51 BIT I RUN FROM TO 00:00 01 :15 01:15 03:00 I JOB NUMBER I EVENT CODE 124 HRS PROG TMD 1 TVD I DFS CD2-53 ODR 12,407.0 7,207.0 10.00 I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAIL Y TANG Doyon Drilling Inc 19 ALPINE 17,323.0 0 ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD Performing PIT @ 12427' o 1 REPT NO. I DATE 11 7/12/2004 ICUM. TANGO CUM INT ANG WI MUD o CUM COST WI MUD 2,176,566 AUTH. LAST BOP PRES TEST 7/12/2004 o H2S I LIME I ES BIT NO. I 3 BHA LENGTH 375.81 CONN SIZE CONN TYPE SIZE I MANUF. I TYPE 6.125 HUGHES-CHR HC 306 BITS I SERIAL NO, I JETS OR TFA 7104036 12/12/13/13/13/13 I DEPTH IN DATE IN I I-O-D-L-B-G-O-R 12,407.0 7/12/200~ 1-1-NO-A-D-I-NO-TD BIT OPERATIONS RPM I GPM I PRESS I P BIT I HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP HOURS 1.25 1.75 OPERATIONS SUMMARY PHASE CODE CASE P CASE P INTRM1 INTRM1 DESCRIPTION Stage pumps up to 4 bpm and CBU - FCP 570 psi. PUW 310K SOW 145K. Run 7" casing f/1 0945' to 12351' (293 jts. total) MU landing joint and FMC fluted hanger and land casing with float shoe @ 12394' and Float collar @ 12307' . 03:00 03:30 0.50 CASE P OTHR INTRM1 LD fill up tool - blow down Top Drive - MU cement head and lines. 03:30 05:30 2.00 CEMENT P CIRC INTRM1 Staged pumps up to 7 bpm - ccirc and cond mud for cementing - reduced YP to < 20, FCP @ 840 psi full returns throughout. Reciprocated pipe PUW 350K SOW 140K (initial) began lossing slack off wt., landed casing @ 0400 hrs. PJSM. 05:30 07:30 2.00 CEMENT P PUMP INTRM1 Cement 7" casing as follows: Pumped 5 bbls CW-100 - Test cement lines to 3 2 WOB TROUBLE SUB CIRC RUNC Printed: 9/29/2004 11:15:50 AM WELL NAME CD2-53 e e Conoco I JOB NUMBER I EVE~Dc~DE 124 HRS PROG I TMD I TVD I DFS I REPT NO. I DATE 12,407.0 7,207.0 10.00 11 7/12/2004 OPERATIONSSWMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 05:30 07:30 2.00 CEMENT P PUMP INTRM1 3500 psi - Pumped 15 bbls CW-100 - Pumped 50 bbls Mud PushXL @ 12.5 ppg @ 5 bbls/min. - Dropped btm plug - Mixed & pumped 30.2 bbls slurry ( G wI D46 0.2%, D65 0.3%, B155 0.07%, D167 0.4%) @ 15.8 ppg 15.5 bbls/min I 375 psi Dropped top plug wI 20 bbls water fl Dowell - switched to rig pumps & displaced wI 9.8 ppg mud @ 7 bbls/min 1690 psi for first 396 bbls of dispalcement - slowed pumps to 6 bbls/min @ 650 to 800 psi for 49 bbls - slowed rate to 3.5 bpm last 5 bbls pumped final pressure 630 psi - bumped plugs to 1130 psi - total displacment 450 bbls - calc. 450.1 bbls. - CIP @ 0715 hrs. - floats held - Full returns during job. 07:30 08:15 0.75 CASE P MIT INTRM1 Test casing to 3500 psi for 30 min. 08:15 08:45 0.50 CASE P RURD INTRM1 Rigged down Casing and cementing tools. 08:45 09:45 1.00 CASE P PTCH INTRM1 Installed and tested packoff on casing hanger to 5000 psi. 09:45 15:00 5.25 WELCTL P BOPE INTRM1 Changed rams and set test plug. Tested BOP. Annular tested 250/3500. Rams, Kill and choke lines, choke valves, top drive valves, and floor valves tested 250/5000 PSI. Tested closing unit. Pulled test plug and installed wear bushing. Witinessed by Chuck Scheve from State. 15:00 15:30 0.50 DRILL P RIRD INTRM1 Rigged up bales and elevators. 15:30 17:45 2.25 DRILL P PULD INTRM1 Pick up BHA and RIH. 17:45 22:15 4.50 DRILL P PULD INTRM1 Pick up and RIH 4" DP to 5623'. 22:15 00:00 1.75 DRILL P TRIP INTRM1 RIH with stands to 9919'. 24 HR SUMMARY: Run casing - cond mud and cement casing, FS @ 12394', FC @ 12307'. Install and test packoff - Test BOPE - MU BHA # 5 - PU 168 jts of 4" drill pipe - RIH to 9919'. COMPANY ConocoPhillips Company Fairweather E&P Service Doyon Drilling Inc Arctic Catering Inc. Dowell Halliburton - Sperry-Sun ITEM Fuel Water, Drilling RESERVOIR NAME CD2-27 SERVICE PERSONNEL DATA NO. HOURS COMPANY 1 Halliburton - Sperry-Sun 1 M-I Drilling Fluids 26 Swaco 5 FMC Corporation Well he 2 Other 2 10 SERVICE NO. HOURS 2 4 4 UNITS gals bbls MATERIALS I CONSWMPTION USAGE ON HAND ITEM 661 10,640 Water, Potable 800 970 Fuel UNITS bbls gals USAGE 120 ON HAND 800 2,080 I CD2-53 RESERVOIR AND INTERVAL DATA ZONE I TOP I BASE 1 1662 3.5 1150 COMMENTS Printed: 9/29/2004 11 :15:50 AM Well Name: I Ri9: Drilling Supervisor: I / Type of Test: I Annulus Leak Off Test for Disposal Adequacy Hole Size: 8-1/2" 1..-' Casing Shoe Depth RKB-CHF:I 1Ft-MOl Casinq Size and Description: 19-5/8" 36#/Ft J-55 BTC ,ChanQes for Annular AdeQuac,< Test Juter casing shoe test results in comments Description references outer casing string. ;ize is that drilled below outer casing. ;timated TOC for Hole Depth. Enter inner casing OD at right I Volume Input Barrels I'" ... Casinf Test Pumpin(; Shut-in Bbls psi Min psi PRESSURE INTEGRITY TEST CONOCOPHILUPS Alaska, Inc. IDate: I I Cement Unit I... Pumping down annulus. I I Hole Depth Ft-MD I I Ft-TVD ·r Pressure InteQrityTest Mud Weight: ppg Inner casing 00: In. Desired PIT EMW: Estimates for Test: ppg 641 psi 0.7 bbls I·, .l. EMW == leak-off Pressure + Mud Weight = 534 9 8 0.052 x TVD 0.052 x 2370 + . EMW at 3394 Ft-MD (2370 Ft-TVD) = 14.1 1000 W IX: ::> en 500- en w IX: c.. .~ ~ -.~ o o 2 3 4 Barrels 5 6 -LEAK-OFF TEST """IIIIIIøroCASING TEST Comments: PIT 15 Second Shut-in Pressure, psi 490 7 8 o 5 10152025 Shut-In time, Minutes o PIT Point I· 30 Volume Pumped 0.0 Bbls Volume Bled Back 1Bbls Pressure Integrity Test Pumping Shut-in Bbls . psi Min psi o 0.25 0.5 1 1.5 2 2.5 3 3.5 4 4.5 5 5.5 6 6.5 7 7.5 8 8.5 9 9.5 10 Bbls/Strk I ... o 1 2 3 4 5 6 7 8 9 10 15 20 25 30 Volume Pumped 7.0 Bbls Pump Rate: Bbl/min -------1 ..... Volume Bled Back IBbls WElL DETAIlS ""'" Plan:CDg3 +N/·S ·376.88 +FJ..W Northing 46.53 5974264.070 &stiug 371136.310 -1320 -1240 ~-1033 ··~827 --;)20 -413 -207 -0 270 --207 -·413 --620 -827 ~-1033 -1240 -1320 Latirude LoJJgÎ!t¥k Slot 70"2O'16.518N 15l"02'26.724W NlA ANTI·COLLISION SETTINGS WElLPATHDET AILS Rig: CD2~53 COMPANY DETAILS Conooo=kaInc - MethodMD From: 3384.00 MIWJJ1UII} auge: 1320.00 Interval: 1.00 To: 4004.00 Reference: DefwtÎve Survey ~ Ref. Duum: 52'MSL 52,{JOft CakuJarion Method: Minimum Curvature Error System: LSCWSA ScaJI:Meihöd; fIorizontalP!ane Ewl' SI.1I'ÛCe; Et&ptical+Casing Waming Method: Rub; Bastd 36.10 V.Section Aug" S"""" FromTVD Origin Origin +Nf·S +FJ-W CDZ-52 (CO2-52) o 147.351" 0.00 0.00 From Colour 36 300 400 500 750 1000 1250 1500 1750 2000 2500 3000 3500 4000 4500 5000 5500 6500 7500 8500 9500 10000 10500 ¡¡ 000 12000 13000 14000 15000 16000 17000 18000 19000 90 180 B2!J Reference Azimuth Angle [deg] vs Centre to Centre Separation [ft] --- -- -----] ToMD 300 400 500 750 1000 1250 1500 1750 2000 2500 3000 3500 4000 4500 5000 5500 6500 7500 8500 9500 10000 10500 ¡¡ 000 12000 13000 14000 15000 16000 17000 18000 19000 2??oo e e SURFACE CASING SHOE SEPARATION FROM CD2-53 CD2-~3 x y Surface Casing Shoe ASP 4 Coordinates: 372896,67 5972509,19 Ulstance Details from Surface csg. Surface csg. @ Ann. Object Shoe X Shoe Y Wells AOGCC Permit # Permit Date Source well Vol. .... Start Date End Date well' Coord. Coord. CD2-35" y .----' - - ~--- - 1618 372312.31 5974017.68 CD2-24, CD2-33, CD2-33A, CD2-42 Y 301-140 6/1/2001 CD2-15 33992 6/1/2001 10/10/2001 2331 371098.46 5973992.48 CD2-33 (+A&B), CD2-39, CD2-24 Y 301-186 7/13/2001 CD2-14, CD2-15 33999 7/16/2001 1 0/9/2001 3167 370630,11 5974721.81 CD2-33 B'" Y ----- - - ---- --- - 3067 370155.64 5973886.23 CD2-39 Y 301-281 10/9/2001 CD2-15, CD2-47, CD2-44 29945 10/10/2001 9/16/2002 1250 372350.61 5973633.17 CD2-14 Y 301-288 10/9/2001 CD2-45, CD2-47, CD2-32 31073 11/13/2001 315/2002 2548 372202,47 5974960,87 CD2-15 Y 301-308 11/6/2001 CD2-50, CD2-25, CD2-44 31652 3/6/2002 9/21/2002 3223 370832.00 5974984.02 CD2-47 Y 301-322 12/3/2001 CD2-34, CD2-26 27349 12/17/2001 1/20/2002 1841 371231.72 5973294,19 CD2-45 Y 301-345 12/13/2001 CD2-49, CD2-17 22991 1/20/2002 2/19/2002 1351 372765.13 5973853,74 CD2-34 Y 302-069 3/4/2002 CD2-13, CD2-37 22842 10/17/2002 11/28/2002 2219 371803.06 5974439.79 CD2-26 Y 302-068 3/4/2002 CD2-44, CD2-29, CD2-13 29626 9m2002 10/17/2002 2322 371798.52 5974554.55 CD2-49 Y 302-070 3/4/2002 CD2-50, CD2-46, CD2-22 27960 4/22/2002 5/28/2002 2264 371252.38 5974065.93 CD2-17 Y 302-122 4/10/2002 CD-48, CD2-08 18181 5/29/2002 2f712003 2413 371774,00 5974645.00 CD2-32 Y 3Q2-119 4/30/2002 CD2-19, CD2-41, CD2-23 31113 6/14/2002 7/23/2002 2404 371295.61 5974302.38 CD2-41, CD2-19, CD2-16, CD2-50 y 302-121 4/30/2002 CD2-38 32000 7/24/2002 9m2002 2114 371665,21 5974227.65 CD2-25 Y NA 2362 371594.00 5974479.00 CD2-46 Y 302-273 9/20/2002 CD2-51, CD2-12 31864 4/15/2003 5/19/2003 2166 371694.80 5974310.85 CD2-22 Y 302-274 9/20/2002 CD2-08, CD2-36, CD2-51 31253 2f712003 3/16/2003 2387 371678.61 5974562,30 CD2-28, CD2-35a, CD2-48 y 302-275 9/20/2002 CD2-45, CD2-08 32000 12/10/2002 2/4/2003 1762 371631.74 5973736.14 CD2-19 Y 303-083 4/28/2003 CD2-58, CD2-52 31337 5/19/2003 6/27/2003 2257 372284.88 5974681.33 CD2-41 Y 303-081 4/28/2003 CD2-20, CD2-55,CD2-43 32000 6/27/2003 7/28/2003 1579 371990.58 5973802.52 CD2-23 Y 303-080 4/28/2003 CD2-18, CD2-55, CD2-06 32000 9/4/2003 1/1/2004 3179 371013.17 5975070.46 CD2-16 Y ----- - -' ---- --- - 2322 372460.34 5974790.01 CD2-38 Y 303-082 4/28/2003 CD2-40, CD2-30 30011 7/28/2003 9/412003 1334 372033,86 5973527,13 CD2-44 Y ---- - ---- --- - 2013 372034.57 5974328.53 CD2-29 Y 303-249 8/25/2003 CD2-06, CD2-30, CD2-27 29036 1 0/8/2003 11119/2003 2399 372652.44 5974896.02 CD2-13 y ---- - - ....--:: --- - 3285 372658.78 5975785.31 CD2-37 Y ----- - :---: --- - 1376 371569.79 5972874.47 CD2-28 Y -:;:::::::. - - :---: --- - 2345 372139.80 5974728.95 CD2-08 Y - ::--- --- - 3104 372655.88 5975603.76 CD2-36 Y 303-365 12/12/2003 CD2-43 32000 12/31/2003 7/912004 1467 371848,22 5973535.38 CD2-51 Y 303-312 10/28/2003 CD2-07, CD2-10 31769 11/19/2003 12/2412003 928 373114.02 5973411.81 CD2-12 Y 303-365 12/12/2003 NA 32000 5/15/2004 6/912004 3458 371071.29 5975445,60 CD2-58 y NA 808 372102.03 5972657.80 CD2-52 Y NA 1181 372637.61 5973661.63 CD2-20 y 304-288 7/30/2004 NA 3366 371366.14 5975507.11 CD2-55 Y --- - - ---- --- - 1906 371118.23 5973194.84 CD2-40 y NA 0 2556 370691.67 5973801.44 CD2-3O NA 0 2662 370473.52 5973610,96 CD2-18 --- - - ---- ~ - 3782 369825,76 5974716.05 CD2-06 y NA 0 3737 371610.81 5976018.45 CD2-27 Y 304-226 6/23/2004 NA 32000 7/9/2004 8/27/2004 582 373046.07 5973071.83 CD2-10 y 304-289 7/30/2004 NA 24294 8/27/2004 9/23/2004 3665 371800,58 5976006.36 CD2-07 Y NA 0 3839 372218.06 5976287.95 CD2-43 --- - Ar,..t;^~ ---- ~ - 2746 370344.04 5973520,68 'CD2-57 Y NA 0 404 372537.05 5972324.37 CD2-31 NA 0 3635 ~ß9824.37 5974451..3Q.-, CD2-53 NA 0 0 SZ2896.67 5972509...1-9 ~, CD2-05 NA 0 2909 370258.60 5973735.40 CD2-09 NA 0 4534 370318.00 5976239.00 'CD2-56 NA 0 3069 369875.93 5973053.08 CD2-54 NA 0 QQ?ID 369991.09 5973363.59 . Lateral distance in feet, between surface casing shoes, in the X-Y plane .. CD2-35 was drilled from an ice pad in early 1998, The 9-5/8' x 7' annulus has not been permitted for annular disposal. '''CD2-33 B was a delineation well with a window milled out of 9-5/8' casing at 3840' MD (3062' TVD), shoe depth shown indicates window depth. It has not been permitted for annular disposal. .... As of 9-23-04 Note that this sheet is not the definitive record e e ;(~£l2C¡ /2 ç, ifo WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: ftgbin IXc\Sðl\ ~ 333 West 71lt Avenue, Suite 100 Anchorage, Alaska 99501-3539 August 05, 2004 RE: MWD Formation Evaluation Logs: CD2-53, AK-MW-3143996 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: Rob Kalish, Sperry-Sun, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20494-00. RECEIVED SEP ~ 2004 AI", /, 1'" D ~ . . rmn·· I I). ~ r- fÃ\ II I ~ \ Lb lIìj 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 FRANK H. MURKOWSKI, GOVERNOR J\. 'J1ASIiA OIL AND GAS CONSERVATION COMMISSION Chip Alvord Alpine Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage AK 99510 Re: Colville River Field CD2-53 ConocoPhillips (Alaska), Inc. Pennit No: 204-089 Surface Location: 2093' FNL, 1499' Sec. 2, TIIN, R4E, UM Bottomhole Location: 1337' FSL, 4084' FEL, Sec. 18, TIIN, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This pennit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission t witness any required test. Contact the Commission's petroleum field inspector at (907) 659 6 7 (pager). BY ORDER OF THE COMMISSION DATED this..1(day of June, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Drill~ Re-entry D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 1 a. Type of Work: STATE OF ALASKA ALASKA OIL & GAS COMMISSION PERMIT TO DRILL ExploratoryU Development Oil I..::d Multiple Zone D ServiceD Development Gas D Single Zone 0 5. Bond: I..::d Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 CO2-53 6. Proposed Depth: 12. RelcVPooI(s): / MD: 17323' " 1VD: 7222' Colville River Reid 7. Property Designati0.9: ADL 380075, 372097 8. Land Use Pennit: '- RedrillU 1 b. Current Well Oass: Stratigraphic Test D P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 2093' FNL, 1499' FEL, Sec. 2: T11N, R4E:, UM j Top of Productive Horizon: ,/ 439' FSL, 1649' FEL, Sec. 12, T11 N, R4E, UM Total Depth: ""1"1/M r<.ÇE J ./ 1337FSL,4084'FEL,Sec. 18,)13N,n4C,~ }~.2.~.Dcf 4b. Location of Well (State Base Plane Coordinates): Surface: x- 371736.31 v 16. Deviated v.ells: Kickoff depth: 225 ft. 18. Casing Program Size Hole 42' 12.25" 8.5" 6.125" Casing 16" 9,625" 7" 3.5" 19 Total Depth MD (ft): Weight 62.5# 36# 26# 9.3# ./ y- 5974264.1 Zone- Maxim.Jm Hole Angle: 910 Specifications Grade Coupling Length H-40 Weld 77' J-SS BTC 3327' L-80 BTC-M 12459' L-80 EUE-M 11940' PRESENT WELL CONCmON SUMMARY Total Depth TVD (ft): Plugs (measured) Casing Structural Conductor Detailed Operations Intennediate Production Uner Perforation Depth MD (ft): 20. Attachrrents: RUng Fee 0 Property Plat D Length Size BOP SketchD Diverter Sketch D Drilling Program0 Seabed Report 0 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name f,.,,. C. Alvord ll~D.'1~ Signature '- ~ na 9. kres in Property: 2560 Alpine River Pool 13. Approximate Spud Date: 6'30/2004 14. Distance to Nearest Property: 439' FSL, Sec. 12 10. KB Elevation 15. Distance to Nearest 4 (Height above GL): 52 feet Well within Pool: CD2-39 , 926 17. Anticipated Pressure (see 20 MC 25.035) / V tv1ax. Do\M1hole Pressure: 3268 psig / Max. Surface Pressure: 2549 psig Setting Depth Quantity of Cement Top Bottom c. 1. or sacks MD TVD MD TVD (including stage data) 37' 37' 114' 114' 37' 37 3364' 2390' 619 sx AS Ute & 230 sx UteCrete 37 37 12496' 7232 (97 sx 11 ppg UteCrete,126 sx 15.8 32' 32' 11972' 7098' ppg G) sxOass G (To be COIl"pleted for Redrill and Re-Entry Operations) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Cement Volume MD TVD Perforation Depth 1VD (ft): Time v, Depth Plot D Drilling Auid Program 0 Date: Shallow Hazard Analysis D 20 AAC 25.050 requirements 0 Contact V. JohnsonlZ KuenzJer @265-6081/1308 Title Alpine Drilling Team Leader Phone 265-6120 Date 5/26/2004 '2.{'S - {. q 7 9 s /-¿ 7 J to 'of Preœred bv Zane Kuenz/er Commission Use Only Permit Approval f1t(o 1 I See cover letter Date: ~ t¡}Lf for other requirements Mud log requir D Yes H No Directional survey required ~ Yes 0' No Permit to Drill / / c.~ API Number: Number: .zD i-- ðc~ 1 so- /63- 2êl.;Jt(-Cb Conditions of approval: Samples required DYes Øo Hydrogen sulfide measures DYesS No \ t'-'. \J K- \3(J ? \-é c:, \- COMMISSIONER BY ORDER OF THE COMMISSION RECEIVED ~a~f~~:r;"n\C>\an A- Þ,ncnof8Qß J Form 10-401 Revised 3/20031 Submit in Duplicate . ORfGINA~ CD2-53 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole /9-5/8" Casina Interval Event Risk Level Conductor Broach Low Well Collision Low Gas Hydrates Low Running Sands and Gravel Low Abnormal Pressure in Surface Formations i >2000' TVD Lost Circulation Low Low 8-1/2" Hole /7" Casina Interval Event Risk Level Abnormal Pressure in low Surface Formations .j >2000' TVO Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure low Hydrogen Sulfide gas ,/ Low Mitigation Strate~y Monitor cellar continuously during ~terval. Gyro single shots as required v Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Increase mud weight Reduce pump rates, mud rheology, lost circulation material, use of low density cement slurries Mitigation Strate~y BOPE drills, Keep mud weight above 9.6 ppg. Check for flow during connections and if needed, increase mud weight. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weighted sweeps. Well control drills, increased mud weight. No mapped faults occur within 700' of the planned wellbore. H2S drills, detection systems, alarms, standard well control practices, mud scavengers 6-1/8" Hole / Horizontal Production Hole Event Risk Level Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure ) Medium Hydrogen Sulfide gas Low -£ Mitigation Strategy Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECO) monitoring, mud rheology, lost circulation material Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECO) monitoring, weighted sweeps. BOPE drills, Keep mud weight above 8.8 ppg. " Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. H2S drills, detection systems, alarms, standard well control practices, mud scavengers ~Æt.- Â~ \'¿~ih.·. .~ L ~r ~ tJ E' ~.'. - !¡¡;j " f! -".í" ó " ~ ~ ~.,' c '--'" '- Alpine: CD2-53 & CD2-53 PB1 Procedure 1. Move on Doyon 19. 2. Drill 12 1A" hole to the surface casing point as per the directional plan. 3. Run and cement 9 5/8" surface casing. '- 4. Pressure test casing to 2500 psi. v" 5. Install and test BOPE to minimum 5000 psi. 6. Pick up and run drilling assembly. Drill out 20' of new hole. Perform leak off test to 18 ppg. 7. Drill 8 %" hole to the intermediate casing point in the Alpine Sand. (LWD tools, GR/RES/PWD) v 8. Run and cement 7" casing as per program. Top of cement +1-500 feet MD above Nanuq (Albian 96) sand if present. Note: Carry out a leak off test down the 9-5/8" x r casing añnulus to ëonfirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus. 9. Pressure test casing to 3500 psi. --- 10. BOPE Test to 5000 psi. 11. Pick up and run drilling assembly. Drill out and perform FIT to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg. 12. Drill 6-1/8" horizontal section to well TD. (LWD: GR/RES/PWD) 13. Circulate the hole clean and POOH. 14. Run 3-%", 9.3 #, L-80 tubing with SSSV, gas lift mandrels, sliding sleeve, landing nipple and production packer. Land hanger. 15. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 16. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 17. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi I 30 mins. 18. Shear open sliding sleeve. Displace tubing and annulus to diesel keeping pressure on the system. 19. Set BPV and secure well. Move rig off. ORIGINAL Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-52 will be the closest well to CD2-53. Well separation is 9.0' @ 300' MD. Accounting for survey uncertainties, the ellipse-to-ellipse separation is 3.3' @ 300' MD. Orillina Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. j Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumpina Operations: Incidental fluids developed from drilling operations on well C02-53 will be injected into a permitted annulus on C02 pad or the class 2 disposal well on CD1 pad, The CD2-53 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. Upon completion of CD2-53 form 10-403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, 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. j Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2390') + 1,500 psi = 2,990 psi Pore Pressure = 1,081 psi Therefore Differential = 2991 ~ 1081 = 1910 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate 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 00 (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,41 0 ps i 4,599 psi 7,240 psi 6,154 psi a~WJf}ffliO '--- - 1 111- --' ...¡; ia. CD 2-53 Completion Diagram Updated OS/26/2004 16" Conductor to 114' Sperry Sun Directional v WPQ4 3-%" x 4-%" cross-over, 2 jts below 4-%Olanger ---- ...II III!!!! 3-1/2" Cameo TRM-4E SSSV Nipple (2.813" ID) at 1862' TVD=2400' MD -2.813" X-Over -Single W'xO.049" sls control line III ~~ 9-5/8" 36 ppf J-55 STC .. Surface Casing @ 3364' MD I 2390' TVD cemented to surface G'L' J Camco KBUG GLM (2.867" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 3-1/2" 9.3 ppf L-80 1ST Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope GL J Camco I<BUG GLM (2.867" ID) at 5700' TVD for E Dummy with 1" BK-2 Latch Camco KBUG GLM (2.867" ID) 2 joints above sliding sleeve E Dummy with 1" BK-2 Latch Packer Fluid mix: Diesel in tubinQ and annulus Completion .MQ TVD Tubing Hanger 32' 32' 4-%" 12.6 #/ft 1ST-Mod Tubing (2) Crossover 3-1/2", 9.3#/ft, 1ST-Mod Tubing Camco SAL-O SSSV Nipple 2400' 1862' 3-1/2", 9.3#/ft, 1ST-Mod Tubing Camco KSUG GLM (2.867" ID) 5206' 3400' 3-1/2", 9.3#/ft, 1ST-Mod Tubing Cameo KSUG GLM (2.867" ID) 9401' 5700' 3-1/2", 9.3#/ft, 1ST-Mod Tubing Camco KSUG GLM (2.867" ID) 11700' 6960' 3-1/2" tubing joints (2) Saker 3-1/2" CMPA sliding sleeve 11800' 7015' wI 2.81" X Profile 3-1/2" tubing joint (2) Baker SAB3 Packer 11900' 7065' with millout extension 3-1/2" tubing joints (1) HES "XN" (2.75" ID)-64.6º inc 11960' 7093' 3-1/2" 1 0' pup joint WEG 11972' 7098' Baker 3-%" CMPA sliding sleeve with 2.81"Q(CProfile set 2 joints above SAB3 packer Pinned for 2865 psi annular shear CW 2.81" X Profile Baker SAB 3 Packer at +1- 11900' MD Toe @ +1- 9812' MD 1 5926' TVD (500' MD above top of Nanuq/Albian 96 sand if present C) Well TO at 173231 MD I 72221 TVO ,/ 7" 26 ppf L-80 STC Mod Production Casing @ 12496' MD I 7232' TVD @ 85.5º aA~øENAL CD2-53 DRILLING FLUID PROGRAM Density PV YP Funnel Viscosity Initial Gels 10 minute gels API Filtrate H PHT Fluid Loss at 160 PH KCL Oil/water ratio SPUD to 9-5/8"surface casing point-12 ~" 8.8 - 9.6 ppg 20 - 60 100 - 200 Intermediate hole to 7" casing point - 8 Y2" Production Hole Section - 6 1/8" 8.5 -9,0 9.0 -10.0 8.1-8.8 ppg ,/ 10 -15 25-30 1 0-1 5 12-20 NA 12-14 cc/30 min 9.0-9.5 6% Approx. 80/20 9.6 - 9.~ 1 0 - 25 15 - 25 NC - 10 cc / 30 min 4-8 <18 4 - 12 cc/30 min (drilling) Surface Hole: A standard high viscosity fresh water 1 gel spud mud is recommended for the surface interval. Keep flowline viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel 1 polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section : The horizontal production interval will be drilled with a 80/20 oil/water ratio M-I Versa-Pro mineral oil based drill-in fluid. The base fluid will consist of high flash point (>200 F) mineral oil with 25% by weight calcium chloride as the internal phase. Calcium carbonate bridging material will be added to minimize formation damage. ORIGINAL ---- PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACe 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: 7" NIA Csg Setting Depth MDfTVD(ft) 114/114 3364/2390 12496/7232 17323 I 7222 Fracture Gradient (Ibs. I gal) 10.9 14.5 16.0 16.0 Pore pressure (psi) 52 1081 3272 '& \~ 3268 ./ ASP Drilling (psi) 53 1525 2549 NIA Casing Size (in) 16 9 5/8 . NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to minimum 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/gal 0.052 = Conversion from Ib./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP - (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) -'0.1] D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1081 - (0.1 x 2390) = 842 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D = [(14.5 x 0.052) ..... 0.1] x 2390 = 1563 psi OR ASP = FPP - (0.1 x D) = 3272 - (0.1 x 7232') = 2549 psi / 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3268 - (0.1 x 7222') = 2546 psi ORIGINA_ 95/8" Surface Casing run to 3364' MD 12390' TVD. Cement from 3364' MD to 2864' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2864' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1795' MD). Lead slurry: System: Tail slurry: System: (2864'-1795') X 0.3132 fe/ft X 1.5 (50% excess) = 502.2 fe below permafrost 1795' X 0.3132 fe/ft X 4 (300% excess) = 2248.8 fe above permafrost Total volume = 502.2 + 2248.8 = 2751.0 ft3 => 619 Sx @ 4.45 ft3/sk <::-- 619 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% SOOI accelerator, 50% D124 extender and 9% BWOWI D044 freeze suppressant 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fe => 230 Sx @ 1.17 felsk 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1 % S002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 12496' MD /7232' TVD Lead cement from 11770' MD to +1- 9812' MD (minimum 500' MD above top of Albian 96 Formation) with 11 PPG LiteCrete. Assume 30 % excess annular volume. Tail cement from 12496' MD to +1- 11770' MD (minimum 500' MD above top of Alpine C Formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Lead: System: Tail: System: (11770' -9812') X 0.1268 ft3/ft X 1.3 (30% excess) = 322,8 fe annular vol Total volume = 322.8 ft3 = 97 Sx @ 3,35 ft3/sk 97 Sx 11 ppg LiteCrete 0.4% D046 antifoamer, 1 % D065 dispersant, 0.01% B 155 retarder and 0.25% D 167 fluid loss additive @ 11 PPG yielding 3.35 ft3/sk .~ (12496' - 11770') X 0.1268 fe/ft X 1.4 (40% excess) = 128.9 fe annular vol. 80' X 0.2148 fe/ft = 17.2 ft3 shoe joint volume Total volume = 128.9 + 17.2 = 146.1 ft3 => 126 Sx @ 1.16 fe/sk -- 126 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant, 0.07% B 155 retarder and 0.4% D167 fluid loss additive @ 15.8 PPG yielding 1.15 fe/sk 1 By Weight Of mix Water, all other additives ar". ; 1~'f_..~tr1\rf{,ÅI ,'",' t3 ft t~ {S ~t~, '\J r\ L ------../ "-" ConocóPÍ1illips Co no coP hill ips Alaska Inc. Colville River Unit Alpine CD2 Plan: CD2-53 CD2-53 Plan: CD2-53 (wp04) Standard Planning Report 25 May, 2004 Sm........p....... '&!.. ..........\, Sm·......·..un···......·· ~~jjj::1 '"I .. ::If-CmI. ... o _0_ IOAuILmL"IN"G..u..mSEA'VI'''CuIiS .... _ ...... . m.. _ ........_..._.._____.. ......m.. A IlA,LLl8:W1'ON çOMP~ANY ORIGINAL ConocoPhillips Alaska Inc. ConocóPhillips Engineering Calculation Method: Error System: Scan Method: Error Surface: Waming Method: Alpine Minimum Curvature ISCWSA Elliptical Conic Rules Based Trav. Cylinder North Proiect: Colville River Unit Site: Alpine CO2 Well: Plan: CO2-53 Wellbore: CO2-53 Plan: CO2-53 (wp04) Approved Plan ~----------------- SHL (2()lJ.3' FNL & 149'::1'FEL; Se-c2-T11N-R4E) ./ I ¡ I .-------_. ...Begin Dir @ 3,00; 225.010'MD,225.010'TVD . "·-.-1 , I --- '-'- .____~ntinue Dir @ 4.00: 425.010'MD, 424.645' TVD -'--'--'--'¡-..--J ! End Dir, Start SaIl @ 56.754; 1697.870' MD, 1476.650' TVD I I I I -..- ~518" Csg Pt..Drill out 8-1f2" Hole: 3363.875'MD, 2390.000'TVD -~-_._--~ o -9000 I I I I , ~ -------------------r--~·-· f I I I I , I I I I , I I I I , , , I , ~ I I , I I , I , I f I I I I I I I I I I I I I , I , I , I I . I I _-..-' _ I I ¡ _"â I, ! 1;a-r =- - - - - - - - - - - - - - - - - - ï - - -,- - - - - - - - -1- - - - - - - - - . I I ! I I ! , ~ = = = = = = = = = = = = = = = = ì = F = = =¡= = = = =-~-.~~-~--î-~~-~-::-_-~-~·-~·~--·~·-f:··, 7" Csg Ptoo.Continue Dir @4.00: Begin 6-1/8" Hole: 12496.000' MD, ??~.465eTVD ": I I I: \://.--.-+.-..../ 1 I ¡ ¡: Target Heel: Begin GeoStær; 12614' MO, 7237,000' TVD,. (~137'FNL & 1479'FEL, Sec12-T11N-R4E) 'I: I .. I II I I 'I I I II I I II I I I, I I II I I 'I I ' II I I II I I II I I II I I II , 'I I I II -:- - - - - - - - - - - T - - - - T -; - - -:- - - - - - - - - - - - - - _~~-~.~~~-~f-~~-~-~-::---::·~-~-~~· I Target Too: Open Hole: 17323' MO, 77n.OOQ' TVD, (3943'FNL & 4004'FEL, Sec18- T11 N-~) ./ 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 ;rr;--, , I I I I I 'I ,I I -3000 -2000 -1000 0 1000 2000 3000 4000 5000 6000 Begin Dir @ 4.00; 11775.43O'MD,7001.449'TVD -1 000 -2000 -3000 -4000 ê ~ -5000 o o o 8 +' -6000 :c t::: o Z '; :c "S o (j') -7000 -8000 ~r:,.,\ \.~Çj ;¿:'6':J (r>j.CJ) _ Cp?:- Ç;\'<P" -10000 -11 000 -12000 unmn'_ 6 1/8" Open Hole -13000 I I I I I I I , I ! , I 7000 8000 9000 10000 West(-)/East(+) (2000 ft/in) SECTION DETAILS See MD Ine Azi TVD +NI-S +E1-W DLeg TFace \'See Target 1 36.100 0.000 0.000 36.100 0.000 0,000 0,00 0,000 0.000 2 225.000 0.000 0.000 225,000 0.000 0,000 0,00 0,000 0,000 3 425.000 6.000 160.000 424.635 -9.831 3,578 3,00 160.000 10.246 4 1697.865 56.754 147.216 1476,647 -556,273 336,758 4,00 -13,793 650.243 5 11775A20 56.754 147.216 7001.444 -7641.980 '1900,362 0,00 0,000 9076,783 6 12614.476 90.166 150.593 7237.000 -8321.987 5308,060 4,00 6,117 9869.581 CO2-53 (Heel) 7 17322.833 90.199 149,719 7222,QOO.12405,880 'i651 ,090 0,02 -87,82514575,494 CO2-53 (Toe) sparsr-a,::/-5un ffF'ffì:"¡:·TN(3"·:="$_J~j:fY.1 c'e~~ d RJGr¡~Å r A IL\LunCRlOX ("O\II'A"" ConocoPhillips Alaska Inc. Conoc;¡)hillips Engineering Alpine Project: Colville River Unit Site: Alpine CO2 Well: Plan: CO2-53 Well bore: CO2-53 Plan: CO2-53 (wp04) Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Suriace: Elliptical Conic W::Imina Methon: Rules R::Isen Approved Plan c :::c: - G1 - Z ):::- r- ] I I I SHL (2093' FNL & ' 499'FEL: Sec2-T11N-A4E) '1''' I I I ..... Begin Dir @ 3.00; 225.010'MD,225.010'lVD .. .. .....1. I I I Continue Dlr @ 4.00: 425.010'MD, 424.645' lVD I I I = 1477 650 '#.. .... End Dir, Start Sail @ 56.754; 1697.870' MD, 1476.650' TVD _ - - -1- - - - -1- - - - -1- - - I ..rtì.. .' . I I I I ê 2000-=- 2390 I I .# 9-5J8" Csg ~::~~~I~ .out 8-112" Hole: 3363.875'MD, 2390.000'TVD : =-~+C~3;--I---~t--h----ì71Ir I I I I ~ 3000 -' '. C-20 I :: : J:: I I I õ.. K-3 MARKER ì I I c3 ..1 I I I - 4000 .. ..·L· BASAL K-3 SS r5 .1' ~ MARKER I > BASE K-2 SEQUENCE ~ 5000 1 ~ ALBIAN 97 = A 0-=-= - - --=-=- - - _._i.. - - - - - - - - - - -ÐQ....- ...... .....-.... -------------- 1000 II 6000 I I I , ~ I ð I 0 I ~ .. ALBIAN;96 11:1 I 1/ 1 I I 6118·tnHo'ì ¡ 7000 =:d~~~~~z-J~--~J--~._--t-----.--b~~~:~;~;;::~L::'::)~7~7:;t;,;,.;,d,;~.......:,...~J;~.r~.!~;J~.:!~\.. / ].. .... .......1 ~ --.-.......-- -:- K-1 MARKER'- - -r-r -- - -:~ -- --r----r.o;o-.......r...-......r--.....~.T.~·~··':':·~l·":':·':':':~··;;::':-' .... ·I' ···· ..' ...···::t· , ..... I I Target _. Begin GOOst.er. 12614' MD 7237.000 1VD (5137'FNL & 147iFËC Sec1H11N·R4E) r I , ' I I I I.... .. I '. I I LCU I 'I ' I ' I 'I I Target Toe; Open Hole: 17323' MD, 7222.000' TVD, (3943'FNL & 4084'FEL, Sec1lH11N-R5E) <..-. '1',.,1, I I I I I I I I I I II I I I II I ( I I I I I I I I I I I I I I II 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 I I I I ( I I I ·'~1000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 I I I I Begin Dlr @ 4.00; 11775430'MD,7001.449'TVD I I 7" Csg Pt...Contlnue Dlr @ 4.00: Begin 6,"11800 Hole: 12496.000' MD, 7232.465' TVD u ¡¡¡- ~ II 1.1 o 11 II ..........( i-. 8000 SIËCTION· DETAILS $e(: MD Inc AzI TVD fN!~S +EI-W DLeg TRI~ VSec Target 136.100 0.000 0,000 36~1.00 0.000 0.000 0.00 0.000 0.000 2225,000 0.000 0:000 225;000 0.000 MOO 0;00 MOO O.( ()() 3 425;000 6.( ()()160.000 .424.635 -9.831 3;578 3.00160.000 10.246 4 1697.8()5 56.754147.216.1476.647 -556.273 '336.758 4;()O -13;m. 650;243 ~ 1177::'.0120:'6 7:.'>-1 1~7 ~16 700 1..w.t-764 1.980 01000.362 0.00 0.0009076.783 (.1261J J71) 9\) 166 1:'0 ::.93 7:137 0008321987 :)308 ODO 4.00 6.1179869;581 CO2-53 (Heel) 71732: 8..1:190 19':1IJ':I71~i 7~~ 0002JOS B80 76:;1091) 0.02 -87.8294575.494 CO2-53 (Toe) sper'r'Y-5un P..~ÎL.l..N~ Se.RVIc:eS A IL.\I.MIJI'IU·O.-': C:~I~II·.\.W Conoc~illips SPERRY_SUN HES Planning Report spei'i'y-sun CRIL-LING seRVIc:es A HALUB·URTO:'i C'O-MPA"'ì DatãbaSQ: CQrtìP~Hjy: Riôjeêt: Site¡ Well: Y'lè~lb9re: Dé~i9fl; EOM 2003,5 Single User Db ConocoPhillips Alaska Inc. (Alpine) Colville River Unit Alpine C02 Plan: C02-53 C02-53 C02-53 (wp04) Local Co--ordi.riáteRðfetence: TVDReference: MDReference': NófthReférerice: Survey· CalcUlation Method: Well Plan: C02-53 52' MSL @ 52.000ft (52' MSL) 52' MSL @ 52.000ft (52' MSL) v Colville River Unit, North Slope Alaska. United States Map System: Geo Datum: Map Zone: US State Plane 1927 (Exact solution) NAO 1927 (NAOCON CONUS) Alaska Zone 04 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Northing: Easting: Sloï Radius: ./ 5974641.660 usft Latitude: 371696.240usft ,/ Longitude: O.OOOin Grid Convergence: 700 20' 020" N 151002' 028" W -0.980 0 Well Position +N/-S +EI-W Position Uncertainty 0.000 ft 0.000 ft 0.000 ft Northing: Easting: Wellhead Elevation: 5974264,070 usft 371736.310 usft ft Latitude: Longitude: Ground Level: 70020' 016" N 151002' 026" W O.OOOft CO2-53 Magnetics Model Name $ampleDáte, Declination Oìp Äng Ie . Field Strength (0) (0) (nT) bggm2003 8/26/2002 24,736 80.592 57425 Design CO?-53(wp04) Audit Notes: Version: 2 Phase: PLAN Tie On Depth: VeftiCãISecfioh: +EJ-W (ft) 0,000 Plan Sections Measured Vertical Dogleg Build Turn Depth Incltnation Azimuth Depth +N/-S +EI-W Rate Rate Rate TFO (ft) (0) (oJ (ft) (ft) (ft) (0/100ft) (0/100ft) (0/100ft) (0) Target 36.100 0.000 0.000 36.100 0.000 0.000 0,00 0,00 0.00 0.000 225,000 0,000 0.000 225,000 0,000 0.000 0.00 0.00 0.00 0.000 425,000 6,000 160.000 424,635 -9,831 3.578 3.00 3.00 0.00 160.000 1697,865 56.754 147.216 1476.647 -556.273 336.758 4.00 3.99 -1,00 -13.793 11775.420 56.754 147,216 7001.444 -7641.980 4900.362 0.00 0,00 0.00 0.000 12614.476 90,166 150.593 7237.000 -8321.987 5308.060 4,00 3.98 0.40 6.117 C02-53 (Heel) ./ 17322.833 90.199 149.719 7222.000 "'-12405.880 7651.090 0.02 0,00 -0.02 -87.825 C02-53 (Toe) 5/25/2004 2:24:30PM Page 2 of 7 COMPASS 2003.5 QRI81'NAl¡ ConocJ'Phillips . SPERRY_SUN HES Planning Report .~ 5pe""""~-5un DRIL.LING SERVices A IlALUBl!RTON COMJ''''',' Database: Company: Project: Site: Wëll: Wellbore: Design: EOM 2003.5 Single User Db ConocoPhillips Alaska Inc. (Alpine) Colville River Unit Alpine C02 Plan: C02-53 C02-53 C02-53 (wp04) .LocatCC)-()t4ìnat~R~~rQÔciQ: .. TVO.·.Refetente: MDRefereoÇ9: NortttReferer1ç~:·..........··\\·../.......·.·....·.._. SUl'veYCalcÜlatIPQMittIiÞèI:· . Well Plan: C02-53 52' MSL @ 52.000ft (52' MSL) .··52' MSL @ 52.000ft (52' MSL) True Minimum Curvature Plêlnned:Survey Measured Depth (ft) Inclination (0) Azimuth (0) +Ef-W (ft) Vertical Section - (ft) Dogleg Rate (0/100ft) Build Rate (D/100ft) Turn Rate (°/1000) 36.100 0.000 0.000 36.100 0.000 0.000 0.000 0.00 0.00 0.00 SHL (2093' FNL & 1499'FEL; Sec2-T11N-R4E) 100.000 0.000 0.000 . 100.000 0.000 0.000 0.000 0.00 0.00 0.00 200.000 0.000 0.000 200.000 0.000 0.000 0.000 0.00 0.00 0.00 225.000 0,000 0.000 225.000 0.000 0.000 0.000 0.00 0.00 0.00 Begin Dlr @ 3.00; 225.010'MD,225.010'TVD or 300.000 2,250 160.000 299.981 -1 .384 0.504 1 .442 3.00 3.00 0.00 400.000 5.250 160.000 399.755 -7.529 2.740 7.847 3.00 3.00 0.00 425.000 6.000 160.000 424.635 -9.831 3.578 10.246 3.00 3.00 0.00 Continue Dlr @ 4.00: 425.010'MD, 424.645' TVD 500.000 8.942 155.396 498.990 -18.817 7.347 19.872 4.00 3.92 -6.14 600.000 12.906 152.525 597.159 -35.798 15.738 38.730 4.00 3.96 -2.87 700.000 16.887 150.990 693.780 -58.417 27.939 64.387 4.00 3.98 -1.54 800.000 20.875 150.028 788.380 -86.564 43.890 96.718 4.00 3.99 -0.96 900,000 24.867 149,363 880,500 -120.102 63.513 135.564 4.00 3.99 -0.66 1000.000 28,861 148.872 969,690 -158.867 86.713 180.738 4.00 3.99 -0.49 1100.000 32.856 148.492 1055.517 -202.671 113.377 232.018 4.00 4.00 -0.38 1200.000 36.852 148.186 1137,562 -251.300 143.374 289.154 4.00 4.00 -0.31 1300.000 40.849 147.932 .1215.425 -304.517 176.559 351.870 4.00 4.00 -0.25 1400,000 44.846 147.716 1288.727 -362.063 212.770 419.858 4.00 4.00 -0.22 1500.000 48,844 147.528 1357.110 -423.658 251.830 492.788 4.00 4.00 -0.19 1600,000 52.842 147,362 1420.243 -489.001 293.550 570.304 4.00 4.00 -0,17 1697.865 56.754 147.216 1476,647 -556.273 336.758 650.243 4.00 4.00 -0,15 End Dlr, Start Sail @ 56.754; 1697.870' MD,1476.650' TVD 1700.000 56.754 147.216 1477.817 -557.774 337.725 652.028 0.00 0.00 0.00 1800.000 56.754 147.216 1532.640 -628.086 383.009 735,645 0.00 0.00 0.00 1900.000 56.754 147.216 1587.463 -698.397 428.294 819.262 0.00 0.00 0.00 2000.000 56.754 147.216 1642.286 -768,709 473.579 902.879 0.00 0.00 0.00 2100.000 56.754 147.216 1697.108 -839.021 518.864 986.496 0.00 0.00 0.00 2200.000 56.754 147.216 1751.931 -909,333 564.149 1070.113 0.00 0.00 0.00 2300.000 56,754 147.216 1806.754 -979.644 609.434 1153,730 0.00 0.00 0.00 2400.000 56.754 147.216 1861.577 -1049.956 654.718 1237.347 0.00 0.00 0.00 2500.000 56.754 147.216 1916.400 -1120,268 700.003 1320,964 0.00 0.00 0.00 2600.000 56,754 147.216 1971.222 -1190.580 745.288 1404.581 0.00 0.00 0.00 2700.000 56.754 147.216 2026.045 -1260.892 790.573 1488.197 0.00 0.00 0.00 2800,000 56,754 147.216 2080.868 -1331,203 835.858 1571.814 0.00 0.00 0.00 2900.000 56.754 147.216 2135.691 -1401.515 881 .143 1655.431 0,00 0.00 0.00 3000.000 56.754 147.216 2190,514 -1471,827 926.427 1739.048 0,00 0.00 0.00 3100.000 56.754 147.216 2245,336 -1542.139 971.712 1822.665 0.00 0.00 0.00 3200.000 56,754 147.216 2300.159 -1612.450 1016.997 1906.282 0.00 0.00 0.00 3300,000 56,754 147.216 2354.982 -1682.762 1062.282 1989.899 0.00 0.00 0.00 3363.875 56.754 147.216 '2390,000 -1727.674 1091.208 2043,309 0.00 0.00 0,00 9-5/8" Csg Pt...Drill out 8-112" Hole: 3363.875'MD, 2390.000'TVD - 95/8" csgPt@3364'MD 3396.708 56.754 147.216 2408.000 -1750.759 1106.076 2070.763 0.00 0.00 0.00 C-30 3400.000 56,754 147.216 2409.805 -1753.074 1107.567 2073.516 0.00 0.00 0,00 3500.000 56.754 147.216 2464.628 -1823.386 1152.852 2157.133 0.00 0.00 0.00 3600.000 56.754 147.216 2519.450 -1893.698 1198.136 2240.750 0.00 0.00 0.00 3700.000 56.754 147.216 2574.273 -1964.009 1243.421 2324.367 0.00 0.00 0.00 3800.000 56.754 147.216 2629.096 -2034.321 1288.706 2407.983 0.00 0.00 0.00 5/2512004 2:24:30PM Page 3 of 7 COMPASS 2003.5 ORIGINAL ~ SPERRY - SUN HES SpSi'i'y-sun ConocoPhillips Planning Report DRIL-L..ING SERVll:eS A HALLlBL-'RT().:'i COMP"-'''Y Database: EOM 2003.5 Single User Db Local..Oo-ord{hatø'Refcnencø: Well Plan: CO2-53 Compªhy: ConocoPhillips Alaska Inc. (Alpine) TVDReferencè: 52' MSL @ 52.000ft (52' MSL) Prgjøct: Colville River Unit MD Reference; 52' MSL @ 52,OOOft (52' MSL) S11e: Alpine CO2 N:orth· Reference: True Well: Plan: CO2-53 SUf'\I6yOalculatlonMetnod; Minimum Curvature Wêllbol'e: CO2-53 De$igrÚ C02-53 (wp04) 3900,000 56.754 147,216 2683,919 -2104,633 1333.991 2491.600 0,00 0,00 0,00 4000,000 56.754 147.216 2738.741 -2174.945 1379,276 2575,217 0.00 0,00 0,00 4077,082 56.754 147,216 2781,000 -2229,143 1414.182 2639.671 0.00 0,00 0.00 0-20 4100,000 56.754 147,216 2793,564 -2245.256 1424,561 2658.834 0,00 0.00 0,00 4200,000 56,754 147.216 2848.387 -2315,568 1469.845 2742.451 0,00 0,00 0.00 4300,000 56.754 147,216 2903,210 -2385.880 1515,130 2826,068 0,00 0,00 0,00 4400.000 56,754 147,216 2958,033 -2456,192 1560.415 2909.685 0,00 0,00 0.00 4500,000 56,754 147,216 3012,855 -2526,504 1605,700 2993.302 0.00 0,00 0,00 4600,000 56.754 147.216 3067,678 -2596.815 1650,985 3076,919 0,00 0,00 0.00 4700,000 56.754 147,216 3122,501 -2667.127 1696,270 3160,536 0.00 0.00 0,00 4800,000 56.754 147,216 3177,324 -2737.439 1741.554 3244.153 0,00 0,00 0,00 4900,000 56.754 147,216 3232.147 -2807.751 1786.839 3327,769 0,00 0.00 0.00 5000,000 56.754 147.216 3286,969 -2878.062 1832,124 3411.386 0,00 0.00 0,00 5100,000 56.754 147.216 3341,792 -2948.374 1877 .409 3495.003 0,00 0,00 0.00 5200.000 56,754 147.216 3396,615 -3018.686 1922.694 3578.620 0,00 0.00 0.00 5300.000 56,754 147,216 3451.438 -3088.998 1967,979 3662,237 0,00 0.00 0.00 5400.000 56,754 147,216 3506,261 -3159.309 2013,263 3745,854 0,00 0.00 0.00 5500,000 56.754 147,216 3561,083 -3229.621 2058.548 3829.471 0.00 0.00 0.00 5600,000 56.754 147,216 3615,906 -3299.933 2103,833 3913,088 0.00 0,00 0.00 5700,000 56.754 147,216 3670.729 -3370,245 2149,118 3996,705 0.00 0,00 0.00 5800.000 56.754 147,216 3725,552 -3440,557 2194.403 4080.322 0.00 0.00 0,00 5900,000 56.754 147.216 3780.374 -3510,868 2239.688 4163.939 0.00 0.00 0.00 6000,000 56.754 147.216 3835.197 -3581,180 2284,972 4247.555 0.00 0.00 0.00 6025.177 56.754 147,216 3849.000 -3598,883 2296,374 4268.608 0,00 0.00 0.00 K-3 MARKER 6100.000 56.754 147.216 3890,020 -3651.492 2330.257 4331,172 0.00 0.00 0,00 6200.000 56,754 147.216 3944.843 -3721.804 2375.542 4414,789 0.00 0.00 0,00 6300.000 56.754 147.216 3999,666 -3792.115 2420.827 4498.406 0.00 0.00 0.00 6382.693 56.754 147,216 4045,000 -3850,258 2458.274 4567,551 0.00 0.00 0.00 BASAL K-3 SS 6400,000 56.754 147,216 4054.488 -3862.427 2466,112 4582.023 0,00 0,00 0.00 6431,942 56.754 147.216 4072,000 -3884,886 2480.577 4608.732 0.00 0.00 0.00 K-2 MARKER 6500.000 56.754 147,216 4109,311 -3932,739 2511.397 4665,640 0.00 0.00 0.00 6600,000 56.754 147.216 4164.134 -4003.051 2556.681 4749.257 0.00 0.00 0,00 6621.644 56.754 147,216 4176,000 -4018.269 2566.483 4767,355 0.00 0,00 0,00 BASE K-2 SEQUENCE 6700,000 56.754 147.216 4218.957 -4073.363 2601,966 4832.874 0.00 0.00 0,00 6800.000 56.754 147.216 4273,780 -4143,674 2647,251 4916.491 0,00 0.00 0,00 6900.000 56.754 147.216 4328,602 -4213.986 2692.536 5000,108 0,00 0.00 0.00 7000,000 56.754 147.216 4383.425 -4284,298 2737.821 5083,725 0.00 0.00 0,00 7100,000 56.754 147.216 4438,248 -4354,61 ° 2783.106 5167.341 0.00 0.00 0.00 7200.000 56,754 147.216 4493.071 -4424.921 2828.390 5250.958 0,00 0.00 0,00 7300.000 56.754 147.216 4547.894 -4495.233 2873,675 5334.575 0.00 0.00 0.00 7400.000 56.754 147.216 4602.716 -4565.545 2918,960 5418.192 0.00 0.00 0,00 7500.000 56.754 147.216 4657.539 -4635.857 2964,245 5501.809 0.00 0.00 0,00 7600.000 56.754 147.216 4712,362 -4706,168 3009,530 5585.426 0.00 0.00 0.00 7700.000 56.754 147.216 4767,185 -4776.480 3054.815 5669.043 0.00 0,00 0,00 7800.000 56.754 147.216 4822,007 -4846,792 3100.099 5752.660 0.00 0.00 0.00 7900.000 56.754 147.216 4876.830 -4917.104 3145.384 5836.277 0.00 0.00 0.00 8000.000 56.754 147,216 4931,653 -4987.416 3190.669 5919.894 0,00 0.00 0.00 8100,000 56.754 147.216 4986.476 -5057.727 3235,954 6003.511 0.00 0,00 0.00 8200,000 56.754 147.216 5041.299 -5128,039 3281.239 6087.127 0.00 0.00 0.00 8300,000 56.754 147.216 5096.121 -5198.351 3326.524 6170.744 0.00 0.00 0.00 8400,000 56.754 147.216 5150.944 -5268.663 3371,808 6254.361 0.00 0.00 0,00 8500.000 56.754 147.216 5205.767 -5338.974 3417,093 6337.978 0.00 0.00 0.00 8600,000 56.754 147.216 5260.590 -5409.286 3462,378 6421 .595 0,00 0.00 0,00 5/25/2004 2:24:30PM Page 4 of 7 COMPASS 2003.5 O'R f Gl N1(l~~ ConocJP't,illips - SPERRY_SUN HES .~ 5pE!~""V-5Un Planning Report DRILLING seRVIc:es A HALUBURro.~ COMP.\.'\Y Database: EOM 2003.5 Single User Db Local Co..ordìnateRefØrence: Well Plan: CO2-53 Company: ConocoPhillips Alaska Inc. (Alpine) TVD Reference: 52' MSL @ 52.0000 (52' MSL) Project: Colville River Unit MDReferef1ce: ..... 52' MSL @ 52.000ft (52' MSL) Site: Alpine CO2 NorthReference:··· ... ............. . True Well: Plan: CO2-53 Sul"\ley.CálcülåtïorrMê~hºd;.··..·. Minimum Curvature Wellbore: CO2-53 Design: C02-53 (wp04) 8700.000 56.754 147.216 5315.413 -5479.598 3507.663 6505.212 0.00 0.00 0.00 8800.000 56.754 147.216 5370.235 -5549.910 3552.948 6588.829 0.00 0.00 0.00 8900.000 56.754 147.216 5425.058 -5620.222 3598.233 6672 .446 0.00 0.00 0.00 9000.000 56.754 147.216 5479.881 -5690.533 3643.517 6756.063 0.00 0.00 0.00 9100.000 56.754 147.216 5534.704 -5760.845 3688.802 6839.680 0.00 0.00 0.00 9200.000 56.754 147,216 5589.527 -5831.157 3734.087 6923.296 0.00 0.00 0.00 9300.000 56.754 147.216 5644.349 -5901.469 3779.372 7006.913 0.00 0.00 0.00 9400.000 56.754 147.216 5699.172 -5971.780 3824.657 7090.530 0.00 0.00 0.00 9441.640 56.754 147.216 5722.000 -6001.058 3843.513 7125.348 0.00 0.00 0.00 ALBIAN 97 9500.000 56.754 147.216 5753.995 -6042.092 3869.942 7174.147 0.00 0.00 0.00 9600.000 56.754 147.216 5808.818 -6112.404 3915.226 7257.764 0.00 0.00 0.00 9700.000 56.754 147.216 5863.640 -6182.716 3960.511 7341.381 0.00 0.00 0.00 9800.000 56.754 147.216 5918.463 -6253.028 4005.796 7424.998 0.00 0.00 0.00 9900.000 56.754 147.216 5973.286 -6323.339 4051.081 7508.615 0.00 0.00 0.00 10000.000 56.754 147.216 6028.109 -6393.651 4096.366 7592.232 0.00 0.00 0.00 10100.000 56,754 147.216 6082.932 -6463.963 4141.651 7675.849 0.00 0.00 0.00 10200.000 56.754 147.216 6137.754 -6534.275 4186.935 7759.466 0.00 0.00 0.00 10300.0 0 .754 147.216 6192.577 -6604.586 4232.220 7843.082 0.00 0.00 0.00 .716 56. 54 147.216 6199.000 -6612.824 4237.526 7852.879 0.00 0.00 0.00 ALBIAN 96 10400.000 56 54 147.216 6247.400 -6674.898 4277 .505 7926.699 0.00 0.00 0.00 10500.000 .754 147.216 6302.223 -6745.210 4322.790 8010.316 0.00 0.00 0.00 0.000 56.754 147.216 6357.046 -6815.522 4368.075 8093.933 0.00 0.00 0.00 10700.000 56.754 147.216 6411.868 -6885.833 4413.360 8177.550 0.00 0.00 0.00 10800.000 56.754 147.216 6466.691 -6956.145 4458.645 8261.167 0.00 0.00 0.00 10900.000 56.754 147.216 6521.514 -7026.457 4503.929 8344.784 0.00 0.00 0.00 11000.000 56.754 147.216 6576.337 -7096.769 4549.214 8428.401 0.00 0.00 0.00 11100.000 56.754 147.216 6631.160 -7167.081 4594.499 8512.018 0.00 0.00 0.00 11200.000 56.754 147.216 6685.982 -7237.392 4639.784 8595.635 0.00 0,00 0.00 11293.059 56.754 147.216 6737.000 -7302.824 4681.926 8673.448 0.00 0.00 0.00 TOP HRZ 11300.000 56.754 147.216 6740.805 -7307.704 4685.069 8679.252 0.00 0.00 0.00 11400.000 56.754 147.216 6795.628 -7378.016 4730.354 8762.868 0.00 0.00 0.00 11500.000 56.754 147.216 - 6850.451 -7448.328 4775.638 8846.485 0.00 0.00 0.00 11600.000 56.754 147.216 6905.273 -7518.639 4820.923 8930.102 0.00 0.00 0.00 11603.149 56.754 147.216 6907.000 -7520.854 4822.349 8932.736 0.00 0.00 0.00 BASE HRZ 11687.056 56.754 147.216 6953.000 -7579.850 4860.346 9002.896 0.00 0.00 0.00 K-1 MARKER 11700.000 56.754 147.216 6960.096 -7588.951 4866.208 9013.719 0.00 0.00 0.00 11754.546 56,754 147.216 6990.000 -7627.304 4890.909 9059.329 0.00 0.00 0.00 TOP KUPARUK 11775.420 56.754 147.216 7001.444 -7641.980 4900.362 9076.783 0.00 0.00 0.00 Begin Dlr @ 4.00; 11775.430'MD,7001.44.9'TVD 11800.000 57.732 147,340 7014.743 -7659,371 4911.536 9097.450 4.00 3.98 0.50 11830.981 58,965 147.492 7031.000 -7681.592 4925.738 9123.819 4.00 3.98 0.49 LCU 11900.000 61.711 147,818 7065.154 -7732.258 4957,820 9183.784 4.00 3.98 0.47 12000,000 65.691 148,262 7109.451 -7808.306 5005,258 9273.414 4.00 3.98 0.44 12100,000 69.672 148.679 7147.418 -7887.144 5053.621 9365.903 4.00 3.98 0.42 12116.318 70.322 148.745 7153.000 -7900.248 5061.584 9381.236 4.00 3.98 0.40 MILUVEACH A 12179,627 72,843 148.996 7173.000 -7951.661 5092.634 9441.295 4.00 3.98 0.40 ALPINE D 12200.000 73.655 149.075 7178.872 -7968.389 5102.671 9460.802 4.00 3.98 0.39 12270.299 76.455 149.343 7197.000 -8026.731 5137.436 9528.709 4.00 3.98 0.38 ALPINE C 5/25/2004 2:24:30PM Page 5 of 7 COMPASS 2003.5 ORIGINAL ConocJPhillips SPERRY_SUN HES Planning Report 5pE!I'""'~Y-5un DRIL.L.ING seRVIC:~S A HALUBlJR1"'Q.:'i C'O-!'&'A..··Ù- Database: C()rt1~'at1y: FIr-pipet: Site: Welt: Well bore: Dê$igrÙ EDM 2003,5 Single User Db ConocoPhillips Alaska Inc. (Alpine) Colville River Unit Alpine CD2 Plan: CD2-53 CD2-53 CD2-53 (wp04) L.ocalCo-ordi nateReference: TVO ReferèhCè: MOReference: North Reference: S urveyCalcülatiol'lMethod: Well Plan: CD2-53 52' MSL @ 52.000ft (52' MSL) 52' MSL @ 52.000ft (52' MSL) True Minimum Curvature 12300,000 77.638 149.455 7203.658 -8051,644 5152,170 9557,648 4,00 3.98 0,38 12400.000 81.621 149.823 7221.656 -8136,504 5201,877 9655,969 4,00 3.98 0,37 12496.000 85.446 150,170 7232.465 -8219,096 5249,567 9751,300 4.00 3.98 0.36 7" Csg Pt...Continue Dir @ 4.00: Begin 6-118" Hole: 12496.000' MD, 7232.465' TVD -7" Csg Pt @ 12496'MO 12500,000 85,605 150,184 7232.777 -8222,555 5251,550 9755.286 4,00 3,98 0.36 12600.000 89.589 150.542 7236,969 -8309,379 5300,947 9855,115 4,00 3.98 0.36 12614.476 90,166 150,593 7237,000 -8321,987 5308,060 9869,581 4.00 3,98 0.36 Target Heel: Begin GeoSteer; 12614' MD, 7237.000' TVD, (5137'FNL & 1479'FEL, Sec12-T11N-R4E) - C02-53 (Heel) 12700,000 90,167 150,577 7236,752 -8396.485 5350,063 9955.038 0,02 0,00 -0.02 12800.000 90,167 150,559 7236.461 -8483.579 5399,202 10054.962 0.02 0,00 -0.02 12900,000 90.168 150.540 7236,168 -8570.656 5448,369 10154,887 0,02 0,00 -0.02 13000.000 90.169 150.522 7235,874 -8657,718 5497.564 10254,813 0,02 0.00 -0.02 13100.000 90,169 150.5037235,579 -8744,764 5546,788 10354,741 0.02 0,00 -0.02 13200,000 90,170 150.484 7235,283 -8831,794 5596.03910454.669 0,02 0.00 -0.02 13300.000 90.171 150.466 7234,986 -8918,808 5645,319 10554,599 0.02 0,00 -0.02 13400,000 90,171 150.447 7234,687 -9005,805 5694,627 10654.530 0,02 0.00 -0,02 13500,000 90,172 150.429 7234.387 -9092,787 5743.963 10754.463 0.02 0,00 -0.02 13600.000 90.173 150.410 7234,086 -9179.753 5793.328 10854.396 0,02 0,00 -0,02 13700,000 90.174 150,392 7233,784 -9266,703 5842,721 10954.331 0.02 0,00 -0,02 13800.000 90,174 150,373 7233.480 -9353.637 5892,141 11054.267 0,02 0,00 -0.02 13900.000 90.175 150.354 7233.175 -9440.555 5941,590 11154.203 0,02 0.00 -0.02 14000.000 90.176 150.336 7232,869 -9527.456 5991,06711254.142 0,02 0.00 -0.02 14100,000 90,176 150,317 7232,562 -9614.342 6040,573 11354,081 0.02 0,00 -0.02 14200.000 90.177 150.299 7232.253 -9701.212 6090,106 11454,021 0,02 0,00 -0.02 14300,000 90.178 150.280 7231.944 -9788.066 6139,668 11553.963 0.02 0,00 -0.02 14400.000 90.179 150,262 7231,633 -9874.903 6189,257 11653.905 0.02 0.00 -0.02 14500,000 90.179 150,243 7231,320 -9961.725 6238,875 11753.849 0.02 0,00 -0.02 14600,000 90.180 150,224 7231,007 -10048,530 6288,521 11853.793 0.02 0,00 -0,02 14700.000 90,181 150,206 7230,692 -10135,319 6338,195 11953.739 0.02 0,00 -0.02 14800,000 90,181 150,187 7230.376 -10222.093 6387,898 12053.686 0.02 0,00 -0.02 14900.000 90.182 150.169 7230,059 -10308,850 6437,628 12153.634 0,02 0.00 -0.02 15000.000 90,183 150.150 7229,741 -10395.591 6487,386 12253.583 0,02 0,00 -0.02 15100,000 90.183 150,132 7229.421 -10482,315 6537,173 12353.533 0,02 0,00 -0.02 15200,000 90.184 150.113 7229,101 -10569,024 6586,988 12453.484 0.02 0,00 -0,02 15300.000 90.185 150.095 7228.779 -10655,717 6636,830 12553.435 0.02 0,00 -0.02 15400,000 90.186 150.076 7228.455 -10742.393 6686,701 12653,388 0.02 0.00 -0.02 15500,000 90.186 150.057 7228.131 -10829,053 6736,600 12753.342 0.02 0,00 -0.02 15600,000 90,187 150.039 7227.805 -10915.697 6786,527 12853,297 0,02 0.00 -0.02 15700,000 90.188 150.020 7227.478 -11002,325 6836.482 12953.253 0.02 0.00 -0.02 15800,000 90.188 150.002 7227.150 -11088.937 6886.465 13053,210 0.02 0.00 -0.02 15900,000 90,189 149.983 7226,820 -11175.532 6936.477 13153,167 0.02 0,00 -0.02 16000,000 90.190 149.965 7226.490 -11262,111 6986,516 13253,126 0.02 0.00 -0.02 16100.000 90.191 149.946 7226.158 -11348,674 7036,583 13353,086 0.02 0,00 -0.02 16200.000 90.191 149.927 7225.825 -11435.221 7086,678 13453.046 0,02 0,00 -0.02 16300,000 90.192 149,909 7225.490 -11521,752 7136.802 13553.007 0.02 0,00 -0.02 16400.000 90.193 149,890 7225,155 -11608.266 7186,953 13652,970 0.02 0.00 -0.02 16500,000 90,193 149.872 7224.818 -11694.764 7237.133 13752,933 0,02 0.00 -0.02 16600,000 90.194 149,853 7224.480 -11781.246 7287.340 13852.897 0.02 0.00 -0.02 16700,000 90.195 149.835 7224.141 -11867.711 7337.576 13952.861 0.02 0.00 -0.02 16800,000 90.195 149.816 7223.800 -11954.160 7387,839 14052.827 0.02 0.00 -0.02 16900.000 90.196 149.797 7223.459 -12040,593 7438,131 14152.794 0.02 0.00 -0.02 17000.000 90.197 149.779 7223.116 -12127.010 7488.451 14252,761 0.02 0.00 -0.02 17100,000 90.198 149.760 7222.771 -12213.410 7538,798 14352.729 0.02 0.00 -0.02 17200.000 90.198 149.742 7222.426 -12299,794 7589,174 14452.698 0.02 0.00 -0.02 17300.000 90.199 149.723 7222.079 -12386.162 7639.577 14552,668 0.02 0.00 -0.02 17322,833 90.199 149,719 7222.000 -12405,880 7651.090 14575.494 0.02 0,00 -0.02 Target Toe; Open Hole: 17323' MD, 7222.000' TVD, (3943'FNL & 4084'FEL, Sec18- T11 N-RSE) . 6 1/8" Open Hole - CD2-S~ 5/2512004 2:24:30PM Page 6 of 7 COMPASS 2003.5 OR I' Rl ~rì{t'_ ~"~' : " ~ "'="" , , '." . =~ Conoc~illips Database: Company: Project: Site: Wèll: Wellbore: Design: Targets TargetName C02-53 (Heel) C02-53 (Toe) Casing. Points ~ SPERRY_SUN HES Planning Report EOM 2003.5 Single User Ob ConocoPhillips Alaska Inc. (Alpine) Colville River Unit Alpine C02 Plan: C02-53 C02-53 CD2-53 (wp04) Shape Rectangle Point Local Co-ordinate Reference: lVD Reference: MD Reference: North Reference: Survey Calculation Method: Northing ( usft) 5965853.206 5961730.176 7237.000 7222.000 .~ spa"'''''Y-5un DRIL.L.ING seRVices A HALLIBURTOt.~ COMP..\.:'\"Y Well Plan: C02-53 52' MSL @ 52.0000 (52' MSL) 52' MSL @ 52.000ft (52' MSL) True Minimum Curvature Name +N/-S ft -8321.987 -12405.880 +E1-W ft 5308.060 7651.090 Created Updated 2/23/2004 5/25/2004 2/2312004 5/18/2004 Easting (usft) 376900.814 379173.456 FórÎnatlons M.8¡îsured Depth (ft)..· 3396.708 4077 .082 6025.177 6382.693 6431.942 6621 .644 9441.640 10311.716 11293.059 11603.149 11687.056 11754.546 11830.981 12116.318 12179.627 12270.299 P~ånÄnri()tätions¡ . Me~sured Depth (ft) 36.110 225.010 425,01 ° 1697.870 3363.875 11775.430 12496,000 12614.480 17322.800 5/25/2004 2:24:30PM 2390.005 9 5/8" Csg Pt @ 3364'MO 7232.465 7" Csg Pt @ 12496'MO 7222.000 61/8" Open Hole Vertical Oep~h (ft) 2408.000 2781,000 3849.000 4045.000 4072.000 4176.000 5722.000 6199.000 6737.000 6907.000 6953.000 6990.000 7031.000 7153.000 7173,000 7197,000 7267,000 Vertical Depth 1ft) 36.110 225,010 424,645 1476.650 2390,000 7001.449 7232.465 7237.000 7222.000 Name C-30 C-20 K-3 MARKER BASAL K-3 SS K-2 MARKER BASE K-2 SEQUENCE ALBIAN 97 ALBIAN 96 TOP HRZ BASE HRZ K-1 MARKER TOP KUPARUK LCU MILUVEACH A ALPINE D ALPINE C BASE ALPINE Casing Diameter (in) 9.625 7,000 6.125 Hole Diameter (in) 12.250 8.500 6.125 Comment Lithology Dip . Direction CO) Dip (0) 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Local Coordinates 'tN/~S +EI-W (ft) (ft) 0.000 0.000 0.000 0,000 -9,832 3.579 -556.276 336.760 -1727,674 1091.208 -7641.987 4900.366 -8219.096 5249,567 -8321,990 5308.062 -12405,851 7651,073 SHL (2093' FNL & 1499'FEL; Sec2-T11N-R4E) Begin Oir @ 3.00; 225.01 O'MO,225.01 O'WO Continue Oir @ 4.00: 425.010'MO, 424.645' WO End Oir, Start Sail @ 56.754; 1697.870' MO, 1476.650' TVO 9-5/8" Csg PL.Orill out 8-112" Hole: 3363.875'MO, 2390.000'TVO Begin Oir @ 4.00; 11775.430'MO,7001.449'WO . 7" Csg PL.Continue Oir @ 4.00: Begin 6-1/8" Hole: 12496.000' MO, 72 ! Target Heel: Begin GeoSteer; 12614' MO, 7237,000' TVO, (5137'FNL 8/' Target Toe; Open Hole: 17323' MO, 7222.000' TVO, (3943'FNL & 4084 Page 7 of 7 ORIGINAL COMPASS 2003.5 CD2-S-.1(wp04) Approved Plan 18~2-55 (CD2-55) Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [10ft/in] Colour 50v 750 1000 1250 1500 1750 2000 2500 3~.. jm 4 - 4000 45 - 4500 5000 - 5000 5500 5500 6500 6500 7500 7500 8500 8500 9500 l-..- 9500 10000 __ 10000 \()5()O w, 10500 11 000 9()' 11000 12()OO _ 12000 13000 13000 19 __ 19000 --'" :r ') 120 u.u:..---/ A Tr \,fD Scanned from Surface to TD 36.10 Orir,in +NI·$ 0.00 Rig: Ref. [)atum.: V.Socbon An~1c 148,336" COMPANY DETAILS ConocoPhilips AJ.sb Int.:, EJI¡:inæring ~inc C.leul,";.n Mclhod: Minimum Cwv._ ~r= If';;V¿y~cr North w=:=.~: ~1ic~J",ing 0,00 ~~~;fvr, :g;-~ WELLP A TH D£'fAlls C02·53 Doyon 19 52' MSL 52,001I Travelling CyJinder Azimuth (TPO+AZI) [deg] vs Centre to Centre Separation [fl] -20.0 -'20.7 SECTION DETAILS TVD +N/-S +r:J-w Dug TF""e VSec Turgct :,6,10 0,00 0,00 0,00 0.000 0.00 225.00 0.00 0.00 0.00 0.000 0.00 424,63 -9,83 3,58 3,00 160,000 10.25 1476.65 -556.39 336.60 4.00 -13.771 650,26 7(x) 1.74 - 7644,35 4898,12 O,(X) 0.000 9077. 63 7237,(X) ·8321.94 5308.10 4.00 5,281 9869,56 CD2-53 (Bcd) 7222.00 -12405.81 7651.15 0,00 18,928 14575,47 CD2-53 (Toc) MD Inc ..,;- V') N C) u § e;. ..,;- ''( ë g ¡;:; Sc<' %.10 0.000 0,000 225.00 0.000 0.000 425.00 6.000 160.000 1697,88 56.755 147,236 11776,24 56,755 147.236 12614,31 90.166 150150 17322,61 90,19<) 150.161 Azj -15.0 ) r '-~~ / /{ -~~~ // ß// 96 ______~ 150 1})( 100 -10.0 Plan: CD2-54 (P an: CD2-54) -5.0 -0 90 From Colour ToMD 36 - 300 300 - 400 400 500 500 - 750 750 - \000 1000 - 1250 1250 1500 1500 - 1750 1750 - 2000 2000 2500 2500 - 3000 3000 - 3500 3500 - 4000 4000 - 4500 4500 - 5000 5000 - 5500 -'20.7 5500 - 6500 -20.0 6500 - 7500 7500 - 8500 8500 9500 ggoo - 10000 100 - 10500 -15.0 11000 12000 13000 14000 15000 16000 -10,0 17000 18000 19000 20000 -5.0 C}.. ~"\) 1>.'\ ,(,'0 ' ~<)ì \)~ c\')'),' c.))'1: ,~'\)'Q.~ - ~<) 1:. (,'0'), /,,'\)'1: ~'\) ~ v (,'\)'1: . CD2-45 (CD2-45) CD2-51<!f>9.&~W ~ (CD2_52) o CD2-43 (CD2-43PB \) CYt)~~~C(~1)~?24 ) eD2-4'2> (C.1)2-4ß) (\)2.46 «D'1_46) Tool CB-GYRO-SS MWD+IFR-AK-CAZ-SC Depth Fm Depd1 To Survey/Plan 36,10 1220.00 Planned: CD2-53 (wp04) V21 1220.00 17322.61 Planned: CD2-53 (wp04) V21 SURVEYPROORAM ANTI-COLLISION SErnNGS Inlerpolillion Melhod:MD Interval: 25.00 Depth Range From: 36.10 To: 17322.61 Maximum Ronge; 1928.65 RefeI'Cnce: Plan: CD2-53 (wp04) NUld u.r, .I("'_~:~ ~9742tiA.07(1 J717::~",;\IO ..¡.N/-S -.H6.!UI UIÆ1...lc 70"2(1'1 f..51 tiN 151 "02"26, 724W UH.gfudc S~I« .. :J.\V WJ;.1.l.1)1~.T¡\Jl,."" I 2 ., 4 5 (, 7 --96 -100 -72 -, '-48 :¡ ---4~ ,;:, S I';) U "'I O~,q 00 U lion ~ , ''1 ;;::) "'I ''1 . ..aog ~ ~, --.......... ,:', C~···'o'Ì.-.: __ '-..1:::rJ4~ ~2 ~:. 2 :Þ~:~ '-' . '."~<;?:' r,.: ~"- r-"~I. ~, ..:.../i ,::;", -,': "-'72 -100 ---96 N.mc P"'l CL>2~.5.~ ·'rlalliburton Sperry-Sun\'-" Anticollision Report Sper"I""'Y-SLJn Q1!!J"J,.IN_~ "fU'''_~ -\ M-uu...."n- n-.~.....'\ Company: ConocoPhillips Alaska Inc. ' Field: Colville River Unit Reference Site: Alpine C02 Reference Well: Plan: C02-53 Reference Wellpath: C02-53 GLOBAL SCAN APPLIED: All well paths within 200'+ 100/1000 of reference Interpolation Method: MO Interval: 50,00 ft Depth Range: 36.10 to 17322.61 ft Maximum Radius: 1928.65 ft Date: 5/25/2004 Time: ·13:59:44 Page: 1 Co-ol'dilUlte(N.E).Ref¢rence: Vel'tical(TVD)Reference: Well:PIélr1:C02-53,·TrueNorth 52'MSl..S2.0 .. Reference: Error Model: Scan Method: Error Surface: Db: Oracle Plan: C02-53 (wp04) & NOT PLANNED P~:)GR. ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Casing Points MD TVD Diameter Hole Size Nanie ft ft in in 3363.93 2390.00 9.625 12.250 9 5/8· @ 3364' MO 12496.00 7232.47 7.000 8.500 7" @ 12496'MO 17322.61 7222.00 6.125 6.125 6 1/8" Open Hole Plan: C02-53 (wp04) Date Composed: 5/25/2004 Version: 21 Principal: Yes Tied-to: From Well Ref. Point Sununary <-------------------- Offset \Vellpath ---------------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Alpine CO2 C02-27 C02-27 V6 334.79 350.00 256.61 6.34 250.28 Pass: Major Risk Alpine CO2 C02-30 C02·30 V8 246.71 250.00 230.22 4.35 225.87 Pass: Major Risk Alpine CO2 C02-32 C02-32 PB 1 VO 246.77 250.00 209.83 4.31 205.52 Pass: Major Risk Alpine CO2 C02-32 C02-32 VO 246.77 250.00 209.83 4.20 205.63 Pass: Major Risk Alpine CO2 CD2-33 C02-33 V2 247.64 250.00 200.27 4.13 196.14 Pass: Major Risk Alpine CO2 C02-33 C02-33A Vi 247.64 250.00 200.27 4.08 196.18 Pass: Major Risk Alpine CO2 C02-33 C02-34B Vi 247.64 250.00 200.27 4.13 196.14 Pass: Major Risk Alpine CO2 C 02-34 C02-34 V3 200.09 200.00 190.39 3.93 186.46 Pass: Major Risk Alpine CO2 C02-34 C02-34PB1 V2 200.09 200.00 190.39 4.04 186.35 Pass: Major Risk Alpine CO2 C02-35 C02-35 Vi 260.10 250.00 179.42 4.51 174.90 Pass: Major Risk Alpine CO2 C02-35 C02-35A Vi 247.26 250.00 179.30 4.27 175.04 Pass: Major Risk Alpine CO2 C02-36 C02-36 Lat 1 Vi Plan 293.73 300.00 171.25 4.93 166.32 Pass: Major Risk Alpine CO2 C02-36 C02-36 Lat 2 Vi Plan 293.73 300.00 171 .25 4.93 166.32 Pass: Major Risk Alpine CO2 C02-36 C02-36 Lat 3 V2 Plan 293.73 300.00 171.25 4.93 166.32 Pass: Major Risk Alpine CO2 C02-36 C02-36 Lat 4 Vi Plan 293.73 300.00 171.25 4.93 166.32 Pass: Major Risk Alpine CO2 C02-36 C02-36 PB1 V5 293.73 300.00 171.25 4.93 166.32 Pass: Major Risk Alpine CO2 C02-36 C02-36 V5 293.73 300.00 171.25 4.93 166.32 Pass: Major Risk Alpine CO2 C02-37 C02-37 Lat 1 V2 Plan: 247.63 250.00 159.59 4.58 155.02 Pass: Major Risk Alpine CO2 C02-37 C02·37 Lat 2 Vi Plan: 247.63 250.00 159.59 4.58 155.02 Pass: Major Risk Alpine CO2 C02-37 C02-37 Lat 3 Vi Plan: 247.63 250.00 159.59 4.58 155.02 Pass: Major Risk Alpine CO2 C02-37 C02-37 V16 247.63 250.00 159.59 4.58 155.02 Pass: Major Risk Alpine CO2 C02-38 C02-38 (Sag) VO 247.76 250.00 149.86 4.17 145.69 Pass: Major Risk Alpine CO2 C02-38 C02-38 V5 247.76 250.00 149.86 4.39 145.47 Pass: Major Risk Alpine CO2 C02-39 C02-39 Vi 295.02 300.00 139.17 4.63 134.54 Pass: Major Risk Alpine CO2 C02-39 C02-2·9PB1 VO 294.18 300.00 139.17 4.62 134.54 Pass: Major Risk Alpine CO2 C02-40 C02-40 V7 248.07 250.00 129.57 4.27 125.30 Pass: Major Risk Alpine CO2 C02-40 C02-40PB1 V9 248.07 250.00 129.57 4.27 125.30 Pass: Major Risk Alpine CO2 C02-41 C02-41 V9 248.33 250.00 118.14 4.17 113.97 Pass: Major Risk Alpine CO2 C02-42 C02-42 VO 248.62 250.00 110.13 4.04 106.09 Pass: Major Risk Alpine CO2 C02-42 C02-42PB1 VO 248.62 250.00 110.13 4.04 106.09 Pass: Major Risk Alpine CO2 C02-43 C02-43 (Sag) VO 247.96 250.00 100.74 4.31 96.43 Pass: Major Risk Alpine CO2 C02-43 C02-43 V8 247.96 250.00 100.74 4.68 96.07 Pass: Major Risk Alpine CO2 C02-43 C02-43PB1 (Sag) VO 247.96 250.00 100.74 4.31 96.43 Pass: Major Risk Alpine CO2 C02-43 C02-43PB1 V8 247.96 250.00 100.74 4.68 96.07 Pass: Major Risk Alpine CD2 C02-44 C02-44 V15 248.42 250.00 90.07 4.66 85.40 Pass: Major Risk Alpine CO2 C02-45 C02-45 V5 248.33 250.00 81.16 4.38 76.78 Pass: Major Risk Alpine CD2 C02-46 C02-46 V2 248.55 250.00 69.80 4.11 65.69 Pass: Major Risk Alpine CO2 CD2-47 C02-47 V2 248.67 250.00 59.98 4.22 55.76 Pass: Major Risk Alpine CO2 C02-48 C02-48 Vi 249.13 250.00 50.13 4.65 45.48 Pass: Major Risk Alpine CD2 C02-49 C02-49 Vi 297.81 300.00 39.58 4,68 34.91 Pass: Major Risk Alpine CO2 CO2-50 C02-50 V2 249.19 250.00 30.50 4.83 25.67 Pass: Major Risk Alpine CO2 CO2-50 C02-50PB1 V2 249.19 250.00 30.50 4.83 25.67 Pass: Major Risk Alpine CO2 CO2-51 C02-51 V8 249.72 250.00 21.21 5.03 16.18 Pass: Major Risk Alpine CO2 CO2-52 C02-52 V6 299.20 300.00 8.95 5.70 3.26 Pass: Major Risk Alpine CO2 CO2-55 C02-55 V5 451.46 450.00 20.83 6.62 14.21 Pass: Major Risk Alpine CO2 CO2-58 C02-58 V10 914.78 900.00 44.96 16.94 28.03 Pass: Major Risk ORIGINAL Company: Field: Reference Site: Reference Well: Reference Wellpath: spBr"'l""'y-sun Q..l!..JJ.. L-1NQ _~"y'!'ÇJL~ Halliburton Sperry-Sul:! Anticollision Report ConocoPhillips Alaska Inc. Colville River Unit Alpine CD2 Plan: CD2-53 CD2-53 Sununary <___ouunu_uu__... Offset Wellpath o.._n_u_____________> Site Well Wellpath Alpine CD2 Alpine CD2 Alpine CD2 Alpine CD2 Alpine CD2 Alpine CD2 Alpine CD2 Alpine CD4 Alpine CD4 CD2-58 Plan: CD2-31 Plan: CD2-31 Plan: CD2-54 Plan: CD2-56 Plan: CD2-57 Plan: CD2-57 N-11 N-12 CD2-58L 1 V 4 Plan: CD2-31 (ST Pilot PLAN: CD2-31 V5 Plan: Plan: CD2-54 VO Plan: Plan: CD2-56 VO Plan: CD2-57 VO Plan: CD2-57 Rig: CD2-57 V6 N-11 VO Plan: Prelim: N-12 VO Plan: Prelim: -\Jt.UIIW-iltlt1.".n...!t".,-'\.\ Date: 5/25/2004 Time: 13:59:44 Page: 2 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan: CD2-53, True North 52'MSL 52.0 Db: Oracle Reference Offset Ctr·Ctr No-Go Allowable MD MD Distance Area Deviation Warning ft ft ft ft ft 914.78 900,00 44.96 16.83 28.13 Pass: Major Risk 247.48 250.00 220.10 4.59 215.51 Pass: Major Risk 247.48 250,00 220.10 5.12 214.97 Pass: Major Risk 300.28 300.00 10.21 5.10 5.11 Pass: Major Risk 351,57 350.00 30.13 5.46 24.67 Pass: Major Risk 1013.23 1000.00 34,72 20.15 14.57 Pass: Major Risk 1215.74 1200.00 31.58 26.92 4.66 Pass: Major Risk 17323.60 9750.00 1329.46 235.50 1093.97 Pass: Major Risk 14621,05 13499.15 1089.02 195.32 893.70 Pass: Major Risk O'RI'GNA t - ¡ 34.0-+....· =J I I "1·....·..·..\· i I +.........'j'....... i I I I =i 32·0--:..t·..:..·.. ..........,......-... -! 30.0-"; i I I i ,., ,..I· 28.0--::'j 26.0 = \ - ; -¡ 24.0 _ I - -¡ s ¡:: 22.0 _ ¡ ,8 ' ~ -' I-< 20. Q------+-----, 0; ~ ~ 3 ).> r- 0.0 CD2-27 (CD2-27) CD2-33 (CD2-34B) CD2-36 (CD2-36 Lat 2) CD2-37 (CD2-37 Lat 2) CD2-39 (CD2-39PB 1) CD2-43 (CD2-43 (Sag)) CD2-46 (CD2-46) CD2-51 (CD2-51) Plan: CD2-31 (PLAN: CD2-31) N-12 (N-12) Plan: CD2-53 (wp04) (Plan: CD2-53/CD2-53) ! i I I I i ......··....1 I I 1150 1200 Measured Depth [ft] CD2-30 (CD2-30) CD2-34 (CD2-34) CD2-36 (CD2-36 Lat 3) CD2-37 (CD2-37 Lat 3) CD2-40 (CD2-40) CD2-43 (CD2-43) CD2-47 (CD2-47) CD2-52 (CD2-52) Plan: CD2-54 (plan: CD2-54) CD2-32 (CD2-32 PB1) CD2-34 (CD2-34PB 1) CD2-36 (CD2-36 Lat 4) CD2-37 (CD2-37) CD2-40 (CD2-40PB 1) CD2-43 (CD2-43PB 1 (Sag)) CD2-48 (CD2-48) CD2-55 (CD2-55) Plan: CD2-56 (Plan: CD2-56) CD2-33 (CD2-33) CD2-35 (CD2-35A) CD2-36 (CD2-36) CD2-38 (CD2-38) CD2-42 (CD2-42) CD2-44 (CD2-44) CD2-50 (CD2-50) CD2-58 (CD2-58L1) Plan: CD2-57 (Rig: CD2-57) CD2-32 (CD2-32) CD2-35 (CD2-35) CD2-36 (CD2-36 PB1) CD2-38 (CD2-38 (Sag») CD2-41 (CD2-41) CD2-43 (CD2-43PB 1) CD2-49 (CD2-49) CD2-58 (CD2-58) Plan: CD2-57 (CD2-57) CD2-33 (CD2-33A) CD2-36 (CD2-36 Lat 1) CD2-37 (CD2-37 Lat 1) CD2-39 (CD2-39) CD2-42 (CD2-42PB 1) CD2-45 (CD2-45) CD2-50 (CD2-50PB 1) Plan: CD2-3l (plan: CD2-3l (ST Pil N-ll (N-lI) Company: F1eld: Reference Site: Reference Well: Reference WeHpath: SperT"y-sun º"&t.....U.t:tll_llMY.H;_~.1I Halliburton Sperry-SulI Closest Approach Anticollision Report ConocoPhillips Alaska Inc. Colville River Unit Alpine C02 Plan: C02~53 C02-53 .1 Jt-UIUI..-1i!:1I}:'.''I.JI\.U''.'''....\. Date: 5/25/2004 Page: Time: 14:41 :51 Co-ordìnate(NE) Reference: Vertical (TVD) Reference: Well: Plan: C02-53, True North 52' MSL 52.0 GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpúlation Method: TVO Interval: 5.00 ft Depth Range: 7200.00 to 7250,00 ft Maximwn Radius: 1928.67 ft Reference: Error Model: Scan Method: Error Surface: Db: Sybase Plan: C02-53 (wp04) & NOT PLANNEO P~:)GR. ISCW SA Ellipse Horizontal Plane Ellipse + Casing Casing Points MD TVD Diameter Hole Size ft ft in in 3363.87 2390,00 9.625 12,250 12496.00 7232.47 7.000 8,500 17322.80 7222.00 6.125 6,125 Plan: C02~53 (wp04) Principal: Yes Name 9 5/8" @ 3364' MO 7" @ 12496'MO 6 1/8" Open Hole Sununary <_.____n______________ OffsetWellpath _______u_______u____> Site Well Well path Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 C02-27 C02-30 C02-32 C02-32 C02-33 C02-33 C02-33 C02-34 C02-34 C02-35 C02-35 C02-36 C02-36 C02-36 C02-36 C02-36 CD2-36 CD2-37 CD2-37 CD2-37 CD2-37 CD2-38 C02-38 CD2-39 CD2-39 CD2-40 CD2-40 CD2-41 C02-42 CD2-42 CD2-43 C02-43 C02-43 C02-43 C02-44 CD2-45 C02-46 C02-47 C02-48 C02-49 CD2-50 CD2-50 C02-51 CD2-52 CD2-55 C02-58 CD2-27 V6 C02-30 V8 CD2-32 PB 1 VO C02-32 VO CD2-33 V2 CD2-:33A V1 CD2-:34B V1 CD2-34 V3 C02-34PB1 V2 CD2-35 V1 CD2-35A V1 CD2-36 Lat 1 V1 Plan CD2-36 Lat 2 V1 Plan C02-36 Lat 3 V2 Plan C02-36 Lat 4 V1 Plan CD2-36 PB 1 V5 C02-36 V5 CD2-37 Lat 1 V2 Plan C02-37 Lat 2 V1 Plan C02-37 Lat 3 V1 Plan C02-37 V16 CD2-38 (Sag) VO CD2-38 V5 C02·39 V1 C02-39PB1 VO CD2-40 V7 C02-40PB1 V9 CD2-41 V9 C02-42 VO CD2-42PB1 VO CD2-43 (Sag) VO CD2-43 V8 CD2-43PB1 (Sag) VO C02-43PB 1 V8 CD2-44 V15 C02-45 V5 C02-46 V2 C02-47 V2 C02-48 V1 CD2-49 V1 CD2-50 V2 CD2-50PB1 V2 CD2-51 V8 C02-52 V6 CD2-55 V5 C02-58 V10 Date Composed: Version: Tied-to: 5/12/2004 16 From Well Ref. Point Reference MD ft Offset :rvm . ft Ctr-Ctr Nù-Go Distance Area ft ft Warning Allowable Deviation ft Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 12468.28 16930.64 1398.74 108.61 1290.13 Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range o ~!i. GI~MÆ¥~ Company: ConocoPhillips Alaska Inc. Field: Colville River Unit Reference Site: Alpine C02 Reference Well: Plan: C02-53 Reference Wellpath: C02-53 Swmnary <---------------------- Offset Well path ----------------------> Site Well WeUpath Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C02 Alpine C04 Alpine C04 C02-58 Plan: C02-31 Plan: C02-31 Plan: C02-54 Plan: C02-56 Plan: C02-57 Plan: C02-57 N-11 N-12 o'-"rlalliburton Sperry-Sun'~ Clo~est Approach Anticollision Report Date: 5125/2004 Tiíne: .14:41:51 ~V-5L.n p,nLJ.-ING seAVlceli "' K.\U""IUU'.i .nut".'\,,, Page: z We1f:PlàrkCD2-53. True North 52' MSL52.0 Db: Sybase Co-ordiitate(NE}·Referel1ce: VerticåI (TVD) Reference: Reference MD tt Offset °Ctr..Ctr.· No"Go MD DiStáriceMea ft tt it Allowable I)~YiatîQn ft C02-58l1 V4 Plan: C02-31 (ST Pilot PLAN: C02-31 V5 Plan: Plan: C02-54 VO Plan: Plan: C02-56 VO Plan: C02-57 VO Plan: C02-57 12534.33 12530.54 1493.00 607.19 885.81 Rig: C02-57 V6 12534.33 12551.18 1489.66 327.74 1161.93 N-11 VO Plan: Prelim: N-12 VO Plan: Prelim: ORIGINA:.. WarI1ing Out of range Out of range Out of range Out of range Out of range Pass: Major Risk Pass: Major Risk Out of range Out of range Halliburton Sperry-SUit Sper"f"\Y-SLJn g.a.L\".J..l.N..!L.......e.1'~ GeoReport \ U,nIÞll1t.IU' ('O'I..W_,\'"\ Company: ConocoPhillips Alaska Inc. Date: 5/25/2004 Time: 14:11 :24 Page: 1 Fïeld: Colville River Unit Co-ordil1ate(NE) Reference: Well: Plan: CD2-53, True North Site: Alpine CD2 VerticaJ (TVD) Reference: 52' MSL52.0 Well: Plan: CD2-53 Section (VS) Reference: Well (O.OûN,O,OOE,148;34Azi) Wellpath: CD2-53 Survey Calculation Method: Minimum Curvature Db: Oracle Survey: Start Date: Company: Engineer: Tool: Tied-to: Surve)' MD Inel Azim TVD Sys TVD N/S FJW MapN MapE Comments ft deg deg ft ft ft ft ft ft 36.10 0.000 0,000 36.10 -15.90 0.00 0.00 5974264.070 371736.310 SHL (2093'FNL & 1499'FEL; 100.00 0,000 0.000 100.00 48,00 0.00 0.00 5974264.070 371736.310 200.00 0.000 0.000 200.00 148,00 0.00 0.00 5974264.070 371736.310 225.00 0.000 0,000 225.00 173,00 0.00 0.00 5974264.070 371736.310 Begin Dir @ 3°/100' 300.00 2.250 160.000 299.98 247,98 -1.38 0.50 5974262.678 371736.790 400,00 5.250 160,000 399,76 347.76 -7.53 2.74 5974256.496 371738.921 425.00 6.000 160.000 424.63 372.63 -9,83 3,58 5974254.180 371739.719 Continue Dir @ 4°/100' 500.00 8.942 155.403 498.99 446.99 -18.82 7.35 5974245.132 371743.333 600.00 12.906 152.537 597.16 545.16 -35.80 15.73 5974228.009 371751.429 700.00 16.887 151.004 693.78 641.78 -58.42 27.93 5974205,183 371763.235 800.00 20.875 150,044 788.38 736.38 -86,57 43.87 5974176.765 371778.694 900,00 24.867 149.380 880.50 828.50 -120.12 63.49 5974142,893 371797.730 1000,00 28.861 148.890 969.69 917.69 -158,89 86.68 5974103.732 371820.250 1100.00 32,856 148.510 1055.52 1003.52 -202,70 113.33 5974059.474 371846.144 1200.00 36.852 148.205 1137.56 1085.56 -251.34 143.31 5974010,333 371875.288 1300.00 40.849 147,951 1215.42 1163.42 -304,57 176.48 5973956.549 371907.537 1400.00 44.847 147.735 1288,72 1236.72 -362.13 212,67 5973898.384 371942.736 1500.00 48.844 147.548 1357.11 1305,11 -423.74 251,71 5973836.122 371980,713 1600.00 52.842 147,382 1420,24 1868,24 -489,10 293.41 5973770.066 372021.283 1697.88 56.755 147.236 1476.65 1424,65 -556.39 336,60 5973702.047 372063.312 1698.00 56.755 147.236 1476,72 1424.72 -556.48 336.65 5973701.959 372063.367 End Dir, Start Sail @ 56,8 1700.00 56.755 147.236 1477,81 1425,81 -557,89 337.56 5973700.538 372064.248 1800.00 56.755 147.236 1532,63 1480,63 -628,21 382.82 5973629.451 372108.295 1900.00 56.755 147,236 1587.46 1535.46 -698,54 428.08 5973558.364 372152.343 2000.00 56.755 147.236 1642.28 1590.28 -768.87 473.34 5973487.278 372196.390 2100.00 56,755 147.236 1697,10 1645,10 -839,20 518.60 5973416.191 372240.437 2200.00 56.755 147,236 1751.92 1699,92 -909.53 563.86 5973345,104 372284.485 2300.00 56.755 147,236 1806.74 1754.74 -979,86 609,12 5973274,018 372328.532 2400.00 56.755 147.236 1861.56 1809,56 -1050.19 654.38 5973202.931 372372.579 2500.00 56.755 147.236 1916.38 1864.38 -1120.51 699,64 5973131.844 372416.627 2600.00 56,755 147,236 1971 ,20 1919.20 -1190,84 744.90 5973060.758 372460.674 2700,00 56.755 147.236 2026,03 1974.03 -1261,17 790.16 5972989.671 372504,721 2800,00 56.755 147.236 2080.85 2028,85 -1331.50 835.42 5972918.585 372548.769 2900.00 56.755 147.236 2135.67 2083.67 -1401,83 880.68 5972847.498 372592.816 3000.00 56,755 147,236 2190.49 2138.49 -1472,16 925.94 5972776.411 372636.863 3100,00 56,755 147,236 2245,31 2193,31 -1542.49 971,20 5972705.325 372680,911 3200.00 56.755 147,236 2300,13 2248.13 -1612.81 1016.46 5972634,238 372724.958 3300.00 56,755 147,236 2354.95 2302,95 -1683,14 1061.73 5972563,151 372769.006 3363,93 56,755 147.236 2390,00 2.338,00 -1728.10 1090.66 5972517,708 372797.164 9 5/8" @ 3364' MD 3396,76 56.755 147,236 2408.00 2356.00 -1751.19 1105.52 5972494,367 372811.626 C-30 3400.00 56.755 147.236 2409.78 2357,78 -1753.47 1106.99 5972492,065 372813.053 3500,00 56,755 147,236 2464.60 2412.60 -1823,80 1152,25 5972420.978 372857.100 3600.00 56,755 147.236 2519.42 2467.42 -1894,13 1197.51 5972349.891 372901,148 3700,00 56.755 147.236 2574,24 2522.24 -1964,46 1242,77 5972278,805 372945,195 3800,00 56,755 147.236 2629.06 2577 .06 -2034.78 1288.03 5972207,718 372989,242 3900,00 56.755 147.236 2683.88 2631.88 -2105,11 1333,29 5972136,632 373033,290 4000,00 56.755 147,236 2738.70 2686.70 -2175.44 1378,55 5972065,545 373077,337 4077,15 56.755 147,236 2781,00 2729,00 -2229,70 1413.47 5972010.700 373111.321 C-20 4100,00 56.755 147.236 2793.53 2741.53 -2245.77 1423,81 5971994.458 373121.384 OrK' r~H~rAl· ..: ,,' ., ;,LJ:, :~. ; .. .. '.. .. 'Ifalliburton Sperry -Sun"-" SperT"Y-SLn R!lI..I..J..t ~G ,$ ~-" \ll.!;.!i.~ GeoReport _~ ""_U..li1.'\. 4'~".\..,\\- Company: ConocoPhillips Alaska Inc. Date: 5/25/2004 TiIIle:f4:11:24 Page: 2 Fíeld: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD2-53, True North Site: Alpine CD2 Vertical (TVD) Reference: 52' MSL 52.0 Well: Plan: CD2-53 Section (VS) Reference: Well (0.ooN,O.OOE,148.34Azi) Wellpath: CD2-53 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD IDcI Azim TVD Sys TVD N/S FJW MapN MaPE ft deg deg ft ft ft ft ft ft 4200.00 56.755 147.236 2848.35 2796.35 -2316.10 1469.07 5971923.372 373165.432 4300.00 56.755 147.236 2903.17 2851.17 -2386.43 1514.33 5971852.285 373209.479 4400.00 56.755 147.236 2957.99 2905.99 -2456.76 1559.59 5971781.198 373253.526 4500.00 56.755 147.236 3012.81 2960.81 -2527.08 1604.85 5971710.112 373297.574 4600.00 56.755 147.236 3067.63 3015.63 -2597.41 1650.11 5971639.025 373341.621 4700.00 56.755 147.236 3122.45 3070.45 -2667.74 1695.37 5971567.938 373385.668 4800.00 56.755 147.236 3177.27 3125.27 -2738.07 1740.63 5971496.852 373429.716 4900.00 56.755 147.236 3232.10 3180.10 -2808.40 1785.89 5971425.765 373473.763 5000.00 56.755 147.236 3286.92 3234.92 -2878.73 1831.15 5971354.678 373517.811 5100.00 56.755 147.236 3341.74 3289.74 -2949.06 1876.42 5971283.592 373561.858 5200.00 56.755 147.236 3396.56 3344.56 -3019.38 1921.68 5971212.505 373605.905 5300.00 56.755 147.236 3451 .38 3399.38 -3089.71 1966.94 5971141 .419 373649.953 5400.00 56.755 147.236 3506.20 3454.20 -3160.04 2012.20 5971070.332 373694.000 5500.00 56.755 147.236 3561.02 3509.02 -3230.37 2057.46 5970999.245 373738.047 5600.00 56.755 147.236 3615.85 3563.85 -3300.70 2102.72 5970928.159 373782.095 5700.00 56.755 147.236 3670.67 3618.67 -3371.03 2147.98 5970857.072 373826.142 5800.00 56.755 147.236 3725.49 3673.49 -3441.36 2193.24 5970785.985 373870.189 5900.00 56.755 147.236 3780.31 3728.31 -3511.68 2238.50 5970714.899 373914.237 6000.00 56.755 147.236 3835.13 3783.13 -3582.01 2283.76 5970643.812 373958.284 6025.30 56.755 147.236 3849.00 3797.00 -3599.80 2295.21 5970625.828 373969.427 K-3 MARKER 6100.00 56.755 147.236 3889.95 3837.95 -3652.34 2329.02 5970572.725 374002.331 6200.00 56.755 147.236 3944.77 3892.77 -3722.67 2374.28 5970501 .639 374046.379 6300.00 56.755 147.236 3999.60 3947.60 -3793.00 2419.54 5970430.552 374090.426 6382.82 56.755 147.236 4045.00 3993.00 -3851.25 2457.03 5970371.676 374126.908 BASAL K-3 SS 6400.00 56.755 147.236 4054.42 4002.42 -3863.33 2464.80 5970359.466 374134.474 6432.07 56.755 147.236 4072.00 4020.00 -3885.88 2479.32 5970336.665 374148.601 K-2 MARKER 6500.00 56.755 147.236 4109.24 4057.24 -3933.65 2510.06 5970288.379 374178.521 6600.00 56.755 147.236 4164.06 4112.06 -4003.98 2555.32 5970217.292 374222.568 6621.78 56.755 147.236 4176.00 4124.00 -4019.30 2565.18 5970201.809 374232.162 BASE K-2 SEQUENCE 6700.00 56.755 147.236 4218.88 4166.88 -4074.31 2600.58 5970146.206 374266.616 6800.00 56.755 147.236 4273.70 4221 .70 -4144.64 2645.84 5970075.119 374310.663 6900.00 56.755 147.236 4328.52 4276.52 -4214.97 2691.10 5970004.032 374354.710 7000.00 56.755 147.236 4383.34 4331.34 -4285.30 2736.37 5969932.946 374398.758 7100.00 56.755 147.236 4438.17 4386.17 -4355.63 2781.63 5969861.859 374442.805 7200.00 56.755 147.236 4492,99 4440.99 -4425.95 2826.89 5969790.772 374486.852 7300.00 56.755 147.236 4547.81 4495.81 -4496.28 2872.15 5969719.686 374530.900 7400.00 56.755 147.236 4602.63 4550.63 -4566.61 2917.41 5969648.599 374574.947 7500.00 56.755 147.236 4657.45 4605.45 -4636.94 2962.67 5969577.512 374618.994 7600.00 56.755 147.236 4712,27 4660.27 -4707.27 3007.93 5969506.426 374663.042 7700.00 56.755 147.236 4767,09 4715,09 -4777.60 3053.19 5969435.339 374707.089 7800.00 56.755 147.236 4821.92 4769,92 -4847.93 3098.45 5969364.253 374751.137 7900.00 56.755 147.236 4876.74 4824.74 -4918.25 3143.71 5969293.166 374795.184 8000.00 56.755 147.236 4931 .56 4879.56 -4988.58 3188.97 5969222.079 374839.231 8100.00 56.755 147.236 4986.38 4934.38 -5058.91 3234.23 5969150.993 374883.279 8200.00 56.755 147.236 5041 .20 4989.20 -5129.24 3279.49 5969079.906 374927.326 8300.00 56.755 147.236 5096.02 5044.02 -5199.57 3324.75 5969008.819 374971 .373 8400.00 56.755 147.236 5150.84 5098.84 -5269.90 3370.01 5968937.733 375015.421 8500.00 56.755 147.236 5205.67 5153.67 -5340.23 3415.27 5968866.646 375059.468 8600.00 56.755 147.236 5260.49 5208.49 -5410.55 3460.53 5968795.559 375103.515 8700.00 56.755 147.236 5315.31 5263.31 -5480.88 3505.79 5968724.473 375147.563 8800.00 56.755 147.236 5370,13 5318.13 -5551.21 3551.06 5968653.386 375191.610 8900.00 56.755 147.236 5424,95 5372.95 -5621.54 3596.32 5968582.300 375235.657 ORIGINAL Halliburton Sperry-Sui. 5pE!l'T'~-5un P.JUJ....t.....!...ttlL_"AJU'l'i..tl;..§.1i GeoReport \ HUIU.1.tH1-" .""'ÞO'_"'" Company: ConocoPhillips Alaska Inc. Date: 5/25/2004 Time: 14:11:24 Page: 3 Field: Colville River Unit Co·ordinate(NE) Reference: Well: Plan: CD2-53, True North Site: Alpine CD2 Vertical (TVD) Reference: 52'MSL 52.0 Well: Plan: CD2-53 Section (VS) Reference: Well (O.OON ,O.OOE, 148.34Azi) Wellpath: CD2·53 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD lnel Azim TVD Sys TVD N/S EIW MapN MapE Comments ft deg deg ft ft ft ft ft ft 9000.00 56.755 147.236 5479,77 5427.77 -5691 ,87 3641.58 5968511.213 375279.705 9100.00 56.755 147.236 5534.59 5482.59 -5762.20 3686.84 5968440.126 375323.752 9200,00 56,755 147,236 5589.41 5537.41 -5832.52 3732.10 5968369.040 375367.800 9300,00 56.755 147.236 5644.24 5592,24 -5902.85 3777.36 5968297.953 375411.847 9400,00 56.755 147.236 5699.06 5647.06 -5973.18 3822.62 5968226.866 375455,894 9441 .85 56,755 147,236 5722.00 5670.00 -6002.61 3841 .56 5968197.117 375474.328 ALBIAN 97 9500.00 56.755 147,236 5753.88 5701 .88 -6043,51 3867.88 5968155.780 375499.942 9600.00 56.755 147.236 5808.70 5756.70 -6113,84 3913.14 5968084.693 375543.989 9700.00 56.755 147.236 5863.52 5811.52 -6184.17 3958.40 5968013.606 375588.036 9800,00 56.755 147.236 5918.34 5866.34 -6254.50 4003.66 5967942.520 375632,084 9900,00 56.755 147.236 5973,16 5921.16 -6324.82 4048.92 5967871 .433 375676,131 10000,00 56.755 147.236 6027.99 5975.99 -6395.15 4094.18 5967800.347 375720.178 10100,00 56.755 147.236 6082.81 6030.81 -6465.48 4139.44 5967729.260 375764.226 10200,00 56.755 147.236 6137,63 6085.63 -6535.81 4184.70 5967658.173 375808.273 10300,00 56.755 147.236 6192.45 6140.45 -6606,14 4229.96 5967587.087 375852.320 10311,95 56,755 147,236 6199.00 6147.00 -6614,54 4235,37 5967578.593 375857.583 ALBIAN 96 10400.00 56.755 147,236 6247.27 6195,27 -6676.47 4275.22 5967516.000 375896,368 10500.00 56.755 147.236 6302.09 6250.09 -6746.80 4320.48 5967444,913 375940.415 10600,00 56,755 147.236 6356.91 6304.91 -6817.12 4365.75 5967373.827 375984.463 10700.00 56,755 147.236 6411,74 6359.74 -6887.45 4411.01 5967302.740 376028.510 10800.00 56.755 147.236 6466,56 6414.56 -6957.78 4456.27 5967231.653 376072.557 10900.00 56.755 147.236 6521 .38 6469.38 -7028.11 4501.53 5967160.567 376116.605 11000,00 56.755 147.236 6576.20 6524.20 -7098.44 4546.79 5967089.480 376160.652 11100,00 56.755 147.236 6631.02 6:579.02 -7168.77 4592.05 5967018.393 376204,699 11200,00 56,755 147,236 6685.84 6633.84 -7239,10 4637.31 5966947.307 376248,747 11293.32 56.755 147.236 6737.00 6685.00 -7304,72 4679.54 5966880.971 376289.850 TOP HRZ 11300,00 56.755 147.236 6740.66 6688.66 -7309.42 4682.57 5966876.220 376292.794 11400,00 56.755 147.236 6795.49 6743.49 -7379.75 4727.83 5966805.134 376336.841 11500,00 56.755 147.236 6850.31 6798.31 -7450.08 4773.09 5966734.047 376380,889 11600,00 56.755 147.236 6905.13 6853.13 -7520.41 4818.35 5966662.960 376424.936 11603.42 56.755 147.236 6907.00 6855,00 - 7522.81 4819.90 5966660.533 376426.440 BASE HRZ 11687.32 56.755 147,236 6953.00 6901 .00 - 7581.82 4857.87 5966600.885 376463.400 K-1 MARKER 11700,00 56.755 147.236 6959.95 6907.95 -7590.74 4863.61 5966591 .874 376468.983 11754.82 56,755 147.236 6990.00 6938.00 -7629.29 4888.42 5966552.907 376493.128 TOP KUPARUK 11776,24 56,755 147.236 7001.74 6949.74 -7644.35 4898.12 5966537.680 376502.564 Begin Dir: @ 4°/100' 11800,00 57.702 147.340 7014,61 6962.61 -7661,17 4908.91 5966520.687 376513.072 11831.22 58.946 147.473 7031,00 6979,00 -7683,55 4923.23 5966498.062 376526.998 LCU 11900.00 61,686 147.753 7065,06 7013.06 -7734.01 4955.23 5966447.071 376558,129 12000.00 65.671 148,137 7109,39 7057.39 -7809.96 5002.78 5966370.321 376604,375 12100.00 69,657 148.497 7147.38 7095,38 -7888.66 5051.35 5966290.810 376651,586 12116.41 70.311 148.554 7153,00 7101 ,00 -7901,80 5059.40 5966277 .529 376659.408 MILUVEACH A 12179.68 72,834 148.771 7173.00 7121 .00 -7953,07 5090,62 5966225.737 376689.742 ALPINE D 12200.00 73.644 148.839 7178,86 7126.86 -7969,72 5100,70 5966208.926 376699.532 12270.31 76.448 149,071 7197,00 7) 45.00 -8027,91 5135,72 59661 50,149 376733.554 ALPINE C 12300.00 77,632 149.167 7203,66 7151,66 -8052,74 5150,57 5966125,067 376747.978 12400.00 81.619 149.485 7221 ,66 7169.66 -8137.33 5200,74 5966039.642 376796.689 12496,00 85.448 149.785 7232.47 7180.47 -8219.62 5248.95 5965956.547 376843.480 1" @ 12496'MD 12500.00 85,607 149,797 7232,79 7180,79 -8223.06 5250,96 5965953,067 376845.427 12600,00 89,595 150,106 7236,97 7184,97 -8309,53 5300.98 5965865,764 376893.956 12614.31 90.166 150,150 7237.00 7185.00 -8321,94 5308.10 5965853.239 376900.867 CD2-53 (Heel) 12700.00 90,167 150,150 7236,75 7184.75 -8396.26 5350,75 5965778.202 376942.238 12800,00 90,167 150.150 7236.46 7184.46 -8482,99 5400,53 5965690.638 376990,516 12900,00 90,168 150.151 7236,17 7184.17 -8569,73 5450,30 5965603.073 377038.793 ORIGINAL ~-rlalliburton Sperry-Sun"'~ GeoReport =:af..R:=l ""y-sun 1UIlI.-1,.1.fß1 _S."VICI!!S ~ _\I U~1t1t....... f'UloD"_~""'-- Company: ConocoPhillips Alaska Inc. Field: Colville River Unit Site: Alpine C02 Well: Plan: C02-53 Wellpath: C02-53 Survey MD Incl ft deg 13000.00 90.169 13100.00 90.169 13200.00 90.170 13300.00 90.171 13400.00 90.171 13500.00 90.172 13600.00 90.173 13700.00 90.174 13800.00 90.174 13900.00 90.175 14000.00 90.176 14100.00 90.176 14200.00 90.177 14300.00 90.178 14400.00 90.179 14500.00 90.179 14600.00 90.180 14700.00 90.181 14800.00 90.181 14900.00 90.182 15000.00 90.183 15100.00 90.183 15200.00 90.184 15300.00 90.185 15400.00 90.186 15500.00 90.186 15600.00 90.187 15700.00 90.188 15800.00 90.188 15900.00 90.189 16000.00 90.190 16100.00 90.191 16200.00 90.191 16300.00 90.192 16400.00 90.193 16500.00 90.193 16600.00 90.194 16700.00 90.195 16800.00 90.195 16900.00 90.196 17000.00 90.197 17100.00 90.198 17200.00 90.198 17300.00 90.199 17322.61 90.199 Well path: C02-53 Current Datwn: Magnetic Data: Field Strength: Vertical Section: Azim deg 150.151 150.151 150.151 150.152 150.152 150.152 150.152 150.153 150.153 150.153 150.153 150.154 150.154 150.154 150.154 150.155 150.155 150.155 150.155 150.156 150.156 150.156 150.156 150.156 150.157 150.157 150.157 150.157 150.158 150.158 150.158 150.158 150.159 150.159 150.159 150.159 150.160 150.160 150.160 150.160 150.161 150.161 150.161 150.161 150.161 52' MSL 8/26/2002 57426 nT Depth From (TVD) TVD Sys TVD ft ft 7235.87 7183.87 7235.58 7183.58 7235.28 7183.28 7234.99 7182.99 7234.69 7182.69 7234.39 7182.39 7234.09 7182.09 7233.78 7181.78 7233.48 7181.48 7233.17 7181.17 7232.87 7180.87 7232.56 7180.56 7232.25 7180.25 7231.94 7179.94 7231.63 7179.63 7231.32 7179.32 Date: 5125/2004 Tìme:14:H:24. . .PJige: 4 Co-ordinate(NE)Reference: Wèll:<Plélll::CD2~53, True North Vertical (TVD) Reference: 52' MSL 52.0 Section (VS) Reference: Well (0.OON,O.00E,148.34Azi) Survey Calculation Method: Minimum Curvature Db: Oracle N/S ft -8656.46 -8743.19 -8829.93 -8916.66 -9003.40 -9090.13 -9176.87 -9263.60 -9350.34 -9437.07 -9523.81 -9610.54 -9697.28 -9784.01 -9870.75 -9957.49 7231.01 7179.01 -10044.22 7230.69 7178.69 -10130.96 7230.38 7178.38 -10217.70 7230.06 7178.06 -10304.44 7229.74 7177.74 -10391.17 7229.42 7177.42 -10477.91 7229.10 7177.10 -10564.65 7228.78 7176.78 -10651.39 7228.45 7176.45 -10738.13 7228.13 7176.13 -10824.86 7227.80 7175.80 -10911.60 7227.48 7175.48 -10998.34 7227.15 7175.15 -11085.08 7226.82 7174.82 -11171.82 7226.49 7174.49 -11258.56 7226.16 7174.16 -11345.30 7225.82 7173.82 -11432.04 7225.49 7'173.49 -11518.78 7225.15 7173.15 -11605.52 7224.82 7172.82 -11692.26 7224.48 7172.48 7224.14 7172.14 7223.80 7171.80 7223.46 7171.46 7223.11 7171.11 7222.77 7170.77 7222.43 7170.43 7222.08 7170.08 7222.00 1'170,00 -11779.00 -11865.74 -11952.49 -12039.23 -12125.97 -12212.71 -12299.45 -12386.20 -12405.81 F1W ft 5500.07 5549.84 5599.61 5649.38 5699.15 5748.92 5798.69 5848.46 5898.23 5948.00 5997.77 6047.53 6097.30 6147.07 6196.84 6246.60 6296.37 6346.13 6395.90 6445.66 6495.43 6545.19 6594.95 6644.72 6694.48 6744.24 6794.00 6843.77 6893.53 6943.29 6993.05 7042.81 7092.57 7142.33 7192.09 7241.85 7291.61 7341.36 7391.12 7440.88 7490.64 7540.39 7590.15 7639.90 7651.15 MapN ft 5965515.508 5965427.943 5965340.377 5965252.812 5965165.246 5965077 .680 5964990.113 5964902.547 5964814.980 5964727.414 5964639.847 5964552.279 5964464.712 5964377 .144 5964289.576 5964202.008 5964114.440 5964026.872 5963939.303 5963851.734 5963764.165 5963676.596 5963589.027 5963501 .457 5963413.887 5963326.317 5963238.747 5963151.177 5963063.606 5962976.035 5962888.464 5962800.893 5962713.321 5962625.750 5962538.178 5962450.606 5962363.034 5962275.461 5962187.889 5962100.316 5962012.743 5961925.170 5961837.596 5961750.023 5961730.223 Drilled From: Tie-on Depth: Height 52.00 ft Above System Datum: Declination: Mag Dip Angle: +N/-S +E/-W ORIGINAL MapE ft 377087.070 Comments 377135.347 377183.623 377231.899 377280.174 377328.449 377376.724 377424.998 377473.272 377521.545 377569.818 377618.091 377666.364 377714.636 377762.907 377811.179 377859.449 377907.720 377955.990 378004.260 378052.529 378100.798 378149.067 378197.335 378245.603 378293.871 378342.138 378390.405 378438.671 378486.938 378535.203 378583.469 378631.734 378679.998 378728.262 378776.526 378824.790 378873.053 378921.316 378969.578 379017.840 379066.102 379114.363 379162.624 379173.535 CD2-53 (Toe) Well Ref. Point 36.10 ft Mean Sea Level 24.74 deg 80.59 deg Direction Company: Field: Site: Well: Wellpath: Halliburton Sperry-Sui. GeoReport Spet""'f""')J-SLJn Q.!!tll"..J,.l.NJI~.Y:1Ç.,..$ -\. HUI~w.-"'1U.'" {UUjI'_,,-'\\ ConocoPhillips Alaska Inc. Colville River Unit Alpine C02 Plan: C02-53 CD2·53 Date: 5/25/2004 Time: 14:11 :24 Page: 5 Co-ordinateG'i'E) Reference: Well: Plan: C02-53. True North Vertical (TVD) Reference: 52' MSL 52.0 Section (VS) Reference: Well (0.OON,O.00E,148.34Azi) Survey Calculation Method: Minimum Curvature Db: Oracle \Vellpath: C02-53 Current Datwn: Magnetic Data: Field Strength: Vertical Section: Targets Height 52,00 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 52' MSL 8/26/2002 57426 nT Depth From (TVD) ft 36.10 +N/-S ft 0.00 Well Ref, Point 36.10 ft Mean Sea Level 24.74 deg 80.59 deg Direction deg 148.336 Map Map <on_ Latitude ----> <_u Longitude on> Name Description TVD +N/-S +FJ·W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft C02-53 (Toe) 7222,00 -12405.81 7651.15 5961730.223379173.535 70 18 14.470 N 150 58 43.627 W C02-53 (Heel) 7237.00 -8321.94 5308.10 5965853.239376900.867 70 18 54.654 N 150 59 51.863 W Annotation MD ft 36.10 225.00 425.00 1698.00 3363.93 11776,24 12496.00 12614.31 17322.60 TVD ft 36,10 225.00 424.63 1476.72 2390.00 7001.74 7232.47 7237.00 7222.00 SHL (2093'FNL & 1499'FEL; Sec2-T11 N-R4E) Begin Oir @ 3°/100' Continue Oir @ 4°/100' End Oir. Start Sail @ 56.8° 9-58" Csg PLOrill out 8 1/5" hole Begin Oir: @ 4°/100' 7" Csg Pt..,Continue Oir: Begin 6 1/8" Hole Target Heel: Begin GeoSteer; (5137'FNL & 1479'FEL Target Toe: Open hole (3943'FNL & 4084'FEL) OR IGI NAL REV DAlE BY CK APP DESCRIP1l0N REV DAlE BY I APP DESCRIP1l0N o 5/29/01 G.D J.Z. C.A. PER'--Ã01004ACS 4 5/15/03 G.D. J.2:./1 C.A. PER K03074ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.2, T 11 N, R 4 E U.M. SEC.LlNE US PLAN WELL y' X' LA T.(N) LONG.(W) FNL EL GND PAD 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 15.9 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.8 8.8 8.8 8.8 8.8 8.8 8.8 8.8 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.6 8.6 8.6 8.6 8.6 8.5 8.5 8.5 8.5 8.5 8.5 8.5 8.5 8.5 8.5 1558' 1556' 1555' 1554' 1552' 1551' 1550' 1549' 1548' 1546' 1545' 1544' 1543' 1542' 1541' 1539' 1538' 1536' 1536' 1534' 1533' 1532' 1531' 1530' 1528' 1527' 1526' 1525' 1523' 1522' 1521' 1520' 1519' 1517' 1516' 1515' 1514' 1513' 1512' 1510' 1509' 1508' 1506' 1505' 1504' 1503' 1502' 1501' 1499' 1498' 1497' 1496' 1494' 1493' 1617' 1627' 1636' 1646' 1656' 1666' 1676' 1686' 1696' 1706' 1716' 1726' 1736' 1746' 1755' 1765' 1775' 1785' 1795' 1805' 1815' 1825' 1835' 1844' 1855' 1865' 1875' 1885' 1894' 1905' 1915' 1924' 1934' 1944' 1954' 1964' 1974' 1984' 1994' 2004' 2013' 2024' 2034' 2043' 2053' 2063' 2073' 2083' 2093' 2103' 2113' 2123' 2133' 2143' 02' 28.443" 02' 28.406" 02' 28.359" 02' 28.337" 02' 28.291" 02' 28.259" 02' 28.226" 02' 28.193" 02' 28.151" 02' 28.110" 02' 28.083" 02' 28.044" 02' 28.008" 02' 27.976" 02' 27.939" 02' 27.897" 02' 27.870" 02' 27.817" 02' 27.801" 02' 27.756" 02' 27.725" 02' 27.691" 02' 27.648" 02' 27.620" 02' 27.575" 02' 27.548" 02' 27.513" 02' 27.474" 02' 27.438" 02' 27.407" 02' 27.363" 02' 27.331" 02' 27.297" 02' 27.256" 02' 27.216" 02' 27.187" 02' 27.148" 02' 27.116" 02' 27.087" 02' 27.042" 02' 27.005" 02' 26.971" 02' 26.934" 02' 26.898" 02' 26.868" 02' 26.836" 02' 26.793" 02' 26.762" 02' 26.724" 02' 26.684" 02' 26.652" 02' 26.618" 02' 26.580" 02' 26.544" 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151· 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 151' 21.202" 21.103" ?1.008" ?0.910" 20.812" 20.716" ?.o.617" ?.o.519" 20.424" 20.328" 20.225" 20.130" 20.033" 19.935" 19.842" 19.739" 19.642" 19.545" 19.445" 19.348" 19.250" 19.152" 19.053" 18.958" 18.860" 18.763" 18.665" 18.565" 18.475" 18.370" 18.274" 18.179" 18.079" 17.986" 17.885" 17.787" 17.689" 17.595" 17.494" 17.396" 17.304" 17.200" 17.102" 17.006" 16.908" 16.811" 16.713" 16.618" 16.518" 16.421 " 16.322" 16.226" 16.128" 16.029" 70' 20' 70' 20' 70' ?O' 70' ?O' 70' 20' 70' 20' 70' ?.o' 70' ?O' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' ?O' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' ?.o' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 70' 20' 371,685.60 371,686.73 371,688.17 371,688.72 371,690.14 371.691.07 371.692.02 371.692.98 371,694.26 371,695.50 371,696.24 371,697.39 371,698.48 371.699.38 371.700.50 371.701.77 371.702.51 371,704.15 371.704.52 371,705.92 371,706.81. 371,707.80 371,709.10 371,709.87 371,711.26 371.712.00 371,713.04 371,714.18 371,715.28 371.716.13 371.717.49 371,718.42 371,719.40 371,720.66 371,721.83 . 371,722.68 371.723.84 371.724.77 371.725.60 371.726.94 371,728.07 371.729.06 371.730.13 371.731.19 371,732.05 371,733.00 371.734.28 371,735.18 371.736.31 371,737.50 371,738.44 371.739.42 371,740.55 371.741.60 5.974,741.17 5.974.731.13 5.974.721.46 5.974.711.45 5.974.701.48 5.974.691.64 5.974,681.62 5.974.671.61 5.974,661.90 5.974,652.12 5.974.641.66 5,974,631.95 5,974,622.10 5,974.612.15 5,974,602.64 5,974,592.18 5,974,582.28 5,974,572.39 5,974,562.21 5.974,552.30 5,974.542.33 5,974,532.34 5,974.522.31 5,974,512.60 5,974,502.63 5.974.492.75 5,974,482.74 5,974,472.57 5,974,463.34 5,974.452.65 5.974.442.90 5,974,433.20 5,974,423.05 5,974,413.52 5,974.403.28 5.974,393.27 5.974.383.33 5,974,373.69 5,974,363.45 5,974.353.42 5.974,344.11 5.974,333.52 5,974.323.53 5,974,313.77 5.974.303.80 5,974,293.84 5,974,283.88 5,974,274.18 5,974,264.07 5,974,254.19 5,974,244.05 5,974,234.27 5,974,224.26 5,974,214.18 CD2-1 CD2-2 CD2-3 CD2-4 CD2-5 CD2-6 CD2-7 CD2-8 CD2-9 CD2-10 CD2-11 CD2-12 CD2-13 CD2-14 CD2-15 CD2-16 CD2-17 CD2-18 CD2-19 CD2-20 CD2-21 CD2-22 CD2-23 CD2-24 CD2-25 CD2-26 CD2-27 CD2-28 CD2-29 CD2-30 CD 2 - 31 CD2-32 CD2-33 CD2-34 CD2-35 CD2-36 CD2-37 CD2-38 CD2-39 CD2 - 40 CD2-41 C02-42 CD2-43 CD2-44 CD2-45 CD2-46 CD2-47 CD 2 -48 CD2-49 CD2-50 CD2-51 CD2-52 C02-53 CD2-54 CD2-55 CD2-56 CD2-57 CD2-58 C02-59 C02-60 . . * NOTES COORDINA TES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 27. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) * INDICATES DATA PER LOUNSBURY AS-BUILT. ALPINE 1. 2. 3. CD UNIT: MODULE: CD20 ALPINE PROJECT CD- 2 WELL CONDUCTORS AS-BUILT LOCATIONS 21 I PART: 2 ps Alaska, Inc. I DRAWING NO: ~ ConocoPhilli 4 REV: 3 OF RTGCI~-ICQ2J- U lJ d\JA~ 05-27-01 CADD FILE NO. 01-02-05- ConocoPhillips Alaska, Inc. ..,-, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 May 26, 2004 ,-,' ~. ConocoPhillips Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-53 Dear Sir or Madam: ,/ Phillips Alaska, Inc. hereby applies for a Permifto Drill an onshore production well from the Alpine CD2 drilling pad. The intended spud date for this well is June 30, 2004. It is intended that Doyon Rig 19 drill the well. .- The well, CD2-53, will be drilled and landed in the Alpine sand horizontally. 7" casing will then be run and cemented in place. The horizontal· section will be drilled with...Q!!.:. based mud using mineral oil as the base fluid. CD2-53 will utilize an Alpine open-hole completion as per the attached diagram. At the end of the work program the well will be shut in awaiting surface connection. Note that it is planned to drill the surface hole without a diverter. There have been 41 wells drilled on CD1 pad and 46 wells drilled on" CD2 pad with no significant indication of gas or shallow gas hydrates. / Please find attached the information required by 20 ACC 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 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser setup which replaces diverter RECEIVE~ MAY 2 8 2004 Alaska Oil & Gas Cons. Commission Anchorage -.--- "-/ If you have any questions or require further information, please contact Vern Johnson or Zane Kuenzler at 265-6081 or 265-1308, respectively. Chip Alvord can also be reached by calling 265-6120. - Sincerely, ~~~/ë4o'l Drilling Engineer Attachments cc: C02-53 Well File / Sharon Allsup Drake Chip Alvord Vern Johnson/Zane Kuenzler Cliff Crabtree Steve Moothart! Jeff Yeaton Nancy Lambert Lanston Chin e-mail: ATO 1530 ATO 1700 A TO 1702/1704 ATO 1768 A TO 1756/1752 Anadarko - Houston Kuukpik Corporation Tommy_ Thompson@anadarko.com e . r"" ""';~;~ON K. ALLSUP-DRAKE ~ CONOCOPHILLlPS ¡¡: ATO 1530 ~ 700GSTREET DATE i'7t(ú..,7 2fXJt.f 62-141311 i ANCHORAGE AK 99501 Ii ~~~~Ò~E.. 9fl1fe of A~It5.~Æ/t4C6cC I $ /00.00 ¡I ---Ck LcLeJ ~¡¡;.s<-J~~c. .... 31~·' ~.. CHASE Chase Manhattan Bank USA, N.A. Valid Up To 5000 Dollars . '", ~-,,,-"","-,".,,,, c;L ///i).1 . 1~~O~~0¡1:&{8"7 19079 2?~,;.~~~4k7k±:_·~ i.~ >;;~ 1055 A S<lCurityFeatu'M OOLLARS l!J ~~~~~ Gael< <.."...,,........_~.,....."""'..,,....,...,..,...,,...,.,,... .' e e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRlA TE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER (!K(~ (!ZJ Z,-ç 3 WELL NAME ;¿é) (I - PTD# ~evelopment Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) 089 Exploration Stratigraphic "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production. should continue to be reponed as a function 'of the original API number. stated above. BOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated In both name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance with 20 MC 25.055~ Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing eueption. (Company Name) assumes the liability of any protest to tbe spacing . exception that may occur. All dry ditcb sample sets submitted to tbe Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample iIitervals througb target zones. Çjb/ ~ ()ð Geologic Commissioner: Date: Engineering Commissioner: ./ IJ/If 35 36 37 38 39 CQnta_ct namelphone_for we~lsly progre!!sreports [expl Y_es Yf3S NA NA NA Appr SFD Date 5/28/2004 _S~¡¡bed _condWoo Sllrvey (if off'-shoœ) S~Lsm[c_an¡¡lysjs_ Qf sbaJlow gasz_ooes_ P~rmit _D_ata_PJeseotec! on pote_ntial oveJpres_s!Jr~zones Vem JohnSQn, CPAI seen in this field. Expected œservojr J>re_SSllre is8<7_ppg EMW; wJII b~drilled wjtb 6.:1 6.8 ppg m!Jd. Geology Appr Date &. 5/28. 12004 þ<~/\f1 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 c_an be LSSlled wlo hydrogen sulfide meaS!Jœs I!! pre!!ence Qf Meçhan[c¡¡Lcoodilionpt H2S g¡¡S probabl~ wells wLthin AOR yerLfied (Fors_ervjc:ew~ only) in _comments) _ChokeJ(1anjfold compJies w/APL RF'-53 (May 84) WQI1s will occur withoytoper¡¡tjon_shlltdQIA'n BOPEs,dp _BOPEpJess they meet r~guJation _test to raiing aPJ>ropriate; (put psig _DJilliOQ flujd_ program sc.h~m¡¡tic_& equip istadequatf3 Adequ¡:¡te .wellboJe sep¡¡ratjo_n_proJ>osed Jfdjv~cter it JequiJed, dQes me~t r~guJations_ Adequ¡:¡tetankage_oJ re_serve pit Jtue-d(ill. has a 10:-403 for ¡;¡bandonme_nt bef30 aPPJoved C_asing designs ¡¡deClyaie fpr C,T, B_&_permafr_ost _CMT vol adequate_ to CMTwill coyer_all koownpro_ductiye bQri¡!:ons known USOW!! _CMT vol adequate_ to çirc!Jtate_on_conductor_ tie-Ln IQng _string tosur:f çsg C.onductor _S_ur:fac~ _c¡¡!!ing protecis all & surfcsg Yes NA _Yf3S No_ No_ Yf3S Yes NA Y_es NA Yes Yf3S Yf3S Yf3S Yes No_ NA 4/29J20M:_1-I2S_npt yet - 1-12S no_t seen_at Alpine. _ Rig iseQyipped wjtb sensors and_ alarms. MAS!=> calc;uJated_at 2549 J>si< 35QOpsI aJ>proprjate_. _ CPAJ u!!ualJyJesJ!! tp _50QO psi. DiYerter waiveJ M¡¡ximllm exp~cted fprmaiion pre!!suœ C02_p_ad _8.7 EMW._ MW pl¡¡nned up to _9<8_ io 6-1/2" bQle and 8,8_ io reservoir. has_ been giyenJor I?rpJ5imLty an¡:¡lysis per{orme_d< Jrayeling cylindeJ plotprovjd~d. Gyros possible. Rig jse_quipped_with stf3eLpjts. No_ rese_rve_pjtJ>lanoed, Wasteto ¡¡PPJQved ¡¡nn!Jlus ordjsposal well, OPen_hole completion planned Annular disp_osal m_ay be propo_sed. 7" wil'-b~ _cemented sufficiently for jsol¡;¡tion, Engineering . Appr 5/28/2004 Date o 11 12 13 14 15 16 17 string PJQvid~d AÇMP findjng.of Consistenc;yhas beeniss!Jed_ forJhis pr.oiect PTD#: 2040890 Administration _S_ufficient Jfdevi¡¡tel _OJ>erator _OJ>~rator ,_ Permit c_an be LSSlled wjtbQut _Permit calJ be issued wjtbQut Can permit Well _All weUs_ within Jl4.mile.area.of review jdf30tified (Fpr servJc:e.well only) Pre-produ_ced injector; dur¡:¡tion.of pre-produc;tion lf3s!! than:3 montbs_ (For_service well QnJy) IQcatf3d within area and_strata _authorized by.lojectioo Order # (put 10# in comments) be approved before admin istrative_ apprp\laJ Leasf3number _appropriate Company CONOCOPHILLlPS ALASKA INC Permit fee attached COLVILLE RIVER, ALPINE OIL -120100 Js. weJlbQre platincJu.ded only affected party ¡;¡cr~ageaYail¡;¡ble .U.niq!Je welln.ame .and ollmb.er .IQcated in.a. d.efined J>ool_ _distance. from driJling unit from otber w~lJs 2 3 4 5 6 7 8 9 Well Well Well in dJiUiog lInJt IQcatf3d prpper .distance_ IQcated proper 15-day wait has.apprppriate.bond inJorce co_nservaiion order b.ound.ary Field & Pool Initial ClasslType Yf3S Yes .Yf3S Yf3S Yes Yes Yf3S Yf3S Yes .Yf3S Yf3S .Y.es Yes .NA .NA NA NA No ¡¡qujfers, .p~r ,11.10 .18A conclusion 3. (For Con_servatioo Ord.er NQ. M3,AJpjn.e.QilPool Mor~ ihan50Q' from e>.cterior boundary of_are_a.established.byCQ 44.3 Well Name: COLVILLE RIV UNIT CD2-53 DEV I PEND GeoArea 890 Unit 50360 Program DEV On/Off Shore On Well bore seg Annular Disposal D D e e 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 Dr~ng Services LIS Scan Utility . cf?~~-o~C¡ l "2.<ø ~ $Revision: 3 $ LisLib $Revision: 4 $ Wed Aug 04 08:27:47 2004 Reel Header Service name............ .LISTPE Date.................... .04/08/04 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.................... .04/08/04 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 Colville River Unit (Alpine) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA CD2-53 501032049400 ConocoPhillips Alaska, Inc. Sperry-Sun Drilling Services 04 -AUG-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003143996 R. KRELL D. BURLEY MWD RUN 5 MW0003143996 M. HANIK D. LUTRICK . "-.- # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2 IlN 4E 2093 1499 52.33 15.90 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.500 6.125 CASING SIZE (IN) 9.625 7.000 DRILLERS DEPTH (FT) 3394.0 12394.0 RECEIVED SEP 0 3 2004 # Alaska Oil & Gas Cons. Commissior Anchorage ·~vl\g VII ex uas LOns. Com" : . r,~ REMARKS: . . 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 - 3 WERE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 4. MWD RUNS 4 AND 5 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AND PRESSURE WHILE DRILLING (PWD). RUN 4 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE. RUN 5 ALSO INCLUDED AT-BIT INCLINATION (ABI). 5. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. 6. MWD RUNS 4 AND 5 REPRESENT WELL CD2-53 WITH API#: 50-103-20494-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 16985'MD/7200'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..04/08/04 Maximum Physical Record..65535 File Type.. . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3357.0 3357.0 3357.0 3357.0 3357.0 3365.5 STOP DEPTH 16926.0 16926.0 16926.0 16926.0 16926.0 16919.0 ROP $ 3402.5- 16985.0 - # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- * BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 4 5 MERGE TOP 3357.0 12406.5 MERGE BASE 12406.5 16984.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing........ ............ .60 .1IN Max frames per record........... ..Undefined Absent value.................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3357 16985 10171 27257 3357 16985 ROP MWD FT/H 0.37 1402.93 173.582 27166 3402.5 16985 GR MWD API 26.86 417.96 96.7315 27108 3365.5 16919 RPX MWD OHMM 0.16 2000 7.60786 27139 3357 16926 RPS MWD OHMM 0.09 2000 7.96315 27139 3357 16926 RPM MWD OHMM 0.06 2000 10.2451 27139 3357 16926 RPD MWD OHMM 0.02 2000 14.9197 27139 3357 16926 FET MWD HOUR 0.16 65.52 0.993657 27139 3357 16926 First Reading For Entire File...... ... .3357 Last Reading For Entire File.... ...... .16985 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/08/04 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.... ...04/08/04 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX FET RPD RPS RPM GR ROP $ 2 . header data for each bit run in separate files. 4 .5000 START DEPTH 3357.0 3357.0 3357.0 3357.0 3357.0 3365.5 3402.5 STOP DEPTH 12361.5 12361.5 12361. 5 12361.5 12361.5 12369.0 12406.5 # 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: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # 10-JUL-04 Insite 66.37 Memory 12407.0 3402.0 12407.0 49.9 80.5 TOOL NUMBER 124725 151812 8.500 3394.0 LSND 9.65 35.0 9.3 250 7.6 1.600 .890 1.700 2.600 80.0 149.0 80.0 80.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION . . (IN) : # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.......... ...... . Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3357 12406.5 7881.75 18100 3357 12406.5 ROP MWD040 FT/H 7.74 406.24 202.972 18009 3402.5 12406.5 GR MWD040 API 44.3 417.96 114.265 18008 3365.5 12369 RPX MWD040 OHMM 0.16 2000 5.81296 18010 3357 12361.5 RPS MWD040 OHMM 0.09 2000 5.82214 18010 3357 12361.5 RPM MWD040 OHMM 0.06 2000 6.19354 18010 3357 12361.5 RPD MWD040 OHMM 0.02 2000 11. 5518 18010 3357 12361. 5 FET MWD040 HOUR 0.16 59.65 0.720149 18010 3357 12361.5 First Reading For Entire File.. .... .,. .3357 Last Reading For Entire File.......... .12406.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..04/08/04 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...... .~08/04 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 3 . header data for each bit run in separate files. 5 .5000 START DEPTH 12362.0 12362.0 12362.0 12362.0 12362.0 12369.5 12407.0 STOP DEPTH 16926.0 16926.0 16926.0 16926.0 16926.0 16919.0 16984.5 # 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: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 16-JUL-04 Insite 66.37 Memory 16985.0 12407.0 16985.0 84.5 95.7 TOOL NUMBER 91360 156401 6.125 12394.0 oil Based 8.40 53.0 .0 44000 3.3 .000 .000 .000 .000 .0 167.0 .0 .0 # . . REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units......... ..Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record.. .......... .Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12362 16984.5 14673.3 9246 12362 16984.5 ROP MWD050 FT/H 0.37 1402.93 115.783 9156 12407 16984.5 GR MWD050 API 26.86 155.24 62.0341 9100 12369.5 16919 RPX MWD050 OHMM 2.26 1487.32 11.1489 9129 12362 16926 RPS MWD050 OHMM 3.14 2000 12.187 9129 12362 16926 RPM MWD050 OHMM 0.65 2000 18.2383 9129 12362 16926 RPD MWD050 OHMM 3.65 2000 21.564 9129 12362 16926 FET MWD050 HOUR 0.31 65.52 1. 53324 9129 12362 16926 First Reading For Entire File......... .12362 Last Reading For Entire File.......... .16984.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .04/08/04 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/08/04 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.............. ..UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name........... ..LISTPE , J Date. . . . . . . . . . . . . . . . . . . . .08/04 . Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.. ............. . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments....... ......... .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
