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208-094
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: 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 8210'feet None feet true vertical 6419'feet None feet Effective Depth measured 7983' feet 7427', 7528'feet true vertical 6204'feet 5686', 5778'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 7482' MD 5736' TVD Packers and SSSV (type, measured and true vertical depth) 7427' MD 7528' MD N/A 5686' TVD 5778' 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: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 77 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker Premier Perm Packer Packer: Baker HDR ZXP Liner Top Packer SSSV: None Shane Germann shane.germann@conocophillips.com (907) 263-4597Senior CTD Engineer 7814-7890' feet 6044-6116' feet 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) 175 Gas-Mcf MD 1215 Size 142' 4113 136456 153 223436 200 measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 208-094 50-103-20575-00-00 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: ADL25570 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2A-26 Plugs Junk measured Length Production Liner 7759' 680' Casing 6028' 4-1/2" 7796' 8208' 6417' 3108' 142'Conductor Surface Intermediate 16' 10-3/4" 101' 3149' 2804' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Anne Prysunka at 8:12 am, Jan 06, 2023 Digitally signed by Shane Germann DN: C=US, O=ConocoPhillips Alaska, CN=Shane Germann, E=shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2023.01.05 15:34:50-09'00' Foxit PDF Editor Version: 12.0.1 Shane Germann DTTMSTART JOBTYP SUMMARYOPS 11/5/2022 RECOMPLETION Move Pits and Office and sub from 2W-11 T/2A-26. Hang tree, stage wellhead equipment in cellar. Spot rig over well. Spot pits to rig. Spot auxiliary equipment. Hook up steam and air to pits. Berm in rig. Complete acceptance checklist. Take initial pressures T/IA/OA. Rig up circ manifold in cellar. Offload 12.0 PPG NaCl into pits. Kill Well . Bridle down, 11/6/2022 RECOMPLETION Continue killing well, install BPV. N/D Tree and adaptor, N/U BOPE, Test BOPEs attempt to pull 3 ½ completion 11/7/2022 RECOMPLETION Rig up E-line and RIH and cut 7500 . Rig down E-line and pull 3 ½ completion. 11/7/2022 SUPPORT OTHER OPERATIONS MAKE CUT IN 3-1/2", 9.3.#, L80 TUBING AT ~7479.7' RKB USING 2" RCT CUTTER, CCL TO CUTTER = 14', CCL STOP = 7467.2'. SUCCESSFUL CUT, RIG GOT PIPE MOVING. JOB IS COMPLETE 11/8/2022 RECOMPLETION Continue lay down completion. Install wear bushing. Make up BHA #1 Overshot. Pick up 7,400 of drill pipe, Engage tubing stub @ 7455'. Attempt to jar seals free. No pipe movement. Release from fish. Pull out of the hole. Lay down BHA #1. 11/9/2022 RECOMPLETION Make up BHA #2 Milling assembly. Run in hole to tubing stub. Mill tubing stub F/ 7454' T/ 7460'. Circulate bottoms up. Pull out of hole laying down drill pipe. Lay down BHA #2. Perform rig repair on top drive link tilt cylinders. Pull wear bushing. Rig up tubing handling equipment. Verify joint count and jewelry running order. 11/10/2022 RECOMPLETION Run 3 ½ completion as per tally. Wash overshot over tubing stub. Verify shear pins released. Fully locate overshot. Pick up space out. Make up hanger and landing joint. Reverse circulated 240 Bbls 12.0 PPG CI Sodium Bromide down IA. Run in hole and land hanger. RILDS. Drop ball and rod. Pressure up set packer. Pressure test tubing T/ 3000 PSI for 30 Min. Pressure test IA T/ 2500 PSI for 30 Min. Shear out SOV. Install H BPV. Test BPV from below T/ 1000 PSI for 10 Min. Nipple down BOP. Set tree test dart. Nipple up adaptor spool and tree. Rig up circ manifold and LRS. Pressure test tree T/ 5000 PSI for 10 Min. Pull tree test dart and BPV. 11/11/2022 RECOMPLETION LRS pump 90 Bbls diesel down IA @ 2 BPM. U-tube well. Secure tree and cellar. RDMO 11/13/2022 SUPPORT OTHER OPERATIONS SHAKE OFF BAITED 2" BELLED RS @ 7400' RKB; PULLED SOV & SET OV @ 7397' RKB; PULLED DV & SET GLV @ 6225' RKB. IN PROGRESS. 11/14/2022 SUPPORT OTHER OPERATIONS PULLED DV & SET GLV @ 2932' RKB; OBTAIN GOOD PT ON TBG; PULLED CATCHER, BALL n' ROD, & RHC PLUG @ 7447' RKB; ATTEMPT TO MEASURE BHP & TAG OBSTRUCTION @ 7498' RKB (GRAB BHP HERE-->3460 PSI); RAN 2.5" BAILER & TAG UP @ 7491' & WORK DOWN TO 7503' (METAL SHAVINGS IN BAILER). TURN OVER TO CTU. 11/14/2022 SUPPORT OTHER OPERATIONS MAKE UP 2.80" TAPERED MILL, OPEN WELL, RIH TO D NIPPLE. JOB IN PROGRESS. 11/15/2022 SUPPORT OTHER OPERATIONS MILL NIPPLE AT 7,512.9' TO 2.80". DRY TAG AT 7,885' RKB. CLEAN DOWN TO 8,111' RKB. RUN 17' X 2.63" DUMMY WHIPSTOCK AND CLEAN DRIFT TO 7,900'. JOB COMPLETE. 11/17/2022 SUPPORT OTHER OPERATIONS PERFORM READ 24-ARM CALIPER LOG OVER INTERVAL 8050' - 7390' PDC (CORRELATED TO K1 MARKER AT 7605' PDC) JOB COMPLETE, READY FOR WHIPSTOCK PENDING CALIPER ANALYSIS 11/18/2022 ACQUIRE DATA (PRE-CTD) ALL TREE VALVE NEGATIVE'S & POSITIVE'S TEST (PASSED) 2A-26 CTD Summary of Operations 11/19/2022 SUPPORT OTHER OPERATIONS SET TOP OF BAKER HUGHES GEN II DELTA WHIPSTOCK 1 DEG ROHS AT 7810.0' PDC, CCL TO TOWS = 14.1', CCL STOP DEPTH = 7795.9' SIGNIFICANT AMOUNT OF METAL SHAVINGS ON EL CCL MAGNETS ONCE BACK AT SURFACE (PICTURE IN ATTACHMENTS) JOB COMPLETE, READY FOR CDR 2A-26 Final CTD Schematic2A-26L1-01 wp03Plan TD @ 10,378' MDLiner Top ~7800' MD3-1/2" Camco X-nipple @ 529' MD (2.813" min ID)3-1/2" 9.3# L-80 EUE 8rd Tubing to surface3-1/2" Camco gas lift mandrels @ 2932', 6226', 7398'Baker Premier Permanent packer @ 7427' MD3-1/2" Camco X-nipple @ 7454' MD (2.813" min ID)Poor Boy overshot @ 7475' MDLiner topBaker HRD ZXP liner top packer @ 7528' MDRS Seal Nipple @ 7547' MD10-3/4" 45.5# L-80 shoe @ 3149' MD7-5/8" 29.7# L-80 shoe @ 7797 MD4-1/2" 12.6# L-80 shoe @ 8208' MDA-sand perfs 7814' - 7890' MDKOP @ 7810' MD3-1/2" x 4-1/2" TTWS16" 62# H-40 shoe @ 142' MDModified by SJG 12/12/20222A-26L1-01 TD @ 10,015' MD2-3/8" slotted liner from TDLiner Top ~7552' MD2A-26L1 TD @ 9662' MD2-3/8" slotted liner from TDTop of liner ~8058' MD By Anne Prysunka at 3:42 pm, Dec 07, 2022 C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\LCF4WGUY\2022-11-17_22509_KRU_2A-26_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 22509 KRU 2A-26 50-103-20575-00 Caliper Survey w/ Log Data 17-Nov-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET,SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM By Meredith Guhl at 9:49 am, Nov 18, 2022 208-094 T37273 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.18 09:49:44 -09'00' 1 Regg, James B (OGC) From:Morales, Tony <Tony.Morales@nabors.com> Sent:Tuesday, November 8, 2022 5:30 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:NSK RWO CM; Hobbs, Greg S; Cozby, Kelly; Henson, James; White, Bradley; Wheeler, Nathan Subject:7ES KRU 2A-26 BOPE Test 11/7/22 Attachments:Nabors 7ES 11-7-22 .xlsx Tony Morales 7ES Rig Manager NABORS ALASKA DRILLING INC. Office 907 670‐6132 Mobil 805 797‐6720 tony.morales@nabors.com ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. 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. KRU 2A-26 PTD 2080940 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:7ES DATE:11/6/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2080940 Sundry #322-576 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:2063 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" T90 P Pit Level Indicators P P #1 Rams 1 3 1/2" x 5 1/2"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 2 7/8' x 5"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate P System Pressure (psi)3000 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1350 P Check Valve 0 NA 200 psi Attained (sec)12 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)109 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):5@2000 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 24 P #1 Rams 7 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0 NA #3 Rams 6 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 11/6/22 1:31AM Waived By Test Start Date/Time:11/6/2022 13:00 (date)(time)Witness Test Finish Date/Time:11/6/2022 18:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Brian Bixby Nabors Test with 3 1/2" jnt. Tony Morales / Paul Yearout ConocoPhillips Mark Adams/Lenward Toussant KRU 2A-26 Test Pressure (psi): tony.morales@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022)2022-1107_BOP_Nabors7ES_KRU_2A-26 J. Regg; 12/5/2022 From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:BOP - Nabors 7ES Date:Monday, December 5, 2022 11:54:51 AM Attachments:2022-1107_BOP_Nabors7ES_KRU_2A-26.pdf KRU 2A-26 (PTD 2080940) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 ! 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1LSSOHaIW0' &$0&200**/9V 7%' [ ; 1LSSOH 6XUIDFH&DVLQJ 3URGXFWLRQ/LQHU &RQGXFWRU $VDQGSHUIV 5.% y ,QWHUPHGLDWH&DVLQJ y zoveo ID 221590 WELL LOG TRANSMITTAL #904301281 To: Alaska Oil and Gas Conservation Comm. December 19, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 DEC, 22 2017 DATA / /201 M K BENDER AOGCC RE: Leak Detect Log with ACX: 2A-26 Run Date: 9/14/2017 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 FRSANC@halliburton.com 2A-26 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-103-20575-00 Leak Detect Log with ACX (Processed Log) 1 Color Log 50-103-20575-00 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. SCANK ) Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: Signed:, ' ✓Q-12 424v % -E:+k: • STATE OF ALASKA • ALA.OIL AND GAS CONSERVATION COMMION ,2-1-1A.t REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate Q Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development E Exploratory❑ 208-094 3.Address: P. O. Box 100360, Anchorage,Alaska Stratigraphic❑ Service❑ 6.API Number: 99510 50-103-20575-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 2A-26 ADL 25570 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: RECEIVED Total Depth measured 8,210 feet Plugs measured None feet true vertical 6,419 feet Junk measured None feet SEP 2 2 2017 Effective Depth measured 8,112 feet Packer measured 7,528 feet AoGesc true vertical 6,326 feet true vertical 5,778 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 101 feet 15 " 142' MD 142 TVD SURFACE 3,108 feet 9 3/4 " 3,149' MD 2804 TVD INTERMEDIATE 7,759 feet 8 7/8 " 7,797' MD 6028 TVD LINER 680 feet 5 7/8" 8,208' MD 6417 TVD Tubing(size,grade,measured and true vertical depth) 3.5" L-80 7,562' MD 5,809'TVD Packers and SSSV(type,measured and true vertical depth) PACKER=HRD ZXP Liner Top Packer 7,528' MD 5,778'TVD SSSV = NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): 7814-7890 SCANNED N O V 0 3 201 , Treatment descriptions including volumes used and final pressure: Total Well-1 Stage,96,937 lbs placed See attached schematc for full FRAC details 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 75 BOPD 36 MSCF/D 270 BBL/D 1200 200 Subsequent to operation: Waiting for Hook-up - - - - 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations CI CA,,.1`0\\\\11 Exploratory ❑ Development ❑ Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data IU GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-326 Contact Name: Sandeep Pedam Authorized Name: Sandeep Contact Email: Sandeep.Pedam@cop.com Authorized Title: Staff Completions Eng! per 11��:^,/'/ " I ill-- Contact Phone: (907)263-4722 Authorized Signature: ��V' IDate: Form 10-404 Revised 4/2017 (a4.07'7 RBDMS i 1 S:? n 1 Submit Original Only RBDMS Irl. Jae 2 5 L�m� �In7 t o/(l/2o 17 0 ,1,,... et. • • 2A-26 DTTM JOBTYP SUMMARYOPS START 8/25/17 DRILLING PERFORMED SINGLE STAGE A-SAND REFRAC WITH 16/20 CARBOLITE AND 25# SUPPORT- XL @ 18-22 BPM PUMP RATE, RAMPING PROP CONC. FROM 1 -4 PPA. EXPENSE REI SCREENED OUT 84 BBLS INTO 4 PPA CONC. TOTAL PROPPANT IN FORMATION = 96,937#(48% OF DESIGN). TOTAL PROPPANT LEFT IN WELLBORE= 10,000#. TOTAL FLUID PUMPED = 1852 BBLS. 8/27/17 DRILLING CLEAN FRAC SAND FROM SURFACE TO A HARD TAG AT 8110'RKB, READY FOR SUPPORT- SLICK LINE EXPENSE REI 8/28/17 DRILLING BRUSH n' FLUSHED TBG &TAGGED TD @ 7983' RKB; SET 2.75" CSV @ 7513' RKB SUPPORT- &OBTAIN GOOD TBG TEST; PULLED DV&SET OV @ 7456' RKB; PULLED DV& EXPENSE REI SET GLV @ 6830' RKB; ATTEMPT TO PT TBG (FAILED), SUSPECTING OV LEAKING. IN PROGRESS. 8/29/17 DRILLING REPLACED OV IN KIND @ 7456' RKB; REPLACED GLV IN KIND @ 6830' RKB; SUPPORT- PULLED DV'S &SET GLV'S @ 5635', 4213', &2619' RKB; ATTEMPT TO TEST TBG & EXPENSE REI FAILED W/COMM TO IA. IN PROGRESS. 8/30/17 DRILLING W/ HOLEFINDER IDENTIFY LEAK IN GLM @ 7456' RKB; PULL OV& REPLACED W/ SUPPORT- HIGH SEAL PKG; ATTEMPT TO PT TBG (FAILED W/COMM TO IA); JOB EXPENSE REI SUSPENDED DUE TO HIGH WINDS. IN PROGRESS. 8/31/17 DRILLING PULLED HS OV&SET DV @ 7456. PT TBG (FAILED W/COMM TO IA); PULLED DV SUPPORT- &SET HS EXT PKG TOP STACK DV @ 7456' RKB. PT TBG W/SAME RESULTS; EXPENSE REI PULLED DV&SET HS EXT PKG DV @ 7456' RKB. PT TBG W/SAME RESULTS W/ IA COMM. W/HOLEFINDER DETERMINE LEAK IN TBG BETWEEN 7512'-7473' RKB. JOB SUSPENDED FOR PLAN FORWARD (2.75" CSV STILL IN HOLE). 9/3/17 ANNCOMM (AC EVAL) : T X IA LLR (4.7 GPM @ 3000 PSI). CMIT-T X IA TO 2500 PSI (PASSED). 9/10/17 ANNCOMM U-TUBE TBG TO IA FOR 120 MIN POST LDL (JOB COMPLETE) 9/14/17 ANNCOMM LEAK DETECT LOG WITH ACX: RIH @ 100FPM TO 7510' RKB FOR BASELINE TEMP, LRS PUMP DIESEL DOWN TUBING TAKING RETURNS OFF IA TO FLOWLINE, MAINTAIN 3000-3100PSI ON TUBING WHILE LOGGING, LEAK RATE CALCULATED AT 4.2GPM, LOG 2 UP PASSES FROM 7510' -7400' RKB @ 20FPM, STATION STOPS RECORDED EVERY 3' FOR 30 SEC BETWEEN 7510' -7486' RKB, MAIN PASS LOGGED UP FROM 7510' RKB TO SURFACE, LEAK OBSERVED AT 7491' RKB, READY FOR CALIPER LOG, JOB IN PROGRESS 9/15/17 ANNCOMM 24 ARM CALIPER LOG: LOG REPEAT PASS UP AT 30FPM OVER INTERVAL 7510' -7350' RKB, LOG MAIN PASS UP AT 30FPM OVER INTERVAL 7510' RKB TO SURFACE 9/20/17 ANNCOMM PULLED EXT PKG DV @ 7456' RKB; PULLED 2.75" CSV @ 7513' RKB; BRUSH n' FLUSHED PATCH INTERVAL FROM 7470'-7513' RKB; ATTEMPT TO DRIFT W/30'X 2.77" DMY PATCH ASSEMBLY& UNABLE TO GET PAST 375' RKB; DRIFT W/ 15'X 2.77" DMY PATCH ASSEMBLY& UNABLE TO GET PAST 365' RKB. IN PROGRESS. 9/21/17 ANNCOMM MADE MULTIPLE DRIFTS TROUBLE SHOOTING TBG RESTRICTION @ 375' RKB (10' DMY PATCH DRIFT WILL PASS& 15' DMY PATCH DRIFT WILL NOT PASS); DRIFT W/DMY 2.75" CA-2 PLUG DOWN TO 7513' RKB (NO OBSTRUCTIONS ENCOUNTERED); SET OV @ 7456' RKB. 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Z 0) KUP •D 2A-26 . Conoco-Phillips 4 Well Attributes Max Angle D TD r5,lask-?Ii1t,.. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) iplps 501032057500 KUPARUK RIVER UNIT PROD 51.97 4,162.40 8210.1 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(k) Rig Release Date DEVIATED-2A-26,9/20/20174:0953 PM SSSV:NIPPLE 75 12/5/2016 Last WO: 44.07 1/22/2009 vertical schernahc(ad* _.. Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .�. Last Tag:RKB 7,983.0 8/28/2017 Rev Reason:TAG,SET CAT SV,GLV CIO 8 pproven 9/5/2017 HANGER;35.6 l :It LEAK-SEE NOTES k Casing Strings Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ft08) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.250 41.0 142.0 142.0 65.00 H-40 WELDED S Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 41.3 3,149.0 2,803.8 45.50 L-80 BTC ly,, ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread INTERMEDIATE 75/8 6.875 37.9 7,796.5 6,027.7 29.70 L-80 Hyd 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread LINER 41/2 3.958 7,527.9 8,208.0 6,416.8 12.60 L-80 BTM Liner Details Nominal ID I j Top(ftKB) Top(TVD((ftKB) Top Incl C) Item Des Com (in) 3 7,527.9 5,777.8 23.68 PACKER BAKER HRD ZXP LINER TOP PACKER w/HD 4.950 I CONDUCTOR;41.0-142.0 7,546.9 5,795.3 23.25 NIPPLE "RS"PACKEROFF SEAL NIPPLE 4.890 7,549.8 5,797.9 23.18 HANGER BAKER FLEX-LOCK LINER HANGER 4.870 NIPPLE:5086 7,561.3 5,808.5 • 22.92 SBE 80-40 SEAL BORE EXTENSION 4.000 7,580.7 5,826.4 22.48 XO Bushing CROSSOVER BUSHING 3.980 Tubing Strings 4 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection GAS LIFT;2,619.4 TUBING 31/2 2.992 35.6 7,580.7 5,826.4 9.30 L-80 EUE-8Rnd-Mod 11, Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 35.6 35.6 0.00 HANGER 3.5"Gen V Tubing Hanger EUE 8rd Mod(Pup It 3.60') 3.500 508.6 507.8 7.30 NIPPLE 3.5"Camco"DS"Nipple(Apparent restriction) 2.875 SURFACE;41.3-3,1400 7,512.9 5,764.1 24.02 NIPPLE 3.5"Camco"D"Nipple w/2.75"profile 2.750 4 7,561.9 5,809.1 22.91 LOCATOR Baker 3.5"Locator 0.0.4.54"I.D.3.99" 3.990 GAS UFT;4,212.6 7,562.4 5,809.5 22.90 SEAL ASSY Baker 80-40 PBR w/Seal Assembly O.D.4.01"I.D.2.99 2.990 ili Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl GAS LIFT;5,834.6 - Top(RKB) (ftKB) (') Des Com Run Date ID(in) 7,513.0 5,764.2 24.02 CAT SV 2.75"CAT SV(45 25"OAL/2.79"NO-GO/1.88" 8/28/2017 1.880 ID/23"DEEP)TO SET IN D-NIP Perforations&Slots Ilit.1 Shot GAS LIFT,6,829.6 Dens Tap(ND) Btm(ND) ti Top(ftKB) Btm(ftKB) (ftKB) (TVD) (R (shots/ (ftKB) Zone Date R) Type Com 7,814.0 7,820.0 6,044.2 6,049.9 A-5,2A-26 5/30/2009 6.0 APERF 2.5"HSD PowerJet HMX,60 deg phase GAS i irr,.956 T - 7,826.0 7,842.0 6,055.5 6,070.6 A-4,2A-26 5/30/2009 6.0 APERF 2.5"HSD PowerJet HMX,60 deg phase IF 7,860.0 7,875.0 6,087.6 6,101.8 A-3,2A-26 2/16/2009 6.0 IPERF 2.5"HOD HJ 2506,RDX, 60 deg phase 7,875.0 7,890.0 6,101.8 6,115.9 A-3,2A-26 5/30/2009 6.0 APERF 2.5"HSD PowerJet NIPPLE;7,512.9 iI®�r. HMX,60 deg phase CAT SV;7,513.0 :LA Stimulations&Treatments Proppant Designed(Ib) Proppant In Formation(Ib) Date 2/21/2009 Stimulations&Treatments Vol Clean Pump • Stg# Top(MB) Btm(ftKB) Date StimlTreat Fluid (bbl) Vol Slurry(bbl) ',� 1 7,860.0 7,875.0 2/21/2009 ff �i Mandrel Inserts It I, St an -� g N Top(ND) Valve Latch Port Size TRO Run t Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (0) (psi) Run Date Com LOCATOR;7,561.8Me 1 2,619.4 2,395.7 Camco MMG 1 1/2 Gas Lift GLV RK 0.188 1,294.0 8/29/2017 SEAL ASSY;7,562.4 2 4,212.6 3,503.6 Camco MMG 11/2 Gas Lift GLV RK 0.188 1,281.0 8/29/2017 3 5,634.6 4,390.2 Camco MMG 1 1/2 Gas Lift GLV RK 0.188 1,277.0 8/29/2017 4 6,829.6 5,172.4 Camco MMG 1 1/2 Gas Lift GLV RK 0.188 1,275.0 8/28/2017 .5 7,456.0 5,712.3 Camco MMG 1 1/2 Gas Lift DMY RK 0.000 0.0 8/31/2017 HS EXT PKG Notes:General&Safety End Date Annotation . 1/27/2009 NOTE:View Schematic w/Alaska Schematic9.0 INTERMEDIATE;37.9-7,798.5 8/18/2012 NOTE:TAG ICE/HYDRATES @ 1497'SLM APERF;7,814.0-7,821.0. 8/31/2017 NOTE:HOLEFINDER DETERMINE LEAK IN TBG BETWEEN 7512'-7473'RKB APERF;7,826.0-7,8420. IPERF;7,860.0-7,875.0 AFRAC;7,880.0 APERF;7,675.0-7,890.0 LINER;7,527.9-8,278.0 • • PrDoq • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Monday, September 25,2017 3:22 PM To: NSK Well Integrity Supv CPF1 and 2 Subject: KRU 2A-26(PTD 208-094) Request for production test with known tubing leak Jan, Approval is granted to conduct a production test(<30 days)on KRU 2A-26. Thanx, SCANNED { I ': Victoria From: NSK Well Integrity Supv CPF1 and 2 [mailto:n1617@conocophillips.com] Sent: Monday,September 25,2017 6:10 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com>; NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Subject:2A-26 Request for production test with known tubing leak Victoria, CPAI is requesting permission to put Kuparuk producer 2A-26(PTD#208-094)online with lift gas for a production test (not to exceed 30 days)with a known tubing leak. Prior to being shut in 1A-22 was averaging 75 BOPD. The well was fracked with 100 M#of proppant and while normalizing the well post frack a tubing leak was discovered. The well is currently unable to be patched due to drift issues and does not meet metrics for a RWO. The frack is believed to have potentially increased the oil rate to 150-200 BOPD which would provide justification for a RWO. The 30 day production test is requested to gather the information needed to determine whether the well will move toward RWO or P&A. The tubing leak was located at 7491' by LDL. Diagnostic testing was performed to prove barriers are in place. Attached is a wellbore schematic and MIT form for the diagnostic CMIT TxIA. Please give us a call if you have any questions or concerns. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 ilit/ELLS TEAM conoaphisps1 • Loepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Monday, September 25, 2017 6:10 AM To: Loepp,Victoria T(DOA) Cc: Senden, R.Tyler; NSK Well Integrity Supv CPF1 and 2 Subject: 2A-26 Request for production test with known tubing leak Attachments: 2A-26.pdf;2A-26 CMIT TxIA 9-3-17.xlsx Follow Up Flag: Follow up Flag Status: Flagged Victoria, CPAI is requesting permissionto put Kuparuk producer 2A-26(PTD#208-094)online with lift gas for a production test (not to exceed 30 days)with a known tubing leak. Prior to being shut in 1A-22 was averaging 75 BOPD. The well was fracked with 100 M#of proppant and while normalizing the well post frack a tubing leak was discovered. The well is currently unable to be patched due to drift issues and does not meet metrics for a RWO. The frack is believed to have potentially increased the oil rate to 150-200 BOPD which would provide justification for a RWO. The 30 day production test is requested to gather the information needed to determine whether the well will move toward RWO or P&A. The tubing leak was located at 7491' by LDL. Diagnostic testing was performed to prove barriers are in place. Attached is a wellbore schematic and MIT form for the diagnostic CMIT TxIA. Please give us a call if you have any questions or concerns. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 491WELLS TEAM Corwcaps 1 • • OP STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reoaAtalaska.gov AOGCC.InsoectorsQlalaska.aov phoebe.brooks2Qalaska.ttov chris.wallace lalaska.aov OPERATOR: CPAI FIELD/UNIT/PAD: KRU DATE: 09/03/17 OPERATOR REP: Paul Duffy AOGCC REP: Well 2A•26 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2080940 Type In) N Tubing 1400 2525 2510 2505 Type Test P Packer TVD 7562 BBL Pump 2.3 IA 1320 2500 2480 2480 Interval 0 Test psi 1891 BBL Return 2.3 OA 150 200 200 200 Result P Notes: CMIT TxIA to prove production casing integrity. Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 MM. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Notes: Welt Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result N9_62: Welt Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Weil Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing I I Type Test t Packer ND -BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer ND BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Cotes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(dexxibe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) 2A-26 CMIT TidA 93-17.xlet KUP PROD II 2A-26 ConocoPhillips6 411V Well Attributes Max Angle&MD TD Alaska,Inc. I WellboreAPllLAM Field Name Waltham Status ncl(") MD(RKB) Act Blm(RKB) co 0000n• nem 501032057500 KUPARUK RIVER UNIT PROD 1 51.97 4,162.40 8210.1 , --- mv_ Comment H25(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date DEVIATED-2A-26,92220178:37:58 AM SSSV:NIPPLE 75 12/5/2016 Last WO: 44.07 1/22/2009 Vertical schematic(actual) Annotation Depth(RKB) End Date Annotation Last Mod By End Date rr'�� Last Tag:RKB 7,983.0 8/28/2017 Rev Reason:PULL CAT SV,GLV C/O pproven 9/22/2017 HANGER:35.6 LST {51 Casing Strings Casing Description OD(in) ID(tri) Top(RKB) Set Depth(RKB) Set Depth(NO)...Wt/Len(I...Grade Top Thmed CONDUCTOR 16 15.250 41.0 142.0 142.0 65.00 14-40 WELDED Casing Description OD(In) ID(in) Top(11KB) Set Depth(RKB) Set Depth(TVD)...-Wt/Len(1...Grade Top Thread .,',SURFACE 103/4 9.950 41.3 3,149.0 2,803.8 45.50 L-80 BTC uau c ec Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)...WI/Len(1...Grade Top Thread INTERMEDIATE 75/8 6.875 37.9 7,796.5 6,027.7 29.70 L-80 Hyd 563 Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)...'WNLen(I...Grade Top Thread LINER 41/2 3.958 7,527.9 8,208.0 6,416.8 12.60 L-80 IBTM Liner Details _ Nominal ID ' Top(RKB) Top(TVD)(RKB) Top Ind(1 Item Des Com (in) 7,527.9 5,777.8 23.68 PACKER BAKER HRD ZXP LINER TOP PACKER w/HD 4.950 ,h�; 7,546.9 5,795.3 23.25 NIPPLE "RS"PACKEROFF SEAL NIPPLE 4.890 CONDUCTOR;41.0-142.0 7,549.8 5,797.9 23.18 HANGER BAKER FLEX-LOCK LINER HANGER 4.870 7,561.3 5,808.5 22.92 SBE 80-40 SEAL BORE EXTENSION 4.000 NIPPLE;508.6 7,580.7 I 5,826.4 22.48 XO Bushing CROSSOVER BUSHING 3.980 Tubing Strings • Tubing Description String Ma...ID(in) Top(RKB) Set Depth(ft..Sot Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 35.6 7,580.7 5,826.4 9.30 L-80 EUE-8Rnd-Mod GAS LIFT;2.8194 Completion Details Nominal ID SURFACE;41.3-3,149.0--., Top(RKB) Top(1VD)(RKB) Top Incl(") Item Des Com (in) 35.6 it. 508.6 7,512.9 50 35.6 0.00 HANGER 3.5"Gen V Tubing Hanger EUE 8rd Mod(Pup(13.80') 3.500 7.8 7.30 NIPPLE 3.5"Cameo"DS"Nipple(Apparent restriction) 2.875 5,764.1 24.02 NIPPLE 3.5"Cameo"D"Nipple w!2.75"profile 2.750 r-7 7,561.9 5,809.1 22.91 LOCATOR Baker 3.5"Locator O.D.4.54"I.D.3.99" 3.990 7,562.4 5,809.5 22.90 SEAL ASSY Baker 80-40 PBR w/Seal Assembly O.D.4.01"I.D.2.99 2.990 GAS LIFT;4,212.6 Perforations&Slots Shot Dene GAS LIFT;5,634.6I c3Ir Top(TVD) Btm(TVD) (shots/f Top(RKB) Bbn(RKB) (RKB) (RKB) Zone Date t) Type Com 7,814.0 7,820.0' 6,044.2 6,049.9 A-5,2A-26 5/30/2009 6.0 APERF 2.5"HSD PowerJet HMX,60 deg phase 7,826.0 7,842.0 6,055.5 6,070.6 A-4,2A-26 5/30/2009 6.0'APERF 2.5"HSD PowerJet --- HMX,60 deg phase GAS LIFT;8,8298Iri; 7,860.0 7,875.0' 6,087.6' 6,101.8 A-3,2A-26 2/16/2009 6.0 IPERF 2.5"HSD HJ 2506,RDX, 60 deg phase 7,875.0 7,890.0 6,101.8 6,115.9 A-3,2A-26 5/30/2009 6.0 APERF 2.5"HSD PowerJet �+ 4 HMX,60 deg phase GAS LIFT;7,456.0_1 Stimulations&Treatments i T Proppant Designed(Ib) Proppant In Formation(Ib) Date 2/21/2009 Stimulations&Treatments �J Vol Clean Pump CA NIPPLE;7,512.9 Stg# Top(ftB) Bbn(RKB) Date StirNrreat Fluid (bbl) Vol Slurry(bbl) 1 7,860.0 7,875.0 2/21/2009 Mandrel inserts St ati on Top(TVD) Valve Latch Port Size TRO Run N Top(RKB) (RKB) Make Model OD(in) Sen Type Type (in) (pd) Run Date Com t 2,619.4 2,395.7 Cameo MMG 1 12 Gas Lift GLV RK 0.188 1,294.0 8/29/2017 -- 2 4,212.6 3,503.6 Cameo MMG 112 Gas Lift GLV RK 0.188 1,281.0 8292017 3 5,634.6 4,390.2 Cameo MMG 112 Gas Lift GLV RK 0.188 1,277.0 8/29/2017 453 6,829.6 5,172.4 Cameo MMG 1 12 Gas Lift GLV RKR 0.188 1,275.0 8/28/2017 LOCATOR;7,561 9 5 7,456.0 5,712.3 Cameo MMG 111 12 Gas Lift OV RK 0.250 0.0 9/21/2017 SEAL ASSY;7,562.4 Notes:General&Safety End Date Annotation 1/27/2009ii NOTE:View Schematic w/Alaska Schematic9.0 8/182012 NOTE:TAG ICE/HYDRATES @ 1497'SLM 8/31/2017 NOTE:HOLEFINDER DETERMINE LEAK IN TBG BETWEEN 7512'-7473'RKB INTERMEDIATE;37.9-7,796.5 + Ilk APERF;7,814.0-7,820.0 APERF;7,826.0-7,842.0--. FRAC;7,860.0 IPERF;7,860.0-7,875.0 APERF;7,875.0-7,890.0 LINER;7,5279-8,208.0 • S Loepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Monday, September 25,2017 6:10 AM To: Loepp,Victoria T(DOA) Cc: Senden, R.Tyler, NSK Well Integrity Supv CPF1 and 2 Subject: 2A-26 Request for production test with known tubing leak Attachments: 2A-26.pdf;2A-26 CMIT TxIA 9-3-17.xlsx Follow Up Flag: Follow up Flag Status: Flagged Victoria, CPAI is requesting permission to put Kuparuk producer 2A-26(PTD#208-094)online with lift gas for a production test (not to exceed 30 days)with a known tubing leak. Prior to being shut in 1A-22 was averaging 75 BOPD. The well was fracked with 100 M#of proppant and while normalizing the well post frack a tubing leak was discovered. The well is currently unable to be patched due to drift issues and does not meet metrics for a RWO. The frack is believed to have potentially increased the oil rate to 150-200 BOPD which would provide justification for a RWO. The 30 day production test is requested to gather the information needed to determine whether the well will move toward RWO or P&A. The tubing leak was located at 7491' by LDL. Diagnostic testing was performed to prove barriers are in place. Attached is a wellbore schematic and MIT form for the diagnostic CMIT TxIA. Please give us a call if you have any questions or concerns. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 41::WELLS TEAM conodaxhNNry 1 1' • • lr ... 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N NNNNN N N L- r-Z- 9 n a, 0) 666666 •a) 7);pp N N N 0 0 0 N N L Q1 O O O O O 0 0 0 0 0 0 0 0i+ O• a) Cm 0r0 C U) )n U) U) U) U) v) N a U 427 w Lnv CO QJ m zco. z m E w , G3 Y Q8 W z LC i= a, n 2 a v 3 a 9 Z Q N O N N N .- O aY+ N N A = ' N Z _1 2 Y 0 0 0 E L• F— a a C — O.. < O N . — e- CO N N N N in z N co '-/ L W C +'' (0 vi0 COD :4 It aL a Q �V OF T�� • • w\��\�y7,..• THE STATE Alaska Oil and Gas �� �-�9a Of T Conservation Commissi®n `--� ALA �� 333 West Seventh Avenue 1y t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �� 0 ,;. � Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Sandeep Pedam 17. Staff Completion woe NOG i 1 20 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2A-26 Permit to Drill Number: 208-094 Sundry Number: 317-326 Dear Mr. Pedam: 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, CgarC—V________ Hollis S. French Chair, Commissioner 4\ DATED this ZC day of July, 2017. RBDMS L L- AUG - 9 2017 f • • STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 1 3 2017 APPLICATION FOR SUNDRY APPROVALS p� 20 AAC 25.280 1A JC 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0• Repair Well 0 Operations shutdown❑ Suspend 0 Perforate ❑ Other Stimulate 9 Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other:❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory 0 Development 9 - 208-094 3.Address: Stratigraphic 0 Service ❑ 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20575-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 2A-26 • Will planned perforations require a spacing exception? Yes 0 No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25570 • Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,210' * 6,419' ' 8112 • 6326 • NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 101' 16 142' 142' Surface 3,108' 10 3/4 3,149' 2,804' Intermediate 7,759' 7 5/8 7,797' 6,028' Liner 680' 4 1/2 8,208' 6,417' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7814-7890 MD 6044-6116 ND 3.500" L-80 7,581' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER =BAKER HRD ZXP LINER TOP PACKER 7528=MD and 5778=ND SSSV: NONE N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 9 Stratigraphic 0 Development 0 ' Service 0 14.Estimated Date for 9/1/2017 15.Well Status after proposed work: Commencing Operations: OIL 0 WINJ ❑ WDSPL ❑ /�"' Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG / t7 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ 7' Op Shutdown 9 Abandoned 9 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Sandeep Pedam Contact Name: Sandeep Pedam Authorized Title: Std Complete _.gine- Contact Email: Sandeep.Pedam@cop.com 167 %— 21 Contact Phone: (907)263-4724 Authorized Signature: f Date: fO Ly 12„.2-(5-1-q- ._ US/ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -317 - 3z14, Plug Integrity ❑ BOP Test 9 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes ❑ No ( 4- Approved AA Spacing Exception Required? Yes ❑ No j Subsequent Form Required: l C l-t "7 RBDMS (�CHUG - 9 2017 APPROVED BY 1'�,p� Approved by: LDCr-cTh,_s__, COMMISSIONER THE COMMISSION Date: CLJ f 1 lc �1 VT!- 7/2c6/<f " ` Submit Form and Form 10-403 Revised 4/2017 O R4G, e�l pic lisvalid for 12 months from the date of approval. Attach Bents in Duplicate���V (Ail/ 7//9/Z�/7 A:a: l,si 7 / . 17 • • RECEIVED NIP" ConocoPhillips JUL 13 2017 Alaska, Inc. AOGCC Paul K.Wharton Staff Landman P.O.Box 100360—Suite ATO 1482 Anchorage,Alaska 99510-0360 Phone(907)263-4076 Fax (907)263-4966 Paul.K.Wharton@conocophillips.com To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 2A-26 Well Kuparuk River Unit, Alaska ADL 25570, KRU Tract 50 Dear Sirs: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the 2A-26 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about June 2, 2017. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well as shown on the attached plat (Exhibit 1). Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request CPAI will provide a complete copy of the Application to you. If you require any additional information, please contact the undersigned. Very truly yours, 6L K. Paul Wharton Staff Landman cc: Lynn Aleshire Rebecca Swensen 2A-26 Hydraulic Fracturing Notice Letter June 1,2017 Page 2 Exhibit 1 ADL025569 ADL025644 2A-01 2A-05 2A-12 2A-01A 2A 13 ADL025570 2A-17 `''2A-23 TI' lel FR.P. - 2A-07 2A-22 �� ?A-02 2A 1/ 2A-21 lit 2A25 �� C) - 2A 27A 2A-20O // ADL025655 2A-19 2A-19A et 2A-06 vs 2A-27 2A-15 2A-10 2A'0 2A-09 2A-04 2A-05 2A-16 9 Frac Points ADL025587 ADL025656 Well Trajectory Well Open IntervalN ConocoPhillips 11.111Half Mile Frac Point Radius Alaska,Inc. _ Half Mile Trajectory Radius A 2A-26 Wells within Trajectory Radius 0 0.2 0.4 0.6 Lease Plat CPAI Leases Miles 5/11/2017 2A-26 Hydraulic Fracturing Notice Letter • June 1, 2017 Page 3 Exhibit 2 Mineral Owners: Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1220 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Erik Keskula, Manager, NS Development Non-Operators: BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. John Dittrich Chevron U.S.A. Inc. 310 K Street, Suite 406 Anchorage, AK 99501 Attention: Mr. Dave White ExxonMobil Alaska Production Inc. P.O. Box 196601 3301 C Street, Suite 400 (Zip 99503) Anchorage, AK 99519-6601 Attention: Mr. Jamie Long Surface Owners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director ADL 417951 North Slope Borough PO Box 69 Barrow, AK 99723 Attention: Planning Department TO THE•ASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Paul K.Wharton Request of ConocoPhillips Alaska, Inc.for ) Hydraulic fracturing for the 2A-26 Well ) under the Provisions of 20AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Paul K.Wharton, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Paul K.Wharton, and I have personal knowledge of the matters set forth herein. 2. I am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 3. Pursuant to 20 AAC 25.283(1)CPAI prepared the attached Notice of Operations("Notice"). 4. On or about June 1, 2017, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners,surface owners,and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 1St day of June, 2017. • I/U-4 f/? Paul K.Wharton STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 1St day of June, 2017, by Paul K.Wharton. Notary Public, State of Alaska My Commission Expires: STATE OF ALASKA NOTARY PUBLIC REBECCA SWENSEN 4 �M Commission Ex es A •.27,2020.i i • Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one- half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1) • Affidavit • • Section 2 - Plat 20 AAC 25.283 (a)(2) Plat 1:Wells within 0.5 miles ADL025569 '< ADL025644 2A-01 2A-08 2A-t2 2A-01A 2A-13 ADL025570 17 2A-23 ` -111 NRp . 8E 2A-07 2A 22 � / ?A 2 2A-14 2A-21 --------------u----2k24 �/2A 2A=25 ���L �. 2A-27A 2A.20 ,/ ADL025655 2A-19 2A-19A 2A-06 ?,9...„„6 2A-27 2A-15 !( IVV 2A-03 2A-09 2A-04 2A-05 2A-1�' • Frac Points ADL025587 A D L025656 Well Trajectory Well Open Interval N ConocoPhillips - Half Mile Frac Point RadiusA Alaska,Inc. MIHalf Mile Trajectory Radius 2A-26 Wells within Trajectory Radius 0 0.2 0.4 0.6 Lease Plat CPAI Leases Miles 5/11/2017 • • Table 1:Wells within a 0.5 miles Wells within 1/2 mile buffer of well track Data from SDE layer: SDE_DATA.AK WELL BOTTOM TD ATDB DD83 API Well Name Well Type Status 501032060400 2A-27 SVC PA 501032002800 2A-06 INJ PA 501032002900 2A-07 INJ PA 501032002300 2A-01 PROD PA 501032002301 2A-01A INJ ACTIVE 501032019200 2A-21 INJ ACTIVE 501032019300 2A-17 PROD ACTIVE 501032019400 2A-23 INJ ACTIVE 501032019500 2A-24 PROD ACTIVE 501032019600 2A-20 INJ ACTIVE 501032019700 2A-19 PROD PA 501032019701 2A-19A PROD ACTIVE 501032060401 2A-27A INJ ACTIVE 501032022000 2A-18 PROD ACTIVE 501032022100 2A-22 PROD ACTIVE 501032002400 2A-02 INJ SUSP 501032002500 2A-03 INJ ACTIVE 501032002600 2A-04 INJ ACTIVE 501032003000 2A-05 PROD ACTIVE 501032003900 2A-13 PROD ACTIVE 501032004000 2A-14 PROD ACTIVE 501032004100 2A-15 PROD ACTIVE 501032004200 2A-16 PROD ACTIVE 501032004900 2A-08 INJ ACTIVE 501032023900 2A-25 PROD ACTIVE 501032005600 2A-10 PROD ACTIVE 501032005700 2A-11 PROD ACTIVE 501032005800 2A-12 PROD ACTIVE 501032005900 2A-09 PROD ACTIVE i i Section 3 - Freshwater Aquifers 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within one-half mile radius of the current or proposed wellbore trajectory. None as per Aquifer Exemption Title 40 CFR 147.102(b)(3), "That portions of the aquifers on the North . Slope described by a 1/4 mile area beyond and lying directly below the Kuparuk River oil and gas producing field". • I Section 4 - Plan for Baseline Water Sampling for Water Wells 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. • • • Section 5 - Detailed Cementing and casing information 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.030(b) and tested in accordance with 20 AAC 25.030 (e) when completed. See Wellbore schematic for casing details. • • Section 6 - Assessment of each casing and cementing operation to be performed to construct or repair the well 20 AAC 25.283(a)(6) Casing &Cement Assessments: The 7-5/8" casing cement pump report on 1/11/2009 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.9 ppg "G" GasBlock cement. Took cement returns to surface. The plug was bumped at 1,150 psi and floats were checked and they held. 2A26 did not see any occurrences of losing while drilling. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successful fractured within design limits. • • Section 7 - Pressure test information and plans to pressure test casing and tubings installed in the well 20 AAC 25.283 (a)(7) 20 AAC 25.283. Hydraulic fracturing (a) Before hydraulic fracturing, the operator must submit an Application for Sundry Approvals (Form 10- 403) under 20 AAC 25.280. Unless modified or altered by pool rules established under 20 AAC 25.520, the application must include (7) pressure test information if available and plans to pressure-test the casings and tubing installed in the well; On 01/26/2009 the 10 3/4"casing was pressure tested to 2500 psi. On 01/26/2009 the 7 5/8" casing was pressure tested to 3000 psi. On 01/26/2009 the 3. " 5 tubing was pressure tested to 2500 psi. It will be tested to 4 689 si prior to the p frac. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 6,578 Annulus pressure during frac 2,500 Annulus PRV setpoint during frac 2,600 Annulus pressure test 2,750 Tubing pressure Test 4,689 Nitrogen PRV 7,078 Highest pump trip 6,878 Table 1: Required Pressures • . Section 8 - Pressure ratings and schematics for the Wellbore, Wellhead, BOPE and Treating head 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collapse 10&%" 45.5 L-80 2,090 psi 3,580 psi 7 &5/8" 29.7 L-80 6,890 psi 4,790 psi 3 &%" 9.3 L-80 10,160 psi 10,540 psi Table 2: Pressure Ratings • • Stimulation Surface Rig-Up C, v 7 y ('7 Breed!Tattle Tate Tank Mi w � Iy 1 19 11 a ti+ za U Mil r_ 0000 C, e = N ~ maley 004 h 1":1`i I dwnd U Fs -3ff Tank Pp_Cm t, rk 0.14 Pump Truck a r. vca 1 .: H J C J V .g2.3 g Fra::Furlp -{ —" ►* Frac Pump Frac Pump fr) M: • -4 Frac Pump Frac Pump ` Ma: t Fr.] Frac Pump • • Tree Saver With Wellhead it.OIL sr PROPOSAL: Ilig Energy Services (Canada) Inc. QUOTE#: DATE: Maximum Allowable Pumping Rates SIZE ID OD RATE m'Irnin CSG 2.250 3.750 10 n'i/min 3 1/2" Big Bore 1.750 2.750 6 msimin 2 7/8"&3 112" 1.438 2.360 4 m3/min 2 3/8" 1.000 1.900 2 n'/rein 31/16&41/16 with tapered mandrel 2.750 4.000 15 m'/m in , d 1/16 X Tool Mandrel 3.610 4.750 24 m3Imin Orerd f'osiiaoi CLOSED POSITION ww,t onn" i� r-r .�+wrr+,4At1 rr ...... .s f7)LSrt ? f�. +i _. 1 ' illi IROVIII INFIVIII0 fp,Q .rSe z 3 1 � „ 1 .j ilTi r1 t ON N OCI 6 Vaso o / P� �1 �Y1kl vAkt 0046 t lM s. !, E YAY1)il + ItA 44.41/110t0.1 1111 www.osescanada.com Tree Saver Rating: 15,000 psi 0 • Wellbore schematic /'- '1, KUP PROD 2A-26 ConocoPhillips I tar f l 1 3: 'wbr sits. rix a&v TD A.ibc.anv« It Miss rely Iv61 ser.,Ilse, :.":C5:Y3G ..Y r. :I.T.:- i' $L�4 ♦'.5:'i. 52131 .-�._ omMa..; �- 14�„ �t.e. S..,tl15p l�harm� 33 2.73,} + .7 511Writ .nom Y .i.. 443 I.=MP *RAW..:re 3129 12. 12.1 12.23,197 2 I`e. Me Fa'c" ISM 1n .,: . 2.31 Iti.11 a-^rc..w-ee, r I I 2 2 1 '25.5 Et fa . U c12U SI "Js 1.2C +t-0d Ntf53L' . Cimie.N.14caan .1n1 1U12 12 1.3 2.2 34„IllYl 144 42.44 133047..,3E+1m 92443e toss TT.. tans29022 L 73`94 U. 11 3 13.'C 2 3. H 40`W 2..471 S C 9.630 masa.., ..t1MI 191.i ':l'sal U4 aosttUaa 'i.e NO.ITL;......f.Wa.. '232 973140 N'LIIOLAA4'L 1304 5 073'2 1114S 2 VC_ It lU +It;'0115 Itut.prr Wa ........1; It I attOZi 2•30.2.t11429 2010,0 Nh *0.4.1.2333 Rrarc ..N1 It 1147; 3MS 7 23:''A H21156 04'45 7Ter:.46 910 ISM DAM sas ... + TM ilia Ta 12 7112 Ti; apn Da CxLI . ' ,'.h: 11;10 2 ES i'M" Edp1R MrJ J"^4KIo Y 1 ,A,11.AAwA.nnsAn.ne..+r1Nt9 1`47.11 3925 21.1' 1722- .792.tl3Y SLA.11 rytc � ,4W gg.yu'. �..1..-\ 1'2011 5 3.'^. 3130>1.Wt:A:M Ei141..H1 L.Y.C.,,..tkie,141.1 I. Bi 1 r 7113 0 LP1.1 .295 2140 20.11142.CURL LAI 11CCN {LNC 5.+11.1011 ,''6�y''y�.L*0til'- 011)14 .'141±,,......3; .:4,-,,1NL11 ti.111N' 9 aO:' I. Strilgs : aT+�>. ::., I14 4 Vs'.IC.1-. -I 3302,) S tsar R-.I f. M,Y 90'9 telt iI .I.t,9 II 2331i 2:.3035.. rietlon Dena . Win G Tm 0....., xf Tt r+1.ar :.ct'f Sart. IC `AS f 111 ,.:C 1.1142021 ..3'2.044.0 I bNA 73430 77.2 141 11231 19 00 R 1191 3511' 1404 146 1 ;50 45 Mt 1r idirtcsate:Ids.slossTpuntrisvddrekfil 2011 1119 1 324 411 34111.0 .2"L.nav 2T 040202,2 93:270274 2:.M. UIYIaYt.414e.-I !VS, 1 222 :.UI2.9243wi 0*01"Lwa4'UO 431'1 L'.3.W 3211 ■ '1154 tN... ...._ 000},0.c..1 31.4.0 224.1317223239334 .100 03441 I ll 23'0 208:. _Parrlastfone&slats a.. : `a trot Inn 121.1 r.:..rq l iw1,+1'RR>w, IIE r'. 6.61 1.r...to 154 rM.al lata Ca 4 Try. ECM _ _1.l'' 0UM2 92031 A-. .4:0 1A:.V3R+ 2.RPM '.'nSL I'0w141 . 3841 I%OM p'8.. I . .1 511162 SWTI B tae.A-.! 1p140131 6p Ale. :3'eeDP:weial 11917 AC.01a2a1.. ■ _4.. 0UH;1 05310 141 37.70 311149323 0'7039 12'.S09_:130 03' *301 sm. A 22 Mg sham 12.. 511131 33.1-I;R 2 -to 1441171 A 15 1'40.33.'xl ■ `l Strrai2Yx15&-rsatrn R:B 6601.23t,a.,.: ,v, I>e'rl..r.»-..w,l.l IL*. 0000 StO13J306n&&iY tints 0410266 1234. S- N. '1411035-I at IMJ'f;l:f.L Vha. I 12,,.4.i...2I•a:1)11, 1,4 xeL"'r m: Mandrel Inserts ir T•zI 101,4, 3snw61 ,1.0 • Me. 22 rii+ r-„+ a 1.1 Yet Aar Om Can 31100 t 1221 u'S2X5 1_1 4 1.moi! 4 f4W: 11 . ir. U IHR AU C"7'5:0:1 302.323-302.323- I1 'A 131:.i dr: UIIIS „2 2. .1.A:5 UI2 t 3363 1.115:5 Ore _ 7. ,. NYu i 1 I,Its, CY 9t, 2.3 UL 392.1.349=5 NOM:General&Safety 3.211*72327 GE taw 47;3324:3 1410..3151,111 ef.'r.'.U'.tl NOt2 Mons 502e32•4:20 1*0*.lrin..:;. 11461112 44011.113 9:0.1232121211E12 C 51€'14 1 I ILwx9331227.3e14 Its SXa Al 0000. ...zsrat+-- vas.ttsTb..2aa • • Section 9 - Data for Fracturing zone and confining zones 20 AAC 25.283(a)(9) CPAI has formed the opinion based on seismic, well and other subsurface information currently available that: The Kuparuk interval is approximately 242'TVD thick, with the top and base picked at 7,695'MD/5,800'TVDSS and 7,952'MD/6,042'TVDSS, respectively. The Kuparuk Interval is composed of fine-grained sandstones, siltstones and shale interbeds. The estimated fracture gradient for the Kuparuk interval is 12.5ppg. The overlying confining zone consists of greater than 325'TVD of Lower Kalubik, Upper Kalubik and HRZ mudstones. The fracture gradient for each of these zones is estimated to be 15ppg, 15ppg and 16ppg respectively. The top of the HRZ was encountered at at 7,336'MD/5,471'TVDSS. The underlying confinement zone consists of greater than 200'TVD of mudstones comprising the Miluveach Shale. 2A-26 does not intersect the Miluveach shale. The Top Miluveach was encountered at 7,952' MD/6,042'TVDSS—the Base Miluveach was no encountered. The estimated fracture gradient for the Miluveach Shale is 15-18ppg with fracture gradient increasing with depth. Stress orientation in 2A-26 is interpreted to be approximately North-South and we expected the -/ fractures to propagate parallel to this maximum stress direction. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. • • Section 10 - Location, Orientation and a Report on Mechanical Condition of Each Well that may Transect Confining Zone 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on the following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within one-half mile radius of the proposed wellbore trajectory. Casing&Cement assessments for all wells that transect the confining zone: Original 2A-15:The 7" casing cement report on 8/4/1985 shows that the job was pumped as designed, but a squeeze job was required. Squeeze was successful, indicating competent cementing operations.The cement job was pumped with 15.8 ppg cement class G. Full Returns were seen throughout the job.The plug bumped at 3000 psi, and the floats were checked and they held. 2A-03:The 7" casing cement report on 6/16/1984 shows that the job was pumped as designed, but CBL showed cement was bad so a squeeze job was required. Squeeze was successful, indicating competent cementing operations.The cement job was pumped with 15.8 ppg cement class G. PTD 1840510 2A-16:The 7" casing cement report on 8/15/1985 shows that the job was pumped as designed, indicating competent cementing operations.The cement job was pumped with 15.8 ppg cement class G. Full Returns were seen throughout the job.The plug bumped at 3000 psi, and the floats were checked and they held. PTD 1851470 RWO All three wells have had a RWO cementing the casing.The RWO cement jobs are summarized below. 2A-15:The 7" casing cement report on 6/3/2011 shows that the job was pumped as designed, indicating competent cementing operations.The cement job was pumped with 15.7 ppg cement. Good Returns were seen throughout the job.The plug bumped at 2200 psi. 2A-03:The 7" casing cement report on 9/9/2014 shows that the job was pumped as designed indicating competent cement.The cement job was pumped with 15.7 ppg cement. Cement observed at surface. Plugs bumped to 2450 PSI. • • 2A-16:The 7" casing cement report on 3/15/2010 shows that the job was pumped as designed.The cement job was pumped with 15.4 ppg ARCTICSET cement. No Returns were seen throughout the job. The plug bumped at 2495 psi.Verified plug holding. • • Hi Hi >••• O 0 1/40 HI VI c.1 L Ln HI O by .-I N m .E IJ - r1 c0 CO -0 N -0 ai N U_ N C (N/) 0. V) in CO CO CO CO CO Q Q Q Q o_ H a) U F- LL U- 00 C �r 0 C rn o dr 1 O Ln = Lfl W 0 = Lr) m - Lfl N CC v, H Hi cn -0 HI ca = CO HI U 0 C 4- a) "- U o -o c 4- U LL 00 4- 1- Z o +, 0 o , a, a, o v o 0 0 • +' CO (7 L HI v) CC C NN C O O N (7 C v) 'A cC C v) NO a) E sa , -0 \ _Q Q a) \ a) U N a1 i N < a) _ v 0A O aA rn > _Q co E aA a) o_ 7 Q 0 Ln Q U 0 V) o0 0_ (3 0o N a U m U .1 rn cc oNo 0... 0 .N-+ N 0. 0 - m coo 0 +� O CO 0 4 ..... v v +' 0 +� O +� C co co co co o +-, 4- 9— C � L2 OAC ' " � C2 � � c c—° O a) bEL-) uN QEo� um '� E N 0Ln Eou � O 0 O a) N co Ln 0 a) CO co co a) 0 corn <1.) 0 (13I,- N v) I- u l0 0_ N I- U Hi Q LD U U a-+ 0_ O U -1 D_ Ln L L L. L 0 0 0 0 4- 4- 9- 4- C C C i O N 0 cp O o O }, 0 C O '4, 0 , L u C O U Co C C a.., C C QJ 4- a) 0 a) U a) 7:3 a) O ✓ CO o O 0- • Q O Q O CC ) O 0_ 0 .E O O o 'O a) 'O -o C a) a) 4-, +, 4- C E n3 to O a) 5 = Q E V J J U o a) a) >- co oo m co F- U '0 0 U U U U 0 0 c0 O dr 0 Ln c-1 O O a) C CO O i0) Ou CO NN o v o o .O o 0 0 .O ,� O E o L\n O Q E Ln o a) N CO in 0000 Hi ' c U) � 0 Hi m -- F- U L0 l0 O L0 Hi c)..) LL cc N O 00 V) 1/40 0' CO CC 0 O Ln M N Ol N N N LP) Q O Ol M M M Ol O co Ln N n (0 LLn N • 0_ L) O1 Lf) b0 C 'N a) CO .N U cn N N in IA In o co O •_ O 0_ O N d d a) 1/40 ['n L!1 l0 v E N O r1 co Q Q Q Q Z N N N N • • Section 11 - Location of, Orientation of and Geological Data for Faults and Fractures that may Transect the Confining Zones 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic,well and other subsurface information currently available that there are 4 mappable faults transecting the Kuparuk interval with a %2 mile radius of the frac point, however,the wellbore itself doesn't intersect any of these faults. All four faults transect the v entire Kuparuk interval and terminate in the in the overlying and underlying confining layers. Fault#1 DTS 28' throw Fault#2 DTS 31'throw Fault#3 DTE 20'throw Fault#4 DTE 23'throw • • Plat 2: 2A-26 Fault Analysis ADL025569 ADL025644 ADL025570 2A ADL025655 •1/4 414111 2A-15 2A-03 116110 2A-04 • • Frac Points Well Trajectory ADL025587 ADL025656 Well Open Interval _ Half Mile Frac Point Radius N ConocoPhillips L, Half Mile Trajectory Radius Alaska,Inc. Faults within Frac Point Radius 2A-26 - Wells within Frac Point Radius 0 0.2 0.4 0.6 Frac Plat CPAI Leases Miles 5/11/2017 • • Section 12 - Proposed Hydraulic Fracturing Program 20 AAC 25.283(a)(12) 2A-26 was completed in 2009 as horizontal producer in the Kuparuk A sand formation. The well was completed with 3.5" tubing and a 4.5" liner with perforations. A single stage frac will be pumped through the perforations. Proposed Procedure: Halliburton Pumping Services: (A Sand Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 6 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 2,677 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU HES Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 120 bbl breakdown stage (25# linear gel) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 18 BPM as quick as possible, pressure permitting. Increase annulus pressure to 2,500 psi. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule with a maximum expected treating pressure of 6,578 psi. • • Section 13 - Post-Fracture Wellbore Cleanup and Fluid Recovery Plan 20 AAC 25.283(a)(13) Flowback will be initiated through a third party flowback vendor until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) > KUP PROD 2A-26 ConocoPhillips ° Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status ncl(`) MD(ftKB) Act Btm(ftKB) ,._no c iltcs. 501032057500 KUPARUK RIVER UNIT PROD 51.97 4,162.40 8,210.1 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date DEVIATED-2A-26,5/7120171:34:14 PM SSSV:NIPPLE 75 12/5/2016 Last WO: 44.07 1/22/2009 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 7,917.0 5/6/2017 Rev Reason:H2S,TAG pproven 5/7/2017 *I. L•. , Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.250 41.0 142.0 142.0 65.00 H-40 WELDED OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 41.3 3,149.0 2,803.8 45.50 L-80 BTC LW Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(IVO)...Wt./Len(I...Grade Top Thread INTERMEDIATE 7 5/8 6.875 37.9 7,796.5 6,027.7 29.70 L-80 Hyd 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WELen(I...Grade Top Thread LINER 41/2 3.958 7,527.9 8,208.0 6,416.8 12.60 L-80 IBTM Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 7,527.9 5,777.8 23.68 PACKER BAKER HRD ZXP LINER TOP PACKER w/HD 4.950 j' 7,546.9 5,795.3 23.25 NIPPLE "RS"PACKEROFF SEAL NIPPLE 4.890 CONDUCTOR;41.0-142.0 7,549.8 5,797.9 23.18 HANGER BAKER FLEX-LOCK LINER HANGER 4.870 7,561.3 5,808.5 22.92 SBE 80-40 SEAL BORE EXTENSION 4.000 NIPPLE;588.8 7,580.7 5.826.4 22.48 XO Bushing CROSSOVER BUSHING 3.980 •__ Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 35.6 7,580.7 5,826.4 9.30 L-80 EUE-8Rnd-Mod GAS LIFT;2,619.4 dE Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl 7) Item Des Com (in) 35.6 35.6 0.00 HANGER 3.5"Gen V Tubing Hanger EUE 8rd Mod(Pup jt 3.60') 3.500 508.6 507.8 7.30 NIPPLE 3.5"Camco"DS"Nipple(Apparent restriction) 2.875 7,512.9 5,764.1 24.02 NIPPLE 3.5"Camco"D"Nipple w/2.75"profile 2.750 SURFACE;41.3-3,149.0-v 7,561.9 5,809.1 22.91 LOCATOR Baker 3.5"Locator O.D.4.54"I.D.3.99" 3.990 7,562.4 5,809.5 22.90 SEAL ASSY Baker 80-40 PER w/Seat Assembly O.D.4.01"I.D.2.99 2.990 GAS LIFT;4,212.6 air Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/f GAS LIFT;5,834.6 Top(ftKB) Btm(ftKB) (RKB) (ftKB) Zone Date t) Type Com 7,814.0 7,820.0 6,044.2 6,049.9 A-5,2A-26 5/30/2009 6.0 APERF 2.5"HSD PowerJet HMX,60 deg phase 7,826.0 7,842.0 6,055.5 6,070.6 A-4,2A-26 5/30/2009 6.0 APERF 2.5"HSD PowerJet HMX,60 deg phase 7,860.0 7,875.0 6,087.6 6,101.8 A-3,2A-26 2/16/2009 6.0 IPERF 2.5"HSD HJ 2506,RDX, GAS LIFT;6.629 6 60 deg phase 7,875.0 7,890.0 6,101.8 6,115.9 A-3,2A-26 5/30/2009 6.0 APERF 2.5"HSD PowerJet HMX,60 deg phase Stimulations&Treatments GAS LIFT;7,456.0 Proppant Designed(Ib) Proppant In Formation(Ib) Date 2/21/2009 I Stimulations&Treatments Vol Clean Pump Stg# Any(ftKB) Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) NIPPLE;7,512.9 = 1 7,860.0 7,875.0 2/21/2009 Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sent Type Type (in) (psi) Run Date Com 1 2,619.4 2,395.7 Cameo MMG 11/2 Gas Lift GLV RK 0.188 1,288.0 2/25/2009 I I 2 4,212.6 3,503.6 Camco MMG 11/2 Gas Lift GLV RKmco 0.188 1,269.0 2/25/2009 1! fl 3 5,634.6 4,390.2 CaMMG 1 1/2 Gas Lift GLV RK 0.188 1,252.0 2/25/2009 ' 4 6,829.6 5,172.4 Camco MMG 1 1/2 Gas Lift GLV RK 0.188 1,235.0 2/25/2009 5 7,456.0 5.712.3 Cameo MMG 1 1/2 Gas Lift OV RK 0.250 0.0 3/30/2009 Notes:General&Safety LOCATOR;7,561.9 _ End Date Annotation SEAL ASSY;7,562.4 - 1/27/2009 NOTE:View Schematic w/Alaska Schematic9.0 8/18/2012 NOTE:TAG ICE/HYDRATES @ 1497'SLM INTERMEDIATE;37.9-7,798.5A I APERF;7,814.0-7,820.0- APERF;7,826.0-7,842.0- FRAC;7,860.0 (PERF;7,860.0-7,875.0 II 1 APERF;7,875.0-7,890.0 LINER;7,527.9-8,208.0 IN 'Q N n ! ,54-16 E o o\ .- 0 o n o .. \ u E .n ry ,1 ,2,1 ,1 ,'1 ,M1 LL - o Q- o a p p 0 wQO G m 4 '^ O O O O O O o o m '1, ---9 ,', \m m C 3 & ry ry ry ry ry ry ry ry ry ry 3 ry 3 a 8 \,o E o 5 a O 5 q O n m \ a o 0 o 0 0 0 0 0 0 0 u , u " IS' m °.:15.''- 1 °,1H1 m m m m m '^" \ N E n a J O a o 0 0 0 0 °a,$ a o 0 Q U U C n p \ Q ` 0 0 0 0 0 0 0 0 O o O 0 n O N N .y N N ti N H �r t - i t a o 0 O E NF Z E _ _T -_ o . 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S E u j u m u a ccL W d -17 N cu oj -L Q 0 CD cD rn Lo 00 v v o in co co +� +� Li) d E Z ti 00 ^ z r r ,- 0 O O N O O N ++ E v (4 = a Q eQ N w ❑ ❑ W W ❑ N N M N a N Z v r6 C V) Y C v c CO vrts 0 y a 4 1-- a a 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 b direct inspection of the file. ~D~ - D ~` 4 Well History File Identifier Organizing (done) RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: gY: Maria Project Proofing gY: Maria Scanning Preparation BY: Maria Production Scanning lsl /s/ _ ~ x 30 = _~_ + ~S =TOTAL PAGES (Count does not include cover sheet) Date: ~s~ III II'lllllll) VIII Stage 1 Page Count from Scanned File: ~~!% (Count does include cov r sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~/!D ~s~ ~ p ~// Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ IIIIIIII nnin is com lete at this Dint unless rescanning is required. II I II'I II I I Sca g p p ReScanned III IIIIIIIIIII VIII gY: Maria Date: ~s~ Qualit Checked ~IIII~IIIIIIII'llll Comments about this file: y IIIIINpllllllllll o aew~~,.e~ IIIIIIIIIIIIHIIII DIGITAL DATA OVERSIZED (Scannable) ^ Diskettes, No. ^ Maps: ^ Other, No/Type: , p~Other Items Scannable by V a Large Scanner ~p (ryl p~j D ~.-©G'~ OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: Date: Date: P 10/6/2005 Well History File Cover Page doc DATA SUBMITTAL COMPLIANCE REPORT 6/23/2010 Permit to Drill 2080940 Well Name/No. KUPARUK RIV UNIT 2A-26 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20575-00-00 MD 8210 TVD 6419 Completion Date 1/22/2009 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Ye DATAINFORMATgN Types Electric or Other Logs Run: GR/RES, USIT, CNL, Sonic (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type ed/Frmt Number Name ~caie nneaia No Start Stop cH tzecervea comments g Cement Evaluation 5 Col 6700 7770 Case 1/28/2009 Sonic Scanner, Compressional, Shear, CBL 15-Jan-2009 ~~ C Pds ~ 17510l.~Cement Evaluation 6700 7770 Case 1/28/2009 Sonic Scanner, Compressional, Shear, CBL 15-Jan-2009 g Induction/Resistivity 5 Blu 7380 7780 Open 1/28/2009 SFRT, GR 17-Jan-2009 b C Pds 17511 ~uction/Resistivity 7380 7780 Open 1/28!2009 Slim Formation Resistivy Tool, GR 17-Jan-2009 Cement Evaluation 5 Col 100 7775 Case 2/13/2009 USIT, CCL 16-Jan-2009 ED C Pds 17580 moment Evaluation 100 7775 Case 2/13/2009 USIT, CCL 16-Jan-2009 g Induction/Resistivity 2 Blu 7805 8060 Case 2/23/2009 SFRT, Cased Hole C Pds 17610 'Induction/Resistivity 7805 8060 Case 2/23/2009 Resisitivity 14-Feb-2009 Slim Formation Resistivity ~ Tool, Cased Hole Resisitivity 14-Feb-2009 g Perforation 5 Blu 7450 7920 Case 3/11/2009 Perf Rec, SBHPS 16-Feb- 2009 e ~ C Pds 17667 P rforation 7450 7920 Case 3/11/2009 Perf Rec, SBHPS 16-Feb- 2009 pt Report: Final Well R 0 0 Open 3/11/2009 Final Well Report, Tab of Cont, Equip and Crew, Well Data, Geo Data, Drill Data, Daily Reps DATA SUBMITTAL COMPLIANCE REPORT 6/23/2010 Permit to Drill 2080940 Well Name/No. KUPARUK RIV UNIT 2A-26 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20575-00-00 Mu 2SZ7U iw 641~J l:OmpletlOn UaLe "IlZZlZUUy l:OmpleilOn JialUS l-VIL ~.urrem acacus i-vim uw rv D C 17692 eport: Final Well R 0 0 Open 3/11/2009 Final Well Report, Tab of Cont, Equip and Crew, WeII Data, Geo Data, Drill Data, Daily Reps ~ Yog Mud Log 2 Col 801 8210 Open 3/11/2009 TVD Formation Log og~ Mud Log 2 Col 801 8210 Open 3/11/2009 MD Formation Log eCog Mud Log 2 Col 801 8210 Open 3/11/2009 TVD MWD Combo Log ~! Log Mud Log 2 Col 801 8210 Open 3/11/2009 MD MWD Combo Log gg Mud Log 2 Col 801 8210 Open 3/11/2009 TVD Drilling Dynamics ~ 'Cog Mud Log 2 Col 801 8210 Open 3/11/2009 MD Drilling Dynamics ` `Log Mud Log 2 Col 801 8210 Open 3/11!2009 ND Gas Ratio og Mud Log 2 Col 801 8210 Open 3/11/2009 MD Gas Ratio t LIS Verification 173 8160 Open 3/19/2009 LIS Veri, GR, RPD, FET, RPX, RPS, RPM, ROP, NPHI, DRHO, NCNT, RHOB, FCNT, PEF, DCT, SCRA ~ ~ C Lis 17704 "Induction/Resistivity 173 8160 Open 3/19/2009 g Induction/Resistivity 25 Col 112 8210 Open 3/19/2009 MD DGR, EWR, CTN, ALD, BAT 18-Jan-2009 ~ ~ 'Cog Induction/Resistivity 25 Col 112 6418 Open 3/19/2009 TVD EWR, CTN, ALD, BAT 18-Jan-2009 og Induction/Resistivity 25 Col 112 8210 Open 3/19/2009 MD DGR, EWR, CTN, ALD, 18-Jan-2009 ~o§ Induction/Resistivity 25 Col 112 6418 Open 3/19/2009 TVD EWR, CTN, ALD, 18- Jan-2009 ED C Lis 17748 'Induction/Resistivity 6623 8153 Case 3/20/2009 LIS Veri, plus graphics Dept, GR, Tens, CCL, DRHO, RHOB, NRAT, NPHI, NCNT L Induction/Resistivity 2 Blu 7380 8060 Open 3/20/2009 SFRT w/GR 14-Feb-2009 og Induction/Resistivity 5 Blu 7380 8060 Open 3/20/2009 SFRT w/GR 14-Feb-2009 • DATA SUBMITTAL COMPLIANCE REPORT 6/23/2010 Permit to Drill 2080940 Well Name/No. KUPARUK RIV UNIT 2A-26 Operator CONOCOPHILLIPS ALASKA INC MD 8210 TVD 6419 Completion Date 1/22/2009 Completion Status 1-OIL Current Status 1-OIL API No. 50-103-20575-00-00 UIC N ' g Sonic 2 Blu 6700 7770 Case 3/20/2009 Sonic Scan, Compres, Shear, CBL 16-Jan-2009 og Sonic 5 Blu 6700 7770 Case 3/20/2009 Sonic Scan, Compres, Shear, CBL 16-Jan-2009 g Density 5 Blu 7260 7806 Open 3/20/2009 Plat Express, Neut, Dens, g Por w/GR 16-Jan-2009 Lo Neutron 2 Blu 7260 7806 Open 3/20/2009 Plat Express, Neut, Dens, Por w/GR 16-Jan-2009 pt 17854 Corrosion 0 7583 Case 4/14/2009 Mem Multi Finger Caliper Log Results Summ w/3D PDS graphics C 17854~rrosion 0 7583 Case 4/14/2009 Mem Multi Finger Caliper Log Results Summ w/3D PDS graphics --C 17705 iFrfduction/Resistivity 112 8210 Open Graphics EWR-4, CTN, ALD, ROP pdf, emf, & cgm formats Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? ~~/ ,N~ Chips Received? ~f-AL Formation Tops Analysis ~- Received? • !I Comments: DATA SUBMITTAL COMPLIANCE REPORT 6123/2010 Permit to Drill 2080940 Well Name/No. KUPARUK RIV UNIT 2A-26 MD 8210 TVD 6419 ompletion Date 1/22/2009 Compliance Reviewed By: _ 7 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20575-00-00 Completion Status 1-OIL Current Status 1-OIL UIC N Date: ~ ~ ~ ~+--- ~,--~~ ~ (~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 1St, 2010 o1,~g y ~~"~ Mr. Guy Schwartz Alaska Oil & Gas Commission - 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Guy Schwartz: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRil). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped November 10th, 20th and 24th, 2009. The corrosion inhibitor/sealant was pumped December 29th and 30th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10~L04) Kuparuk Field Date 01/01/10 ~ Pad 2A. 2C. 2D ~ 3K Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2A-26 50103205750000 2080940 12" Na 12" n/a 4.25 12/30/2009 2A-27 50103206040000 2091070 36" Na 36" n/a 12.75 12/30/2009 2C-14 50029212260000 1842100 18' 2.5 50" 11/20/2009 12.32 12/30/2009 2C-15 50029212190000 1842030 SF n/a 26" n/a 4.67 12!30/2009 2C-16 50029212180000 1842020 SF n/a 33" n/a 7.22 12/30/2009 2D-02 50029211770000 1841520 SF n/a 24" n/a 4.45 12/30/2009 2D-03 50029211780000 1841530 SF n/a 24" Na 4.67 12/30/2009 2D-04 50029211760000 1841510 SF n/a 24" n/a 4.45 12/30/2009 2A-05 50029211570000 1841260 SF n/a 24" n/a 4.45 12/30/2009 2D-08 50029211580000 1841270 SF n/a 28" n/a 4.67 12/30/2009 2D-13 50029210700000 1840120 21' 3.0 27" 11/10/2009' 5.1 12/30/2009 2D-14 50029211830000 1841590 SF n/a 24" n/a 6.37 12/30/2009 2D-16 50029211850000 1841610 28' 4.0 26" 11/10/2009 5.1 12/30/2009 3K-27 50029227510000 1970460 7' 1.0 12" 11/24/2009 2.97 12/29/2009 Reviewed By: Safety Valve & Well Pressures Test Report P.I.Suprv ~1~,~~~ Comm Pad• KRU_2A InspDt: 12/15/2009 Inspected by Chuck Scheve Interval 90 Days InspNo svsCS091215194008 Related Insp: _ ~~ Field Name KUPARUK RIVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Mike R son 90-Day Src: _---- -_- ---- ----,-- ---- -:- - -T, - ----- `- ---- --- -- --i--- -__---- ---- --- Wetl Data Pilots SSV SSSV ! Shutln Dtl Well Type L Nell Pressures ;Gas Lh {Waiver comments Well Permit Separ Set L/P Test Test Test Date SI OiI,WAG,GINJ, Inner Outer Tubing ,..........._ i-r.....tio. ncr aci Trin GAe Cnde Cnde GAS.CYCLE. SI PSI PSI PSI Yes/No Yes/No _ --- 2A-OS 2A 09 ~ 1840670 1860010 100 100 70 7~ 83 - 54 P P P P ~ -- ~-1-OII, T 1_OIL - _ ~ ___ _ ~ i _ _ __ _ ~ ~ 2A-11 1860030 100 70 68 P P 1-OIL, _ ` 2A-13 _ 2A i 5 _1851440 1851460 100 100 70 70 52 66 P P P P ~ __ 1-OIL 1-OIL _ 250 100 220 _ No _ Yes IA x OA communication I ___ ______ I 2A-17 1931400 r-- _ --+ 100 -- ' 70 I ~ r 0 i 1 NT _ 1-OIL _ __ Pilot failed to trip (likely frozen), SSV not tested due to leaking wing valve, Well left shut in pending repairs 2A-18 1950590 2A-19A 2010830 ------ ~ 100 70 61 P P 1-OIL~ ~ _ __ t 100 70 I 55 P P 1-OIL ~ _ _ _ _ -~ 1 IL O ~ ~ _ ___ 1931440 2A-24 2080940 F 100 70 61 P P ~ _ ~ 100 70 0 1 P - _ _ _ _ 1-OIL -~ ~ __ Pilot failed to trip (likely frozen) 2A-26 ~ L_..__- _ _ ~ Well left shut in pending repairs Comments Of the 10 wells tested the well house heater was on in 1 of them. Performance Wells Components Failures Failure Rate 10 19 2 10.53% Monday, January 11, 2010 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~U~ ~ ~ ~QQ~ REPORT OF SUNDRY WELL OPERATIOI~Q~ska oil & Gas Cnns_ ('.nmr.,;~~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other QflC~Ila Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate Q - Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 208-094 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20575-00 - 7. KB Elevation (ft): 9. Well Name and Number: RKB 132', 92' AMSL 2A-26 • 8. Property Designation: 10. Field/Pool(s): ADL 25570 ' Kuparuk River Field /Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8210' feet true vertical 6419' ' feet Plugs (measured) Effective Depth measured 8112' feet Junk (measured) true vertical 6326' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 142' 16" 142' 142' SURFACE 3149' 10.75" 3149' 2805' INTERMEDIATE 7796' 7-5/8" 7796' 6021' LINER 680' 4.5" 8208' 6416' f Perforation depth: Measured depth: 7814'-7820', 7826'-7842', 7860'-7890' ~`143~15 R~D3 ~~vOo~S~yQ~~ true vertical depth: 6044'-6050', 6056'-6071', 6088'-6116' Tubing (size, grade, and measured depth) 3.5", L-80, 7581' MD. Packers & SSSV (type & measured depth) Baker'HRD' ZXP pkr @ 75 28' Camco'DS' nipple @ 509' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 437 909 243 -- 185 Subsequent to operation 434 ~ 1073 258 -- 192 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ ~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 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: none Contact John Peirce @ 265-6471 Printed Name John Peirce @ 265-6471 Title Ph 265 6471 Wells Engineer ~ ~~ r~ D t Signature ~ ~ __._ one: - a e l Pr red b Sharon Allsu r k 263-4612 -~~-~~~ Form 10-404 Revise ~~ JU ~ ~ ~ ~ ~ ~ A L ~~1/ Submit Original Only Lam- C 2 TD09 iii/// 1 ` ! ~ /~.,~/~/~l 2A-26 Well Events Summary DATE SUMMARY 3/3/09 SET 2.81" CAT SV Cad 511' RKB. ATTEMPTED TEST TO 3000 PSI. FAILED. SET 2.8 511' RKB. ATTEMPTED TEST, BLEW M1 SV THROUGH NIPPLE. ATTEMPTED VER M1 SV Cad 6292' SLM. NO SUCCESS. JOB SUSPENDED FOR RIG JOB. 3/4/09 ENGAGED 2.81" M1 SV @ 6311' (MAX 2.84" OD). POH, WORK THRU NIPPLE @ 511' RKB. ATTEMPTED SET 2.875" CA2 IN NIPPLE @ 511' RKB, FAILED. SET 2.75" CA2 PLUG IN NIPPLE @ 7515' RKB; APPEARED TO SET PROPERLY. IN PROGRESS. 3/5/09 PULLED 2.75" CA2 PLUG @ 7515' RKB. COMPLETE. 3/30/09 TAGGED (a~ 8031' SLM, EST. 179' RATHOLE. PULLED OV @ 7458' RKB; CHECK & OV IN GOOD CONDITION. SET 1/4" OV @ SAME. COMPLETE. 4/5/09 TAGGED @ 8029' SLM. LOGGED CALIPER SURVEY ACROSS LANDING NIPPLES FROM 7700' - 7000' SLM, AND FROM 550' SLM TO SURFACE. COMPLETE. 5/27/09 TAG @ 7998' SLM W/ 20' DMY GUN DRIFT. NO PROBLEMS. JOB COMPLETE 5/30/09 OBJECTIVE: PERFORATE THE KUPARUK A3, A4 AND A5 SANDS PERFORATE INTERVALS FROM 7814'-7820' 7826'-7842' AND 7875'-7890' USING 2.5" HSD 2506 POWERJET, 6 SPF, 60 DEGREE PHASING GUNS. API DATA: ENTRANCE HOLE: 0.32", PENETRATION: 25.2" 6/15/09 A SAND SCALE SQUEEZE. PUMPED 10 BBLS OF SEAWATER PRE-FLUSH CONTAINING 30 GALLONS OF WAW-5206. PUMPED 20 BBLS OF SEAWATER CONTAINING 110 GALLONS OF SCW-4004. ~ ~ "~ ` '~ KUP .- Canoe©Phill~ps ~ • + ~ Well /attribute s .Max A~t4ha ,r:1, .. ~ Wellbore APl/UWI ' Field Name Well Status ,Intl (° ( 501032057500 + KUPARU PRODUCING I 51 <. K RIVER UNIT - C ent Date A lotion End Date H25 (ppm) l C f DE I / 0G9 5]J3 ?' SSS V: NIPPLE ( 0 1/1/2009 Last WO: V -WZl an ig A_;0 ~$A 2b.k _ gtihemetip Arn t~ 2 N u@I A notation Depth (ftK6) '.End Date Annotation ,., Last Tag' SLM 7,99A.0 '. 5/27/2009 'Rev Reason: TAG S'_M, ADC PERFS HANGER, 3fi ----- ~ Casco Stnn 9 9 Cas ng D pt s - - Sh ng 0... tr g ID .. ' Top (ftK6) Set Depth (TVDi ... S t D pth (f._'1, CONDUCTOR 16 15.250 41.0 1420 1420 Casing Descr noon String 0... String ID ... '.TOp (ftKel Set Depth (f._'i~Set Depth (TVD) ... - - _ SURFACE 103/4 9.950 ~ 41.3 3,149.0 ~ 2,803.8 Casing Description String 0... String ID ... ~ Top (ftK6) Set Depth (f...' Set Depth (TVD) ... INTERMEDIATE 7 5/8 6.875 37.9 7 796.5 6,027.7 Descri tion 9 P SLr / . 9 Str3 t 58 ...'~. Top (HKBI Set Depth (f... Set Depth (TVDj ... "' LINER 41 2 i r 9 ' 7,527.9 11 8,208.0 6 416.8 _ Liner Details __- _ _ .„ Top Depth', 'i (TVD) ~ Top Intl I , NIPPLE. 509 -- GAS LIFT, __ 2,619 SURFACE, _, 41-3,149 GAS LIFT, 4,213 GAS LIfT. 5,635 GAS LIFT, _ _ 6,830 GAS LIFT, ],656 NIPPLE, 7,513 LOCATOR, _ - 7.562 SEAL ASSY, - - ],562 7,527.91 5,777.9 23.68 PACKER 'Baker "HRD" ZXP Liner Top Packer w/HD 7,546.91 5,795 4 23.25 NIPPLE "RS" Packotf Seal Nipple 5.5" 7,549.8 5,798.0 23.18 HANGER Baker 5.5" x 7.625" Flez-Lock Liner Hanger 7,561.3 5,808.6 22.92 SBE 80-40 Seal Bore Extension 5 03' OD 4.00' 7,580 7 5,826.4 22.48 XO Crossover Bushing 5.0" BTC Pin x 4.5" IBT I china Deu:riotinn String D... String ID (Too (HKBI (Set Deoth (f... Set Depth (iVDI ... Top Intl 508.61 507.8 7.30 NIPPLE 13.5" Camco "DS" Nipple (Apparent restyle 7,5129', 5,764.1 24.02 NIPPLE ''3.5" Camco "D" Nipple w/ 2 75" prof le 7,561.9 ~~. 5,809.1 22.91 LOCATOR Baker 3.5" Locator O-D. 4-54' I. D. 3 99" 7,562 41 5,809.61 22.90 I SEAL ASSY Baker 80-00 PBR w/Seal Assembly O-D. Perforat ions $ Slots __ -_ Top (rVD) Btm (TVDI ~ Dens Top (ftK6) , Btm (ftK6) ~ (HKB) (ftK6) Zone Date ieh... ; Type ~ 7,8141 7,820 6,044.2' 6,049.9 A-5, 2A-26 5/30/2009 6.0 APERF 7,826 7,842 6,055.5 6,070.7 _ _ --_ A-0, 2A-26 _ l 5/30/2009 6.0 APERF 7,860 7,875 6,087.7 6,101.8 A-3, 2A-26 2/16/2009 6.0 IPERF 7,875 7890 6,101.8 6,116.O IA-3, 2A-26 5/30/2009 6.0 APERF Stimula tions $ Treatme nts I - - _. _- _-__.. .. ~ I Bottom ---- - "_, -:, Min Top Max Btm Top Depth Depth Depth ~ Depth 'i (TVD1 (TVD) 1 (ftK6) ~ (HKBI I, (HKB) (ftK8) Type Oate 7,860.0. 78750 6,08771, 6,101.8 FRAC 2;21/2009 A-SAND HYC 2A-26 By End Date wi 4/22/2009 t ny... so-nyroPrnra H-00 tr ng ... (String Top Thrtl L-80 BTC tying ... i String Top Thrd L-80 Hvd 563 HSD PawerJet HMX, 60 deg .e HSD PowerJet HMX, 60 tleg placed 99m104# 0(16/20 Carbolite into tormation '~I W/Sppa stage in perfs __ T .. Notes: General__8 Safety __ _- _ - En^ Date Annotation 1/27/2009 1.~NOTE: VIEW SCHEMATIC wlAlaska Schematic9.0 Mandrel Details __ _ anr< Top De th Top (TVD) Intl OD Valve Latch Size TRO Run JTERMEDIATE, Stn To HKB (ftK6) (") ', Make Mod I (in) Serv Type Type (inl (psl) Ru D to Com... 38-],]9] P ( I I 1 2,6194 2,394-913q.24~ICamco MMG 1 1/2 Gas Lif[ GLV RK 0.188 1,288.0,2125/2009 1 APERF, ],eta-],a29 2 4,212.6 3,503.T 52.01 Camco MMG 1 1/2 Gas Lift GLV RK 0.188 1,269.0 1 2/2 512 00 9 i 3 5,6346 4,390.2 51.76 Camco MMG 1 112 Gas Lift GLV RK 0.188 1,252 0 2/25/2009 APERF, ___ 7,e2s~7aa2 ~ ~ 4 6,829.6 5,172.4 38.69 Camco !MMG 11/2 Gas Lift GLV RK 0.1881 1,2350 2/25/2009 FRAC,],aso ~ 7,456.0 5,712.5 25.31 Camco ~IMMG 1 1I2Gas Lift OV RK 0250 0 0 3/30/2009 IPERF. _ - ],860-].8]5 - i~ --- - - ° - -- APERF, ],8]5-],690 LINER. _ 7.528-8.208 -'- TD, 8,218 Page 1 of 1 Maunder, Thomas E (DOA) From: Greener, Mike R. [Mike.R.Greener@conocophillips.com] Sent: Monday, June 15, 2009 8:31 AM To: Maunder, Thomas E (DOA) Subject: RE: 2A-26 (208-094) Attachments: Greener Mike.vcf 1. The cement volume for the liner should be 33 bbls. 2. The liner was reciprocated. 3. Rig pump issues in maintaining a prime. Mike Greener From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, June 15, 2009 8:03 AM To: Greener, Mike R. Subject: 2A-26 (208-094) Mike, I am belatedly reviewing the completion report for this well and have some questions. 1. It appears that the cement volume given for the 4-1 /2" liner on the 407 is actually the displacement volume. Would you confirm? 2. Was the liner reciprocated? 3. On 1/14/09, it appears that same problems were encountered attempting to pressure up the 7-518" casing for the casing test. It appears that the problem was solved, however there is no explanation given as to the solution. Could you please comment? Thanks in advance. I look forward to your reply. Tom Maunder, PE AOGCC 6/15/2009 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ~ 6. Permit to Drill Number: 208-095 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD2-466 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^~ 8. API Number: P. 0. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20576-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^Q or Final ^ 308-294 9/17/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 383* 383 totals (bbls): 2008 / 3rd 0 0 0 0 2008. / 4th 0 0 0 0 2009 / 1st 0 0 0 0 2009 / 2nd Total Ending Report is due on the 20th volume 0 0 383 383 0 of the month following the final month of the quarter. Ex: (bbls>: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *Leak-Off test and freeze rotect volumes onl orrect to the best of my knowledge. I hereby certify that the foregoing is t rue and c // ~~ n Signature: .f~l- t/ l ,~ Date: ~" (~~ 4 Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL I s 1. Operator: 4a. Well Class: Stratigraphic ^ Service ~ 6. Permit to Drill Number: 208-114 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD2-467 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ Q WDSPL ^ 50-103-20579-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ~ or Final ^ 308-295 10/20/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 373* 373 totals (bbls): Zoos / ath 13280 100 0 13380 18 11/10/2008 12/20/2008 CD2-469 and CD2-468 2009 / 1st 5039 100 0 5139 5 1 /4/2009 1 /9/2009 CD2-73 2009 / 2nd 2009 / 3rd Total Ending ( Report is due on the 20th volume 18319 200 373 18892 23 Ex: of the month following the final month of the quarter (bbis): . Apri120 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *FIUSh and freeze protect volumes onl cor rect to the best of my knowledge. I hereby certify that the foregoing i s true and / / ~ / Signature: ~!- (__ l.~` Date: ~ ~ 1 1 ~ ~1 Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate g ,, ~ _, ~~ ~ "~_ ~A ~; $~'J NO. 5138 Schlumberger -DCS ~~ 2525 Gambell Street, Suite 400 ~.' ~ Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ,~ ~ ; Attn: Christine Mahnken ATTN: Beth ` i,J t ~ 333 West 7th Ave, Suite 100 ~ __ ~~_~~._~ ~- Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 03/18/09 2A-26 604C-00011 OH EDIT (PEX,SSCANNER & CHFR) -Ug4l ~5/ 02/14/09 6 1 1E-170 ANHY-00057 PRODUCTION PROFILE a "' 03/06/09 1 1 1A-11 ANHY-00058 LDL ~ C( 03/08/09 1 1 3G-04 ANHY-00060 PRODUCTION PROFILE Q_ 03/10/09 1 1 3B-15 ANHY-00061 INJECTION PROFILE ~} - "b 03/11/09 1 1 1 R-10 ANHY-00063 INJECTION PROFILE ~ 03/13/09 1 1 2M-16 ANHY-00064 INJECTION PROFILE ~ / . 03/14/09 1 1 2G-15 ANHY-00065 PRODUCTION PROFILE 1'~L(- ~ 03/15!09 1 1 _ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~, - S • • WELL L®G TRAle1SMi'TTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 2A-26 March 5, 2009 AK-MW-5884050 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2A-26 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 50-103-20575-00 2" x 5" TVD TRIPLE COMBO Logs: 1 Color Log 50-103-20575-00 2" x 5" MD BAT VDL Logs: 1 Color Log 50-103-20575-00 2" x 5" TVD BAT VDL Logs: 1 Color Log 50-103-20575-00 Digital Log Images 1 CD Rom 50-103-20575-00 YLtJAS~ ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fad:: 907-273,-3535 Bryar~Bi~%rfd'a~halliburton.com Date:_ ~~ BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 -~ _` Signed: WELL LOG TRANSMITTAL T®: State of Alaska March 5, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~` Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 2A-26 AK-MW-5884050 1 LDWG formatted CD Rom with verification listing. API#: 50-103 -20575 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan. Burinda@halliburton. com ~-~ - Date: ,~.~ ~: Signed ~ ~_ ~~ , ~'i~~--' ~ ~ ~ ~ ~" J ~- a- COnotoPh~lllps TRANSMITTAL CONF/DENT/AL DATA FROM: Sandra D. Lemke, AT01486 TO: Christine Mahnken ConocoPhillips Alaska, Inc. State of Alaska P.O. Box 100360 AOGCC Anchorage AK 99510-0360 333 W. 7~' Ave. Suite 100 Anchorage, Alaska 99501-3539 RE: Kuparuk River Unit 2A-26 DATE: 3/11/2009 Hand -carry Transmi Kuparuk River Unit, North Slope, Alaska 2A-26 Report and CDROM Final Well Report, Mud Logging. Data, 2A-26; Epoch, report date: 1/1612009; table of contents, equipment and crew, well data, geological data, pressure/strength data, drilling data, daily reports, formation logs-, Color log prints: Formation Log MD and TVD 801-8210' - LWD Combo Log TVD 801-8210' Drilling Dynamics MD and TVD 801-8210' Gas Ratio Log MD and TVD 801-8210' CDROM contains: well report, morning reports, LAS data, PDF and tiff format color log image files; DML; FIT data files and lithology remarks. CC: Anna Belang r, CPAI Geologist Receipt: ~ Date: ~'u;,.~ , i _ :r s; ~ 7''` a r-~~ ''; ~la.~ ~ ~ ~ ~? 3' ~~. ~~t~1;`'v'"'e ~ ~'~''~~ ?s';°a~ e;~~ ~ ; , i :"?~~`~ a~, ;~ .? ~ ~ j..~'.,'. ,~',.~, ~~~~ ~ .~ndra. ~. ~emke~Corroco~hi!/ice ~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # -;~-- - mm _~'. ~~ p9e..®_, ~ b~~ , NO. 5125 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 03/03/09 3H-33 604C-00006 USIT 02/09/09 1 1 1 D-130 ANHY-00049 INJECTION PROFILE J, ~ - 02/12/09 1 1 2A-26 ANHY-00053 PERF/SBHP SURVEY - _ C (• ~ 02/16/09 1 1 3H-33 AYS4-00039 SFRT - 02/23/09 1 1 3C-06 B14B-00005 GLS ~! - ~; - 02/23/09 1 1 2N-318 6148-00006 SBHP SURVEY _ _ / (} 02/24/09 1 1 3H-33 B04C-00006 SONIC SCANNER - ~' (• 02/09/09 1 1 3J-06 8146-00008 PRODUCTION PROFILE 02/27/09 1 1 1 D-119 AYS4-00044 INJECTION PROFILE , '•} - _ ~ ~ 02/28/09 1 1 3G-03 AYS4-00043 PRODUCTION PROFILE - ~' - 02/27/09 1 1 F~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317,- Thank you. • ConocoPhillips March 4, 2009 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject:. Well Completion Report for 2A-26 Dear Commissioner: G. L. Alvord Alaska Drilling Manager Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 '~ 4~as~C~ fit s ~~s '~< E,~n'"° C~r~~aissioa- Anc9tor~g~ ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Kuparuk wells 2A-26. If you have any questions regarding this matter, please contact me at 265-6120 ar Mike Greener at 263-4820. Sincerely, ,~.. ~, ~ G. L. Alvord Alaska Drilling Manager CPAI Drilling GLA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development O Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: January 22, 2009 ~ 12. Permit to Drill Number: 208-094 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: December 30, 2008 13. API Number: 50-103-20575-00 4a. Location of Well (Governmental Section): Surface: 776' FSL, 227' FWL, Sec. 13, T11 N, R8E, UM 7. Date TD Reached: January 18, 2009 14. Well Name and Number: 2A-26 ° Top of Productive Horizon: 2247' FNL, 1795' FEL, Sec. 24, T11 N, R8E, UM 8. KB (ft above MSL): 132.5' RKB - Ground (ft MSL): 92' AMSL ~ 15. Field/Pool(s): Kuparuk River Field Total Depth: 2370' FNL, 1676' FEL, Sec. 24, T11 N, R8E, UM 9. Plug Back Depth (MD + ND): 8112' MD / 6326' TVD Kuparuk Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 498621 y- 5960198 Zone- 4 10. Total Depth (MD + ND): 8210' MD / 6419' TVD ' 16. Properly Designation: ADL 25570 TPI: x- 501880 y- 5957174 Zone- 4 Total Depth: x- 501999 - 5957053 Zone- 4 11. SSSV Depth (MD + ND): nipple @ 511' MD / 510' ND 17. Land Use Permit: 2668 18. Directional Survey: Yes ^~ ~ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1495' ND ` 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES, USIT, CNL, Sonic 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE CEMENTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.58# H-40 Surf. 142' Surf. 142' 42" 308 sx AS 1,345 sx AS 1 10.75" 45.5# L-80 Surf. 3149' Surf. 2805' 13.5# 577 sx AS Lite, 207 sx LiteCRETE 7 5/8" 29.7# L-80 Surf. 7796' Surf. 6021' 9.875" 84 bbls Class G GasBLOK 4.5" 12.6# L-80 7528' 8208' S77T 6416' 6.75" bbls Class G w/GasBLOK 3 e 23. Open to production or injection? Yes Q No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 7581' 7528' 7860'-7875' MD 6088'-6102' ND 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~~~ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ~~~~ ~~ ~" 7 `6875' 116533# of 16/20 carbolite ~ ~~"~' ,i ~`~ ~ f p~G~~C I ~A~^~`'~ 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) waiting on facility hook-up Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE Gas-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes No ~ Sidewall Cores Acquired? Yes ^ No Q If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ..r_ ( .~~ I L~~~-.~~ b NONE i. z~ ° d9~ ) ~I~U 4 t ,;sayirq~.xeu -. Form 10-407 Revised 2!2007 CONTINUED ON REVERSE SIDE 3 /'7•~Q! ~~ 1,~~ ~/rte, . G ~~ 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ~ Yes / No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1541' 1495' needed, and submit detailed test information per 20 AAC 25.071. C-4 7695' 5933' A-3 7855' 6083' A-2 7923' 6147' A-1 not available N/A Formation at total depth: Kuparuk A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: M e Greener @ 263-4820 Printed Name Chi Alvord Title: Alaska Drilling Manager J Date 31 ~1 Si Ph - t gna ure one ~~ , ~ ~ ZO INSTRUCTIONS Sharon Allsup-D2ke 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 and Ground level elevations in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 Cont~eQPh'tl~ip's ~ WeII AttribEate _ s ~I y _(4 ` Welltgre APUUWI __ Fieltl Name J 501032057500 .. KUPARUK RIVER UNI C nt H2S (ppm) t 2s 2uose x535 ant---: SSSV. NIPPLE 11 _ well_cgn g D w ED _?A~ ,; _ ___- Shcematic~ACW n2l aI ' A oration Depth (ftK6) IEnd Date Last Tag: 11 Casin Strin s Cas ng Descnpt~on String 0... ( String ID HANGER. 3a- ---- CONDUCTOR 16 15.25( Casing Descnpbon .Str ng 0... String ID ~ ~ SURFACE 10 3/4 9.950 I ~ ~ ( Casing Dascnption ~Strmg 0.. String ID ':~it+ wW~'&:.c~a ,.~ .- ^ I S INTFRMFIIIATF 7 S/R fi R75 ~(ND) Top Inc! ~oP (~B) (ftK6) (°) 7,528 5,777.91 23.68 7,547 5,795.4 23.25 7,550 5,798.0 23.18 corvoucroR, a?-?a2 NIPPLE, S?? - GAS LIFT. _-,- 2.621 2A-26 -- - Well Stat Prod/In( Type Max Angle Sr MD ~Incl (°) MD (ftK6) ~ TD -- Act Btm (ft KB) Il T DRILLING 4,162 5197 8,210 A notatron (End Date Date KB Grd (fl) Rig Relaase Da ( I Last WO' IL ~ 44.07 ( IAnnntatinn IEnd Date Innol 41 aei vuyu~ t~ 3 149 .ova y t,.~.l 2 803 8 .... 45 50 L 80 .. y .... BTC _ (RKB) Set Depth (f Set D pih (ND) .. Str ng Wt... Str ng .. String Top Thl 38 7,797 6,027.7 29.70_ L-80 Hyd 563 (RKB) Sat Depth (t... Set Depth (ND) ... String Wt... String ... SMng Top Thl 7,528 8,208 6,416.8 12.60 L-80 IBTM Comment _ _ ID aker "HRD" ZXP Liner Top Packer w/HD 4 ES" Packoft Seal Nipple 5.5" 4. aker 5.5" x 7.625" Flex-Lock Liner Hanger 4 7~0 Seal Bore Extension 5.03" OD 4.00" ID 4 rossover Bushing 5.0" BTC Pin x 4.5" IBT Pin 3 /kKBI (Set Depth lf...~Set DepM(ND)... (String Wl...String ... (String TOp ThI jt 3.60') 511 509.8 7.371 NIPPLE 3.5 Camco"DS"Nipple wl287i' 2. i ~ 7,515 5,766.0 NIPPLE 23 97 35 Camco "D' Nipple w! 2.812' profle --- - ~--- - 2. -- 7,564 5,811.0! LOCATOR 22.861 _ _. ___ - - Baker 3 5" locator O.D. 4.54 I D 3 99" _ 3. 7,5641 5,811 4 22.85 SEAL ASSV _. - _ Baker 80-40 PBR w/Seal Assembly O-D. 4.01" LD. 2.99 - 2. SURFACE, _. a,-3,,a9 Perfora tions 8 Slots __ - - __ i Sho[ Top(ND) Btm (TVD) Dens GAS LIFT, Top (RKB( Btm (ftK6) (ftK6) (ftK6) Zone Date (sh-~ Type Comment 4,2'.5 1 7,860 7,875 6,087.7 6,101.8 A-3, 2A-26 2/16/2009 6.0 IPERF 2.5" HSD HJ 2506, RDX, 60 tleg l S i & T t t phase ... __._. -L____..._ GAS LIFT, _ ~ a timu Min Top t ons Max Bim rea me ~ Top Depth n s Bottom Depth 5,63'! Depth Depth (NDj (ND) (ftK6) (RKB) (RKB) (ftK6) Type Date Comment - 7,860 7,875 6,087.7 6,101 8 FRAC 2/21/2009 A-SAND HYDRAULIC FRACTURE STIMULATIOI placed 99m104# of 16!20 Carbolite into formation W18ppa stage in perfs GAS LIFT,__.. _ __ __- '„ `.- Entl Date 6,832 1/27!2009 NOTE: VIE GAS LIFT, -.. 7 458 ~...-~"~ NIPPLE, ],515-- -- , SEAL ASSV, ~ - ],564 __ - - - . _ . .J Mand rel D etails Top Depth Top Pon (TVD) Inc! OD V Ive Latch Size TRO R St n T op (ftK6) (RKB) (°) Make Mod I (in)- Serv Type Type lin) (p ) Run Date I _ _ 1 2,6211 2,396.7 34.281Camco MMG 1 1/2 Gas Lift DMY RK 0.000 0.0 1/22/2009 2 4,215 3,504.9 52.OOICamco MMG 1 1l2 Gas Lift DMY RK 0 000 0 0 1/22!2009 ', 3 5,637 4,391.5 51.75Camco MMG 11/2 Gas Llft DMY RK 00001 001!22/2009 RMEDwte, ___ _. 4 6,832 5,17513938 Camco MMG 11/2 Gas Llft ,DMY ~ IRK OOOOi 001/22/2009 38-7,797 IPERF. 5 7,458 __ 5,714.3 25.27 Camco (MMG 1 12 Gas Llft (DMY - RK 0 000 0 0 2/2/2009 7.860-7.87 - Iq _ _ ... _ ___ _- . _ 5 FRAC. 7,860 il!!;~ LINER, 7.528-8,208 TD, 8,2?0 i CanacaPl~illips Time Log & Summary. We/N±ew iNeb ReAOrtrn4 Report _ Well Name: 2A-26 Rig Name: DOYON 15 Job Type: DRILLING ORIGINAL Rig Accept: 12/29/2008 6:00:00 PM Rig Release: 1/22/2009 6:00:00 PM Time Logs -- _. D to From To Dur S D~th E Depth #'hase Code 5ubcode__ T___ Comment _ 12/27/2008 24 hr Summary Move off of 3K pad with sub and pit module. 13:00 17:00 4.00 0 0 MIRU MOVE DMOB P RIG RELEASED from 3K-108. Split modules and move off well. 17:00 00:00 7.00 0 0 MIRU MOVE MOB P Sub and pit module moving off 3K- ad 12/28/2008 Move from Oliktok road to 2A pad. Spot mats around well. Move over 2A-26. 00:00 05:00 5.00 0 0 MIRU MOVE MOB P Move rig from Oliktok road to Drilling Tool House 05:00 08:30 3.50 0 0 MIRU MOVE OTHR P Waiting on field crew change. 08:30 12:30 4.00 0 0 MIRU MOVE MOB P Move from Drilling Tool House to 2X ad access. 12:30 13:15 0.75 0 0 MIRU MOVE OTHR P Stop and let traffic pass. Perform walk grounds, checkin hoses. 13:15 15:00 1.75 0 0 MIRU MOVE MOB P Move from 2X pad to CPF-2. 15:00 15:30 0.50 0 0 MIRU MOVE OTHR P Stop and let traffic pass. 15:30 17:00 1.50 0 0 MIRU MOVE MOB P Move from CPF-2 to 2B pad. 17:00 20:00 3.00 0 0 MIRU MOVE OTHR P Wait on field crew change 20:00 22:00 2.00 0 0 MIRU MOVE MOB P Move from 26 pad to 2A pad 22:00 23:00 1.00 0 0 MIRU MOVE MOB P Spotting rig mats around well. 23:00 00:00 1.00 0 0 MIRU MOVE MOB P Move sub onto mats 12/29/2008 Spot sub, pits and rockwasher over well. Hook up lines, berm up around rig. Make ready to spud well. 00:00 03:30 3.50 0 0 MIRU MOVE RURD P Spotting sub over well. Working around ad'acent wellhead & flow line. 03:30 04:00 0.50 0 0 MIRU MOVE RURD P Lower stompers on sub and pre-load. 04:00 04:45 0.75 0 0 MIRU MOVE MOB P Position pit module to crab up onto mats. Generator on pit module shutdown. Work on restartin . 04:45 05:00 0.25 0 0 MIRU MOVE SFTY P PJSM -skidding rig floor. 05:00 07:00 2.00 0 0 MIRU MOVE RURD P Skid rig floor into position. Install roll ca sand hand rails. 07:00 07:15 0.25 0 0 MIRU MOVE SFTY P PJSM -moving pit module 07:15 08:00 0.75 0 0 MIRU MOVE MOB P Crab pit module up onto mats and s of next to sub. 08:00 10:00 2.00 0 0 MIRU MOVE RURD P Spread herculite for rockwasher and berm u around ri . 10:00 10:15 0.25 0 0 MIRU MOVE SFTY P PJSM -picking up beaver slide and connection modules. 10:15 11:00 0.75 0 0 MIRU MOVE RURD P Pick up beaver slide and secure to ri . Connectin u lines. _.~ ~ ~~t~e ~ of 37 Time Logs Date From To Dur S_D~ih_ E_ Depth -Phase Code _ Subcode T Comment 11:00 11:15 0.25 0 0 MIRU MOVE SFTY P PJSM -moving and spotting rockwasher. 11:15 12:00 0.75 0 MIRU MOVE RURD P Spot rockwasher and berm up. Continue connectin u lines. 12:00 18:00 6.00 0 0 MIRU MOVE RURD P Set stairs and landings, set cuttings boxes for rockwasher, dress shakers for surface hole. Finsh connecting lines between modules. Nipple up riser and lines. Moving Alta-Fab camp. RIG ACCEPTED 18:00 18:00 00:00 6.00 0 0 MIRU MOVE RURD P Continue rigging up rockwasher, water lines, steam lines, stairs. Test augers. Rig up diverter line. Load water. Move Cruz cam . 12/30/2008 Rig up diverter, load BHA into pipe shed, loading drill pipe into pipe shed, PJSM, PU two joints of 5"drill pipe, function test diverter system (Witness of test waived by AOGCC inspector Jeff Jones). Tag ice in conductor @ 45', install mousehole in the rotary table, PU/MU/Standback 74 stands of 5" drill pipe, standback 5 stands of 5" HWDP w/jars. Diverting shallow gas drill, pre spud surface hazards discussion, PJSM on picking up/ make up BHA to cleanout conductor. Pickup/ make up BHA, fill conductor with water, check for leaks, presure test mud lines to 3500 psi, cleanout 16" conductor f! 45' to 142', drill from 142' to 175' at midnight. Note: Moved both small camps to well row side of pad (out of the line of fire of the diverter line). EPOCH mud to ers ri in u . 00:00 02:00 2.00 0 0 MIRU MOVE RURD P Continue rigging up diverter line. Dress shakers with screens. Function test auger. Move Cruz cam . 02:00 06:00 4.00 0 0 MIRU MOVE RURD P Load BHA #1 in the pipe shed. Load 5" drill pipe into the pipe shed. Spot EPOCH trailer. Rig up stairs and landin s. 06:00 10:00 4.00 0 0 MIRU MOVE RURD P Continue loading drill pipe into the pipe shed (total of 222 joints (74 stands)). Load 14 joints of 5" HWDP. Prepare pits to take on spud mud. Secure diverter line. Torque bolts on diverter. Remove 4" handling tools from floor, icku 5" tools. 10:00 10:15 0.25 0 0 MIRU DRILL SFTY P Pre job safety meeting on picking up 5"drill pipe, standing back in the derrick. 10:15 11:15 1.00 0 0 MIRU WELCTI BOPE P Pickup 2 joints of 5" drill pipe. Function test diverter s stem. Witness of test waived by AOGCC inspector Jeff Jones. Initial pressure of 3050 psi. After fuctioning annular and knife valve, pressure of 1675 psi. Time of 1 minute and 5 seconds for 200 psi buildup, full charge in 2 minutes 37 seconds. 5 bottle average of 2420 psi on the nitrogen backup. Tested gas alarms. Annular closed in 40 seconds, knife valve o ened in 22 seconds. Pace 2 ~sf 3'7 ~~ Time Logs _ __ __ - - __ _ _- Date From To Dur S. De th E__De_pth Pha'e Code Subcode T Comment __ _______ 11:15 12:00 0.75 0 0 MIRU DRILL PULD P T~q ice in the conductor at 45'. Install mousehole in the rotary table. Pickup/make up/ stand back in the derrick 5" drill pipe. A total of 5 stands at noon. 12:00 20:30 8.50 0 0 MIRU DRILL PULD P Continue to pickup/make up/ stand back in the derrick 5" drill pipe. A total of 74 stands. Pickup/make up! stand back in the derrick 5" HWDP. A total of 5 stands with jars. Prepare s ud mud. 20:30 21:00 0.50 0 0 MIRU DRILL SFTY P Diverting shallow gas drill discussion in dog house. Drilling surface pre spud hazards discussion in dog house. Pre job on picking up BHA #1. 21:00 22:00 1.00 0 0 MIRU DRILL PULD P Pickup/ make up BHA #1 to clean out conductor f/ 45' to 142' RKB. Bit, motor, UBHO and crossover, stand of HWDP w/ ~ars. 22:00 22:30 0.50 0 0 MIRU DRILL OTHR P Fill hole. Check for leaks- ok. Test mud line to 3500 si- ok. 22:30 23:30 1.00 0 142 SURFA( DRILL DDRL P Clean out ice in conductor from 45' to 142'. Rotate 40 rpm. Pumping 450 m w/ 600 si. 23:30 00:00 0.50 142 175 SURFAC DRILL DDRL P Spud--Drill 13-1/2" hole from 142' to ,. 175'. Note: Gyro survey's @ 100':.54 deg inc with 354.52 deg azimuth: 168':.64 deg inc w/ 358.28 deg azimuth 12/31 /2008 Continue to drill from 175' to 225', run gyro survey's @ 100' & 168', POOH w/ 2 stands of HWDP, MU BHA #1, u load, continue to PU/MU BHA, shallow test, drill from 225' to 2161', 00:00 01:30 1.50 175 226 SURFA( DRILL DDRL P Drill 13-1/2" hole from 175' to 226' 01:30 02:00 0.50 226 226 SURFAC DRILL SRVY P Blow down the top drive.Run Sperry Sun gyro survey. Note: Gyro survey's @ 100':.54 deg inc with 354.52 deg azimuth: 168': .64 de inc w/ 358.28 de azimuth 02:00 02:30 0.50 226 226 SURFAC DRILL TRIP P Pull out of the hole two stands of 5" HWDP. 02:30 03:30 1.00 226 226 SURFAC DRILL PULD P Make up BHA #1. 03:30 04:00 0.50 226 226 SURFA( DRILL SRVY P Orient MWD, motor and UBHO sub. 04:00 04:45 0.75 226 226 SURFAC DRILL SRVY P Upload Sperry Sun MWD. 04:45 05:15 0.50 226 226 SURFAC DRILL PULD P Continue to make up BHA #1. 05:15 05:30 0.25 226 226 SURFA( DRILL SRVY P Run gyro survey for toolface. 05:30 05:45 0.25 226 226 SURFAC DRILL DHEQ P Shallow pulse test MWD. 630 gpm w/ 1540 si- 51 % flow out. 05:45 06:00 0.25 226 300 SURFA( DRILL DDRL P Drill 13-1/2" surface hole f/ 226' to 300'. 06:00 12:00 6.00 300 842 SURFA( DRILL DDRL P Drill 13-1/2" surface hole f/ 300' to 842'. Max TOTCO gas observed 54 units. EPOCH not workin et. F'ar~e ~ rsf 37 Time Logs - - ----- -- - ------- -- Date From To Dur S. De th E. De th Phase Cade Subcode T Comment - -- _ - - - - 12:00 18:00 6.00 842 1,447 SURFA( DRILL DDRL P Drill 13-1/2" surface hole f/ 842' to 1447'. Max TOTCO gas observed 926 units: POCH not workin et. 18:00 00:00 6.00 1,447 2,161 SURFA( DRILL DDRL P Drill 13-1/2" surface hole f/ 1447' to 2161'. Max TOTCO gas observed 142 units. Max EPOCH gas observed 125 units. 1 /01 /2009 Continue to drill from 2161' to 3150', circulate 2 BU then a 60 bbl weighted sweep, monitor well, POOH on elevators to 639', trip in to 3150', circulate, then pump a 60 bbl weighted sweep, circulate and condition mud f/ casin ,monitor well, POOH f/ 10-3/4" casin , UD BHA #1. 00:00 06:00 6.00 2,161 2,916 SURFA( DRILL DDRL P Drill 13-1/2" surface hole f/ 2161' to 2916'. Max TOTCO gas observed 1383 units. Max EPOCH gas observed 723 units. 06:00 10:00 4.00 2,916 3,150 SURFA( DRILL DDRL P Drill 13-1/2" surface hole f/ 2916' to 3150'. Max TOTCO gas observed 582 units. Max EPOCH gas observed 267 units. 10:00 11:30 1.50 3,150 3,150 SURFA( DRILL CIRC P Circulate, rotate and reciprocate to clean hole. Pumping 730 gpm w/ 3030 psi. Rotate 80 rpm w/ 6500 ft Ibs of torque. PU wt 168k, SO wt 142k, Rot wt 155k. Circulate bottom's up, then 60 bbl weighted sweep (11.5 ppg/ 244 vis) pumped to surface. Did not see sweep. Pumped a total of 1577 bbls 3.26 BU . 11:30 11:45 0.25 3,150 3,150 SURFA( DRILL OWFF P Monitor well, static. 11:45 14:00 2.25 3,150 639 SURFA( DRILL TRIP P Pull out of the hole on elevators. Monitor well on the trip tank. Record PU & SO wt's every 5 stands. Calculated fill 20 bbls, actual 23 bbls. 14:00 15:45 1.75 3,150 3,150 SURFA( DRILL TRIP P Trip in the hole on elevators. Monitor well on the trip tank. Record PU & SO wt's eve 5 stands. 15:45 18:00 2.25 3,150 3,150 SURFA( DRILL CIRC P Circulate, rotate and reci rotate to clean hole for casing. Stage pumps up from 300 gpm w/ 960 psi. Final rate of 730 gpm w/ 2940 psi. Rotate 70 rpm w/ 6000 ft Ibs of torque. PU wt 168k, SO wt 142k, Rot wt 155k. Circulate bottom's up, then 60 bbl weighted sweep (11.3ppg/ 244 vis) pumped to surface. Pumped a total of 1463 bbls. 18:00 20:30 2.50 3,150 3,150 SURFA( DRILL CIRC P Continue to circulate, rotate and reciprocate to clean hole for casing. Stage pumps up from 730 gpm w/ 2940 psi to 806 gpm w/ 3070 psi. Rotate 70 rpm w/ 6000 ft Ibs of torque. PU wt 168k, SO wt 142k, Rot wt 155k. Pumped a total of 3094 bbls (6.4 BU). Noticed a 50% increase in cuttin s with swee . 20:30 20:45 0.25 3,150 3,150 SURFA( DRILL OWFF P Monitor well, static. ~~ Pa~~ ~# oaf 37 Time Logs __ _ Date Froni To Dur S. Depth E _Depth Phase Code Subcod_ e_ T Comment _ _ 20:45 21:00 0.25 3,150 3,150 SURFA( DRILL PULD P Lay down two single drill pipes, blow down the top drive. PJSM on pulling out of the hole. 21:00 21:45 0.75 3,150 3,150 SURFA( DRILL TRIP P Pull out of the hole on elevators, 10 stands. Monitor well on the trip tank. Record PU & SO wt's every 5 stands. Calculated fill 8 bbls, actual 10 bbls. 21:45 22:00 0.25 3,150 3,150 SURFA( RIGMNT SVRG P Adjust brakes on the drawworks. Monitor well on the tri tank. 22:00 22:45 0.75 3,150 3,150 SURFAC DRILL TRIP P Pull out of the hole on elevators. Monitor well on the trip tank. Record PU & SO wt's every 5 stands. Calculated fill ?? bbls, actual ?? bbls. 22:45 23:00 0.25 3,150 3,150 SURFA( DRILL OWFF P Monitor well, static. 23:00 00:00 1.00 3,150 3,150 SURFA( DRILL PULD P Lay down BHA #1 to 114'. Monitor displacement on the trip tank. Calculated fill 35 bbls, actual fill 40 _ bbls. 1 /02/2009 Finish down loading Sperry Sun MWD, UD BHA #1, clean floor, RU/Run 10-3/4" 45.5 ppf L-80 BTC casing to 1636' w/ TESCO, circulate, continue running casing w/ TESCO to 2872', pump a few in the hole from 2872' to 2949', continue running in from 2949' to to 3109', wash last one down to 3150', tag bottom @ 3150'. Circulate w/ TESCO tool (BU/215 bbls), rig down TESCO tool, rig up long bales with GBR elevators, rig up Dowell cement head, circulate/ reciprocate prior to cementing, PJSM, Dowell pump 5 bbls of water, pressure test lines to 4000 psi. Good. Dowell pump 75 bbls CW 100 (8.3 ppg) @ 5 bpm w/ 350 psi, follow with 75 bbls MudPush II w/ red dye (10.5 ppg) @ 4.5 bpm w/ 115 psi, drop plug, mix and pump 492 bbls (577 sx) (Yield 4.79 cuft/sx) (23.89 gal/sx water) ArcticSet Lite (10.7 ppg) @ 6.9 bpm w/ initial 250 psi, final 500 psi, mix and pump 94 bbls (207 sx) (Yield 2.55 cuft/sx) (8.95 gal/sx water) of LiteCrete tail (12 ppg) @ 4.8 bpm w/ 480 psi, drop plug. Reciprocated pipe from 3150' to 3129'. Unable to reciprocate after dropping top plug- pulled to 385k. Left string with 200k on weight indicator. Dowell pump 20 bbls of water @ 6 bpm w/ 460 psi, turn over to rig. Rig displace with 9.4 ppg mud @ 7 bpm w/ initial pressure of 520 psi, final of 750 psi until 255 bls of mud pumped. Slow to 3 bpm w/ 580 psi and final of 600 psi. Bump plug at 2751 strokes (277 bbls), increase to 1100 psi, hold 10 minutes, bleed of and check floats- held. Note: Had 200 bbls of good 10.7 ppg cement to surface. Full returns. Flush surface a ui ment, ni lin down to ick u stack and set sli s. 00:00 00:45 0.75 3,150 3,150 SURFA( DRILL OTHR P Download Sperry Sun MWD. 00:45 02:00 1.25 3,150 3,150 SURFA( DRILL PULD P Continue to lay down BHA #1. Monitor well on the tri tank. 02:00 03:15 1.25 3,150 3,150 SURFA( DRILL OTHR P Clean and clear rig floor. Monitor well on the trip tank. Load BHA #2 in the pipe shed via the beaver slide, into the i e shed. 03:15 05:00 1.75 3,150 3,150 SURFA( CASING RNCS P Remove bales and elevators from the top drive. Rig up to run 10-3l4" surface casing with TESCO casing runnin tool. Static losses of 1 b h. 05:00 05:15 0.25 3,150 3,150 SURFA( CASING SFTY P Pre job safety meeting on running 10-3/4" 45.5 f L-80 BTC casin . 05:15 05:45 0.50 3,150 3,150 SURFA( CASING RNCS P Pickup/Makeup/RIH with Weatherford float shoe jt (turbolizer in center of joint), threadlock joint (centralizer in center ofjoint), next ~oint with float collar to 120' 05:45 06:00 0.25 3,150 3,150 SURFA( CASING CIRC P Fill pipe, checking floats. Pump 8.5 b m w/ 150 si-37% flow out. ~~~ Pag~a a ~f 37 i C~7 Time Logs _ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 06:00 06:30 0.50 3,150 3,150 SURFA( CASING RNCS P Continue running 10-3/4" 45.5 ppf L-80 BTC casing, installing Weatherford bow spring centralizers over collars. 06:30 07:15 0.75 3,150 3,150 SURFAt CASING SFTY P Crew change/Pre job safety meeting on running 10-3/4" 45.5 ppf L-80 BTC casin . 07:15 09:45 2.50 3,150 3,150 SURFA( CASING RNCS P Continue running 10-3/4" 45.5 ppf L-80 BTC casing, installing Weatherford bow spring centralizers over collars till joint # 15, then continue to run casing without bow spring centralizers. Jt # 40 in the hole. 09:45 10:30 0.75 3,150 3,150 SURFA( CASING CIRC P Reciprocate casing from 1595'to 1636'. Initial circulation @ 2 bpm w/ 170 psi--18% flow out. Pumping 3.7 bpm w/ 130 psi--23% flow out, pumping 5 bpm w/ 140 psi-29% flow out. Final circulation at 5.5 bpm w/ 140 psi--30% flow out. PU wt 158k, SO wt 120k. Pumped a total of 194 bbls casin volume+ 37 bbls . 10:30 12:00 1.50 3,150 3,150 SURFA( CASING RNCS P Continue running 10-3/4" 45.5 ppf L-80 BTC casing to jt # 68 in the hole. Installed two turbolizers in the center of jt # 65. PU wt 200k, SO wt 135k. 12:00 12:15 0.25 3,150 3,150 SURFA( CASING RNCS P Continue running 10-3/4" 45.5 ppf L-80 BTC casing. PU wt 210k, SO wt 140k. Jt # 70 in the hole. 12:15 12:30 0.25 3,150 3,150 SURFA( CASING RNCS P Continue running 10-3/4" 45.5 ppf L-80 BTC casing. Due to poor displacement, pumping while running in jt # 71 and #72 from 2872' to 2949'. 12:30 12:45 0.25 3,150 3,150 SURFA( CASING RNCS P Continue running 10-3/4" 45.5 ppf L-80 BTC casing. PU wt 210k, SO wt 140k. Jt # 76 in the hole. Installed centralizers on collar of jt # 74 and # 75. 12:45 13:00 0.25 3,150 3,150 SURFA( CASING RNCS P Continue running 10-3/4" 45.5 ppf L-80 BTC casing. Pumping to wash to bottom from 3109' to 3150'. Pumping 2 bpm w/ 280 psi--18% flow out. Tag bottom and set down 15k. PU wt 210k, SO wt 140k. Jt # 77 in the hole as landing joint. Jt # 76 will be cutoff'oint. 13:00 14:15 1.25 3,150 3,150 SURFA( CASING CIRC P Reciprocate casing from 3150' to 3129'. Initial circulation @ 2 bpm w/ 320 psi--18% flow out. Final circulation at 7 bpm w/ 320 psi--32% flow out. PU wt 210k, SO wt 140k. Pum ed a total of 215 bbls. 14:15 14:45 0.50 3,150 3,150 SURFA( CASING RURD P Rig up long bales to top drive. Rig down the Tesco casin runnin tool. Pays 5 cif 37 ~ r Time Logs _ _ Date From To___ []ur S Depth E. De th Phase Code Subcode T Comment __ - -- _ _ 14:45 15:15 0.50 3,150 3,150 SURFA( CEMEN" RURD P Rig up Dowell cementing head and 2" cementin hose. 15:15 17:45 2.50 3,150 3,150 SURFA( CEMEN" CIRC P Circ and condition mud prior to cement job. Reciprocate casing from 3150' to 3129' while pumping 7 BPM w/ 320 psi--32% flow out. Pumped a total of 1163 bbls. PU wt 215, SO wt 168k. Note: Held pre job safety meeting on cement job @ 1600 hrs while circulating with Dowell cement head. Mud properties before conditioning: MW in 9.3+, MW out 9.7 ppg, vis 101, PV/YP= 41!38, 10 min gels 62, vis out 250+ Mud properties after conditioning: MW in 9.3, MW out 9.4 ppg, vis 45, PV/YP= 20/12, 10 min els 4, vis out 59 17:45 18:00 0.25 3,150 3,150 SURFA( CEMEN" SFEQ P Dowell pump 5 bbls of water, pressure test lines to 4000 psi. Good. 18:00 20:15 2.25 3,150 3,150 SURFA( CEMEN" PUCM P Dowell pump 75 bbls CW 100 (8.3 ppg) @ 5 bpm w/ 350 psi, follow with 75 bbls MudPush II w/ red dye (10.5 ppg) @ 4.5 bpm w/ 115 psi, drop plug, mix and pump 492 bbls (577 sx Yield 4.79 cuft/sx) (23.89 gal/sx water) ArcticSet Lite (10.7 ppg) @ 6.9 bpm w/initial 250 psi, final 500 psi, mix andLpump 94 bbls (207 sx) (Yield 2.55 cufUsx) (8.95 gal/sx water) of LiteCrete tail (12 ppg) @ 4.8 bpm w/ 480 psi, drop plug. Reciprocated pipe from 3150' to 3129'. Unable to reciprocate after dro in to lu -pulled to 385k. Left string with 200k on weight indicator. 20:15 21:15 1.00 3,150 3,150 SURFA( CEMEN" DISP P Dowell pump 20 bbls of water @ 6 bpm w/ 460 psi, turn over to rig. Rig displace with 9.4 ppg mud @ 7 bpm w/initial pressure of 520 psi, final of 750 psi until 255 bls of mud pumped. Slow to 3 bpm w/ 580 psi and final of 600 psi. Bump plug at 2751 strokes (277 bbls), increase to 1100 psi, hold 10 minutes, bleed off and check floats- held. Note: Had 200 bbls of good 10.7 cement to surface. Full returns. 21:15 21:45 0.50 3,150 3,150 SURFA( CEMEN" OTHR us su aceegwpment. 21:45 22:15 0.50 3,150 3,150 SURFA( CEMEN" RURD P Rig down cement head and cementing line. Vacuum out landing ~oint. ~~ ~~~e 7 tsfi 37 • Time Logs - Date From _ - To - Dur S_De~th E. Depth Phase Code Subcode - T --- Comment __ 22:15 _ 00:00 1.75 3,150 3,150 SURFA( CASING RURD P Nipple down diverter line. Break bolts on the adapter and at the hydril. frig down TESCO casin runnin tool from rig floor. Cleaning rockwasher and its. 1 /03/2009 N/D Diverter, PU diverter, center 10-3/4" casing in conductor, wrap FMC slips (CPAI part # 10935401) around casing, drop slips down to landing ring, with 210k on weight indicator-slack off transferring weight to slips, cut drain hole in jt # 76, drain 9.4 ppg mud from joint, RU Wach's cutter, cut casing 6-1/2" above top of landing ring, pull landing joint and cut off jt to the floor, remove Dowell x-o, lay down landing joint. Finish removing diverter equipment, set equipment in cellar. Prepare to install FMC transition, use Hot head f/ pre heat, weld transition, use hot head for post heat, wrap with insulation to cool. Tested choke manifold to 250 psi low and 5000 psi high. Witness of test waived by AOGCC inspector Chuck Scheve. Test weld on transition to 1650 psi for 10 minutes- good. Nipple up FMC 11" 5m casing spool with lower annulus valve oriented parallel to flowline. Orient FMC 11" 5m tubing spool 60 deg offset to lower annulus. Confirm with drill site operator (Mike Alston) on orientation, pick up and orient tubing spool 30 deg offset of the lower valve. Nipple up heads, DSA, riser, PU BOP stack to install. 00:00 00:30 0.50 3,150 3,150 SURFA( CASING RURD P Continue to Nipple down diverter line, breaking bolts on diverter Tee and quick connect. Pick stack with riser attatched up into rotary table o enin . 00:30 01:15 0.75 3,150 3,150 SURFA( CASING OTHR P Center 10-3/4" casing in the conductor. 01:15 02:15 1.00 3,150 3,150 SURFA( CASING OTHR P Wrap slips (CPAI part # 10935401) around 10-3/4" casing (OD was measured to be 10.85"), drop slips into landing ring and push down to load shoulder. Slack off f/ 210k on weight indicator to transfer weight to the emergency slips. Weight was taken immediately. Blocks & top drive wei ht= 75k. 02:15 03:30 1.25 3,150 3,150 SURFA( CASING OTHR P Cut drain hole to drain joint #76 of 9.4 ppg mud. RU Wach's cutter and cut joint # 76 @ 6-1/2" above the top of the landing ring. Measure cut off--which was 5.13' of joint # 76. Note: LDS and load shoulder are at same depth. Top of landing ring is .40' (4-3/4") above the top of load shoulder, Wach's cut @ .53' (6-1/2") above top of landing ring/ or .93' above load shoulder. The transition will slip 4" over cutoff, leaving 2-1 /2" gap for welder to work with betwen the top of starting head and outside weld oint on the transition. 03:30 04:15 0.75 3,150 3,150 SURFA( CASING RURD P Pull cutoff joint to floor with joint # 77, remove Dowell crossover for the cement head. Remove Sperry Sun short tools from pipe shed via beaver slide. Rig up to test choke manifold. Cleanin its. 04:15 05:45 1.50 3,150 3,150 SURFA( WELCTI NUND P Finish ND diverter equipment in cellar. Set pieces on matting in cellar. Vacuum out cellar box, and removed 4" valves from conductor. ~ ~~;~ 8 of 37 • Time Logs Date From To Dur S. Depth E. De th Phase Code Subcode T Comment __ __. 05:45 06:00 0.25 3,150 3,150 SURFA( WELCTI OTHR P RU to pre heat surface casing with re heat hot head. 06:00 08:30 2.50 3,150 3,150 SURFA( WELCTI OTHR P Install hot head inside of the 10-3/4" cuttoff. Light hot head, pre heat casing to 600 deg. Rig welder welded FMC transition to cuttoff jt (Mark Adam's FMC rep), install post heat hot head, ignite hot head, wrap with insulation to cool down for 8-10 hrs. 08:30 18:00 9.50 3,150 3,150 SURFA( WELCTI OTHR P While waiting for wellhead adapter to cool cleaned pits, loaded shed with 3 1/5" tbg, clean and organize rig, test choke manifold valves 1-18 to 250 psi low and 5000 psi High -all tested good. AOGCC rep Chuck Sheeve waived witnessin test 18:00 19:00 1.00 3,150 3,150 SURFA( WELCTL OTHR P Continue letting transition adapter cool off. 19:00 19:30 0.50 3,150 3,150 SURFA( WELCTI BOPE P Check temp of transition to be 104 deg Farenheit. Rig up and test to 1650 psi with nitrogen. Hold test for 10 minutes. Good test witnessed by FMC rep Mark Adams and CPAI rep Granville Rizek and Rand Dexter. 19:30 22:30 3.00 3,150 3,150 SURFA( WELCTL NUND P Ni le up casing head, nipple up tubing spool. Orient FMC 11" 5m casing head with annulus valve to be parallel to flow lines- pointed to the North. Orient FMC 11" 5m tubing head 60 degrees offset of annulus valve. Called drill site operator (Mike Alston) to inform that we cannot orient according to drawing provided. Drill site operator agreed to orient upper annulus valves 30 deg offset (Counterclockwise) of the lower annulus. Pickup FMC tubing spool and set to 30 de ree offset. 22:30 23:30 1.00 3,150 3,150 SURFA( WELCTL NUND P Install nuts on studs of tubing head. Measure rig floor to Upper LDS 35.65', Lower LDS 37.90', LDS on startin head 41.30' 23:30 00:00 0.50 3,150 3,150 SURFA( WELCTL NUND P Install 11" 5M x 13-5/8" DSA, install 13-5/8" riser, Pickup BOP stack with brid a crane. 1 /04/2009 Finish nipple up of 13-5/8" 5m BOPE, rig up to test BOPE, test 250 psi low and 5000 psi high except for annular, test annular to 250 psi and 3500 psi, test top drive IBOP's, test accumulator (Choke manifold tested 1/3/09) (witness of test waived by AOGCC inspector Chuck Scheve), Rig down testing equipement, set FMC wear bushing, PU/MU BHA #2, RIH to 3054', circulate bottom's up, test casing to 2500 psi for 30 minutes, drillin float collar 3064'. I~a~~ 9 0# 37 \.I Time Logs Date From To Dur S De th E_ De th Phase Code Subcode T Comment __ 00:00 05:15 5.25 3,150 3,150 SURFA( WELCTI NUND P Continue to NU BOPE. Test metal to metal seal on casing head to transition to 1000 psi /10 min- good test. Obtain measurements and modify riser to fit taller wellhead. Reposition BOP stack due to taller well head. Finish NU BOPE 05:15 06:15 1.00 3,150 3,150 SURFA( WELCTL NUND P RU to test BOPE. Set lower test plug, fill stack with water, prepare chart recorder and hoses. 06:15 08:00 1.75 3,150 3,150 SURFA( WELCTI NUND P Continue to nipple up BOPE. Continue to RU to test BOPE. 08:00 12:30 4.50 3,150 3,150 SURFAC WELCTL BOPE P Test BOPE w 5" test jt, hydril to 250 psi low and 3000 psi ig ,Test upper (3-1/2" x 6" variable) and lower (5") pipe rams, choke & kill HCRs & manual 4" valves on kill line and blind rams to 250 psi low and 5000 psi high. all tested good. Accumulator tested -good AOGCC rep Chuck Scheve waived witnessing test. Note: Choke manifold was tested 1/3/2009 while doing wellhead work with welder and letting transition cool to test. 12:30 13:30 1.00 3,150 3,150 SURFA( WELCTI BOPE P Rig down and blow down BOPE test equipment & install FMC wear ring 10.86" OD @ top 10.38" OD at bottom x 9.9375" x 38" Ion . 13:30 14:00 0.50 3,150 3,150 SURFA( DRILL RURD P Rig up to pickup BHA # 2. 14:00 14:15 0.25 3,150 3,150 SURFA( DRILL SFTY P Pre job safety meeting on PU BHA #2. 14:15 15:15 1.00 3,150 3,150 SURFA( DRILL PULD P Make up BHA # 2 to 109'. 15:15 16:15 1.00 3,150 3,150 SURFAC DRILL OTHR P POOH to 49' to upload MWD, upload same. 16:15 17:15 1.00 3,150 3,150 SURFA( DRILL DHEQ P Trip in the hole to 139'. Shallow pulse test MWD. Pumping 625 gpm w/ 1310 si- 60%. Eve thin looks ok. 17:15 18:00 0.75 3,150 3,150 SURFA( DRILL TRIP P Pull out of the hole to 109' and continue to make up BHA #2 to 130'. Pull up to 60', then load nuke sources. Tri into 130'. 18:00 18:30 0.50 3,150 3,150 SURFA( DRILL PULD P Continue to make up BHA #2 to 685'. 18:30 19:30 1.00 3,150 3,150 SURFA( DRILL TRIP P Trip in the hole on elevators to 2969'. Monitor displacements on the trip tank. Record PU & SO wt's every 10 stands. 19:30 19:45 0.25 3,150 3,150 SURFA( DRILL DHEQ P Test Sperry Sun MWD, pumping 605 gpm w/ 2110 psi-51 % flow out. Good test. 19:45 20:00 0.25 3,150 3,150 SURFA( DRILL REAM P Wash to 3054'. Tagged up on cement strin ers. 20:00 20:15 0.25 3,150 3,150 SURFA( DRILL CIRC P Obtain slow pump rates. #1 mp 20 spm w/ 100 psi, 30 spm w/ 170 psi. #2 mp 20 spm w/ 90 psi, 30 spm w/ 160 si. ~~~~_ ?~~~ d2 €~f 37 Time Logs Date From To Dur S De th E. De th Phase Code _ Subcode T Comment --- - - 20:15 20:45 - 0.50 3,150 3,150 SURFA( DRILL _ CIRC P _ Circulate bottom's up, pumping 620 gpm w/ 2100 psi- 59% flow out. Rotate 30 rpm w/ 6-7k ft Ibs of torque. PU wt 160k, SO wt 140k, Rot wt 155k. Circulated 347 bbls. 20:45 21:00 0.25 3,150 3,150 SURFA( DRILL TRIP P Pull out of the hole to 2968'. Stand back a stand. Blow down the top drive. 21:00 21:30 0.50 3,150 3,150 SURFAC CASING DHEO P Rig up to test the 10-3/4" 45.5 ppf L-80 BTC surface casing set @ 3149' 2805' TVD . 21:30 21:45 0.25 3,150 3,150 SURFA( CASING DHEO P Fill lines to remove air from system. 21:45 22:45 1.00 3,150 3,150 SURFA( CASING DHEO P Pressure test casing to 2500 psi, hold for 30 minutes, chart test. Good test. 22:45 23:00 0.25 3,150 3,150 SURFAC CASING DHEO ig own testing equipment. 23:00 23:15 0.25 3,150 3,150 SURFA( CEMEN' DRLG P Wash down from 2968' to 3062'. Pumping 605 gpm w! 2110 psi-57% flow out. 23:15 00:00 0.75 3,150 3,150 SURFA( CEMEN" DRLG P Drilling on float collar @ 3064'. 1 /05/2009 Finish drilling float collar @ 3064', cement, float shoe, 20' new hole to 3170', circulate bottom's up, displace to new 9.2 ppg LSND mud, Perform FIT to 16.2 ppg, PWD baseline, directional drill 9-7/8" intermediate from 3170' to 4778', circulate a 38 bbls weighted sweep (10.3 ppg/ 250 vis) ,reduced ECD's from 10.75 ppg to 10.28 , continue to drill 9-7/8" intermediate to 5149' at midni ht. 00:00 01:15 1.25 3,150 3,150 SURFA( CEMEN' DRLG P Drilling on float collar @ 3064', then cement, float shoe @ 3150'. Pumping 700 gpm w/ 2570 psi- 64% flow out. Rotate 80 rpm w/ 8k ft Ibs of for ue. 6k wei ht on bit. 01:15 01:45 0.50 3,150 3,170 SURFA( DRILL DDRL P Drill 20' of new hole from 3150' to 3170'. Max gas units observed 36 units. 01:45 02:15 0.50 3,170 3,170 SURFA( DRILL CIRC P Circulate bottom's up. Rotate 80 rpm w/ 7k ft Ibs of torque. Max gas observed 22 units. 02:15 03:00 0.75 3,170 3,170 SURFAC DRILL CIRC P Displace to 9.2 ppg 46 vis LSND mud. Circulated a total of 607 bbls 03:00 03:15 0.25 3,170 3,170 SURFAC DRILL CIRC P Obtain slow pump rates. 03:15 03:45 0.50 3,170 3,170 SURFA( DRILL FIT P Pull up inside casing. Rig up for FIT/LOT. Clear lines of air. 03:45 04:30 0.75 3,170 3,170 SURFA( DRILL FIT P Perform FIT. 9.2 ppg MW, 44 vis. Pressure to 1020 psi, bleed down to 790 psi in 10 minutes. 3170' MD= 2819.7'TVD, pumped 45 gal, bleed back 35 al. 16.2 FIT. 04:30 04:45 0.25 3,170 3,170 SURFA( DRILL FIT P Rig down testing equipment. 04:45 05:45 1.00 3,170 3,170 INTRM1 DRILL OTHR P Pick up single, perform PWD baseline. Pumping 650 gpm w/ 1650 psi-60% flow out, 80 rpm w/ 7k ft Ibs of torque, 700 gpm w/ 1730 psi-62% flow out, 100 rpm w-8k ft Ibs of torque, 750 gpm w/ 2010 psi- 63% flow out, 120 rpm w/ 7-8k ft Ibs of for ue. Run in the hole to 3170'. ~~ rave 11 of 37 • Time Logs __ __ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 05:45 06:00 0.25 3,170 3,217 INTRM1 DRILL DDRL P Drill 9-7/8" intermediate f/ 3170' to 3217'. Epoch max gas 1~5 units observed. TOTCO max gas 15 units observed. 06:00 12:00 6.00 3,217 3,947 INTRM1 DRILL DDRL P Drill 9-7l8" intermediate f/ 3217' to 3947. Epoch max gas 177 units observed. TOTCO max gas 1343 units observed. 12:00 18:00 6.00 3,947 4,588 INTRM1 DRILL DDRL P Drill 9-7/8" intermediate f/ 3947' to 4588'. Epoch max gas 155 units observed. TOTCO max gas 245 units observed. Clean hole ECD's 10.3 18:00 19:15 1.25 4,588 4,778 INTRM1 DRILL DDRL P Drill 9-7/8" intermediate f/ 4588' to 4778'. Epoch max gas 158 units observed. TOTCO max gas 162 units observed. 19:15 20:45 1.50 4,778 4,778 INTRM1 DRILL CIRC P Circulate to clean hole/ reduce ECD's. Pump a 38 bbl weighted sweep (10.3 ppg/ 250 vis), while backreaming. Backreamed from 4778' to 4590'. Circulate ECD's down from 10.75 ppg to 10.28 ppg. No significant increase in cuttings. PU wt 195K, SO wt 155k, both before and after um in swee . 20:45 21:00 0.25 4,778 4,778 INTRM1 DRILL TRIP P Trip in the hole. 21:00 00:00 3.00 4,778 5,159 INTRM1 DRILL DDRL P Drill 9-7/8" intermediate f/ 4778' to 5159'. Epoch max gas 47 units observed. TOTCO max gas 130 units observed. 1 /06/2009 Continue to directional drill 9-7/8" intermediate from 5149' to 9895', problem with Sperry Sun logging tools, circulate two bottom's up (1082 bbls) while reciprocating pipe f/ 6872' to 6779', pull out of the hole on elevators from 6779' to 4115', pulling tight f/ 4300' to 4115' (25k over) (light swabbing). Calculated displacement 30 bbls, actual 24 bbls. Backream out from 4115' to 3924'-- pumping 790 gpm w/ 2950 psi, rotating 120 rpm w/ 9k ft Ibs of for ue. De th midni ht 3924'. 00:00 06:00 6.00 5,159 5,825 INTRMI DRILL DDRL P Drill 9-7/8" intermediate f/ 5159' to 5825'. Epoch max gas 216 units observed. TOTCO max gas 130 units observed. Note: Pumped a 40 bbl weighted hi-vis sweep(10.3 ppg/250 vis) @ 5444', slight increase at shakers. Slight decrease in ECD's. PU wt and SO wt remained the same before and after sweep 213k, 158k. Torque dropped from 12-13k ft Ibs to 10k ft lbs. 06:00 12:00 6.00 5,825 6,395 INTRMI DRILL DDRL P Drill 9-7/8" intermediate f/ 5825' to 6395'. Epoch max gas 184 units observed. TOTCO max gas 485 units observed. ~~~; 12 €s~ 3~ Time Logs Date - Frorn - To ____ Dur S. De th E. De th Phase Code Subcode T Cornment ___ __ 12:00 18:00 ____ 6.00 6,395 6,871 INTRM1 ___ DRILL DDRL P Drill 9-7/8" intermediate f/ 6395' to 6871'. Epoch max gas 646 units observed. TOTCO max gas 3132 units observed. Note: Pumped a 40 bbl weighted hi-vis sweep (10.3 ppg/250 vis) @ 6740', slight increase at shakers. Slight decrease in ECD's (10.55 to 10.32 ppg). Pump pressure decreased 300 psi when sweep rounded bit. 18:00 18:30 0.50 6,871 6,895 INTRM1 DRILL DDRL P Drill 9-7/8" intermediate f/ 6871~to 6895'. Epoch max gas 156 units observed. TOTCO max gas 249 units observed. 18:30 19:45 1.25 6,895 6,895 INTRM1 DRILL CIRC T Circulate two bottom's up (pumped 1082 bbls) prior to pull out of the hole for MWD/LWD failure of a sensor. Stand back a stand. Rotate and reciprocate from 6872' to 6779'. Rotate 120 rpm w/ 13k ft Ibs of torque. Pumping 790 gpm w! 3280 si. 19:45 20:15 0.50 6,895 6,895 INTRM1 DRILL CIRC T Acquire slow pump rates. monitor well, blow down the to drive. 20:15 23:00 2.75 6,895 6,895 INTRM1 DRILL TRIP T Pull out of the hole on elevators from 6779' to 4115'. Pulled tight from 4300' to 4115' (20-25k overpull and light swabbing. Calculated displacement 30 bbls actual 24 bbls. 23:00 00:00 1.00 6,895 6,895 INTRM1 DRILL REAM T Backream out of the hole due to overpull. Pumping 790 gpm w/ 2950 psi- 64% flow out. Rotate 120 rpm w/ 9k ft Ibs of for ue. 1 /07/2009 Continue to Backream out from 3924' to 3064' pumping 790 gpm w! 2950 psi, rotating 120 rpm w/ 9k ft Ibs of torque. Blow down the top drive, monitor well on the trip tank- static. Service rig, Pull out of the hole on elevators from 3064' to 2970' (swabbing), continue to backream pumping 620 gpm w/ 1890 psi, rotating 40 rpm w/ 5k ft Ibs of torque, pulling speed 5'/min f/ 2970' to 2782', pull out on elevators from 2782', clean floor, PJSM on nukes, remove sources, UD BHA #2, PU BHA #3, upload MWD, RIH to 293', slip & cut drilling line- service rig, POOH to 109', load nucke sources, continue to MU BHA #3 to 664', RIH to 6653', MAD pass logging f/ 6674' to 6688' bit depth, RIH to MAD pass 6767' to 6895', directional drill 9-7/8" intermediate to 7077' at midni ht. 00:00 02:00 2.00 6,895 6,895 INTRM1 DRILL REAM T Continue to Backream out from 3924' to 3064' pumping 790 gpm w/ 2950 psi, rotating 120 rpm w/ 9k ft Ibs of for ue. 02:00 02:15 0.25 6,895 6,895 INTRM1 DRILL OTHR T Blow down the top drive, monitor well on the tri tank- static. 02:15 03:00 0.75 6,895 6,895 INTRM1 RIGMNT SVRG P Service rig (grease crown, drawworks, to drive and blocks). 03:00 03:15 0.25 6,895 6,895 INTRM1 DRILL TRIP T Pull out of the hole on elevators from 3064' to 2970' swabbin 03:15 04:00 0.75 6,895 6,895 INTRM1 DRILL REAM T Continue to backream pumping 620 gpm w/ 1890 psi, rotating 40 rpm w/ 5k ft Ibs of torque, pulling speed 5'/min f/ 2970' to 2782', pull out on elevators from 2782'. ~ ~''£d C~£? ~ ~ £T~ ~7 ~~ • Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment _ _ 04:00 06:00 2.00 6,895 6,895 INTRM1 DRILL TRIP T Pull out of the hole on elevators from 2782' to 225' 06:00 06:30 0.50 6,895 6,895 INTRMI DRILL OTHR T Clean floor prior to crew change, before PJSM on handling nuke sources. 06:30 06:45 0.25 6,895 6,895 INTRM1 DRILL SFTY T PJSM on handling nuke sources. 06:45 07:15 0.50 6,895 6,895 INTRM1 DRILL TRIP T Stand back BHA from 224' to 110' 07:15 09:15 2.00 6,895 6,895 INTRM1 DRILL RURD T Remove nuclear source from MWD. Continue to LD BHA, and download MWD. Inspect bit and motor -both ood 09:15 09:45 0.50 6,895 6,895 INTRM1 DRILL RURD T PU BHA #3 per DD to 109' 09:45 12:00 2.25 6,895 6,895 INTRM1 DRILL RURD T Upload MWD shallow test same - 610 m 1170 si ood test 12:00 12:30 0.50 6,895 6,895 INTRM1 DRILL TRIP T PU Stand of HWDP, RIH to 293' BD/TD 12:30 13:45 1.25 6,895 6,895 INTRM1 RIGMNT SVRG P Cut and slip Drill line and service rig. PJSM was held while uploading MWD 13:45 14:15 0.50 6,895 6,895 INTRMI DRILL TRIP T POOH from 293' to 109' 14:15 14:30 0.25 6,895 6,895 INTRM1 DRILL RURD T Load nuclear sources into MWD 14:30 14:45 0.25 6,895 6,895 INTRMI DRILL TRIP T Continue PU BHA #3 from 109' to 664' -monitor well on tri tank 14:45 15:45 1.00 6,895 6,895 INTRM1 DRILL RURD T TIH from 664' to 3136' monitor on trip tank, record T & D eve 10 stds 15:45 17:30 1.75 6,895 6,895 INTRM1 DRILL RURD T CBU at 785 gpm, 2550 psi, 50 rpm, 7K torq. Pumped 6.9 BU or 1552 bbls. 17:30 18:00 0.50 6,895 6,895 INTRM1 DRILL RURD T TIH from 3136' to 4850' monitor on trip tank, fill pipe every 25 stds, record T & D eve 5 stds 18:00 19:45 1.75 6,895 6,895 INTRM1 DRILL TRIP T TIH from 4850' to 6657' monitor on trip tank, fill pipe every 25 stds, record T & D eve 5 stds 19:45 20:00 0.25 6,895 6,895 INTRM1 DRILL OTHR T Make a top drive connection on stand # 64. Mad pass logging from 6674.65'bit depth to 6687.65' bit depth. Sensor is 82.65' behind bit. Max 200 fph. Pumping 653 gpm w/ 2560 psi- 61 % flow out. Rotate 120 rpm w/ 13k ft Ib of torque. Trip into 6753' 20:00 21:00 1.00 6,895 6,895 INTRM1 DRILL OTHR T Make a top drive connection on stand # 65. MAD pass logging from 6767.65' bit depth' to 6895' bit depth. Sensor is 82.65' behind bit. Max 200 fph. Pumping 653 gpm w/ 2560 psi- 61 % flow out. Rotate 120 rpm w/ 13k ft Ib of torque. Note: All data from Sperry Sun Bat tool was able to be read at the Sperry Sun shop in Deadhorse, area of possible tool failure was MAD to ed. ~~ - - ~~ar~~ i~ €sf 3t Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 21:00 00:00 3.00 6,895 7,077 INTRM1 DRILL DDRL P Drill 9-7/8" intermediate f! 6895' to 7077'. Epoch max gas 91 units observed. TOTCO max gas 278 units observed. Note Max gas on bottom's up 440 units EPOCH, 2055 units TOTCO. 1 /08/2009 Drill 9-7/8" intermediate f/ 7077' to casing running point of 7490'. circulate 1594 bbls- condition hole, monitor well, bring Frank's casing slips to floor, perform 10 stand short trip to 6564', monitor well- static, trip in the hole to 7490', circulate and condition mud and hole f/ 7-5/8" casing, increase mud weight from 9.3 ppg to 9.5 ppg, take slow pump rates, monitor well- static, pump a dry job. Pull out of the hole from 7490' to 2915'. monitor well- slight flow then static after 45 minutes, continue to pull out of the hole to BHA @ 661', monitor well- slight flow- static after 5 miutes. Work BHA #3, PJSM on removing nuke sources, remove sources, lay down flex drill collars, download MWD/LWD, lay down BHA #3, clean floor, pull wear bushing, set test plug- engage lockdown screws. Changing top and bottom rams to 7-5/8", rigging up to test, rigging up TESCO casing running tool to run casing. Fill stack with water, rigging up to test Annular, top and bottom pipe rams with 7-5/8" test'oint. 00:00 04:30 4.50 7,077 7,490 INTRM1 DRILL DDRL P Drill 9-7/8" intermediate f/ 6895' to 7490'. Epoch max gas 466 units observed. TOTCO max gas 1572 units observed. 04:30 05:45 1.25 7,490 7,490 INTRM1 DRILL CIRC P Circulate 1594 bbls while circulating to condition mud and hole for 10 stand short trip. Obtain slow pump rates. Pumping 790 gpm w/ 3410 psi-64% flow out. Rotate 120 rpm w/ 13k ft Ibs of torque. Reciprocate from 7490' to 7416'. ECD's prior to circulating were 10.1 ppg, after 9.84 05:45 06:15 0.50 7,490 7,490 INTRM1 DRILL OWFF P Blow down top drive. Observe well f! flow- static. 06:15 07:15 1.00 7,490 7,490 INTRM1 DRILL TRIP P Pull out of the hole on elevators, monitor well on the trip tank, record PU & SO wt's every 10 stands. Calculated fill 8 bbls, actual 10 bbls. 07:15 07:30 0.25 7,490 7,490 INTRM1 DRILL OWFF P Blow down top drive. Observe well f/ flow- static. 07:30 07:45 0.25 7,490 7,490 INTRM1 DRILL TRIP P Trip in the hole. Monitor well on the tri tank. 07:45 10:15 2.50 7,490 7,490 INTRM1 DRILL CIRC P Make a top drive connection. circulate and condition mud and hole for 7-5/8" 29.7 ppf L-80 Hyd 563 casin .Pumping 790 gpm w/ 3440 psi. Rotate 120 rpm w! 12-13K ft Ib of torque. Reciprocate from 7490' to 7416'. Circulated a total of 2640 bbls. Epoch max gas 982 units observed. TOTCO max gas 3154 units observed. Raised MW up to 9.5. Pumped 50 bbl, 10.3 ppg/250 vis sweep w/ moderate increase in cuttings after one bottom's up. Note: Lube 776/Lotorq was added to mud after well was TD for casin drilling (7490')--and Myacide for bacteria revention. l~~~~ 1 a cif 37 Time Logs __ Date From To bur S. Depth E. Death Phase Code Subcode T Cori~ment 10:15 11:00 0.75 7,490 7,490 INTRMI DRILL CIRC P Obtain SPR @7490', monitor well, um 25 bbl slu 11:00 13:00 2.00 7,490 7,490 INTRM1 DRILL TRIP P POOH from 7490' to 2915' Monitoring on Tri tank. 13:00 14:15 1.25 7,490 7,490 INTRM1 DRILL OWFF P Monitored well -observed slight flow. continued monitoring on trip tank for flow--slowed to static after 45 min. 14:15 15:00 0.75 7,490 7,490 INTRM1 DRILL TRIP P Continue POOH from 2941' to 661' . Monitorin well on Tri tank. 15:00 15:15 0.25 7,490 7,490 INTRM1 DRILL OWFF P Monitored well, slight flow, static after 5 min. 15:15 15:45 0.50 7,490 7,490 INTRM1 DRILL TRIP P Continue POOH working BHA #3, from 661' to 138' 15:45 16:00 0.25 7,490 7,490 INTRM1 DRILL RURD P PJSM on removing nuclear source / removed source from MWD 16:00 18:30 2.50 7,490 7,490 INTRM1 DRILL TRIP P LD Flecx DC, Download MWD continue LD BHA 18:30 19:30 1.00 7,490 7,490 INTRM1 WELCTL OTHR P Pull FMC wear bushing, drain stack, set FMC test plug, set lockdown screw on test plug. Rigged up to fill hole and monitor annulus below test plug' Use # 2 mud pump to keep hole full and monitor same. 19:30 19:45 0.25 7,490 7,490 INTRM1 WELCTL SFTY P Pre job safety meeting on changing rams to 7-5/8". 19:45 22:30 2.75 7,490 7,490 INTRM1 WELCTL OTHR P Change upper and lower pipe rams to 7-5/8" for runnin casin . 22:30 23:00 0.50 7,490 7,490 INTRMI WELCTL OTHR P Rig up Tesco casing running tool while still changing top and bottom i e rams to 7-5/8". 23:00 00:00 1.00 7,490 7,490 INTRM1 WELCTL OTHR P Rig up testing equipment, fill stack with water. 1 /09/2009 Test Annular, top and bottom pipe rams with 7-5/8" test joint. Test annular to 250 psi low and 3500 psi high, test upper and lower rams to 250 psi low and 5000 psi high, holding each test for 5 minutes, chart test. Rig down testing equipemtn, rig up to run 7-5/8" casing with TESCO casing running tool and Frank's flush mounted slips. Pre job safety meeting on running casing. Run 7-5/8" 29.7 ppf L-80 Hyd 563 casing: Run jt # 1 with Hughes 9-7/8" bit/shoe (EZC403ZX, ser # 7016146) and two TESCO crimp on centralizers (10' and 20' above shoe), another joint with a TESCO crimp on centralizer 5' above pin, Weatherford Model 402DS double valve float collar and then joint # 3. Circulate through shoe track. Pumping 250 gpm w/ 1330 psi- 36% flow out. PU wt 78k, SO wt 82k, Blocks 75k. Continue to run joiints with centralizers 5' above pin to joint # 24 (Total of 25 crimp on centralizers). Continue to run casing to 1759', crew change & pre job safety meeting, continue running casing to 3120', circulate bottom's up, mid job safety meeting, continue running casing to 5412', circulate bottom's up, continue to run casing to 5830', circulate bottom's up, continue to run casing to TD @ 7490'. Blow down the top drive, rig up f! LOT, perform LOT to 12.7 ppg, rig down testing equipment. Drill with casin from 7490' to 7640'. 00:00 01:30 1.50 7,490 7,490 INTRM1 WELCTL BOPE P Test Annular to 250 psi low and 3500 si high with 7-5/8" test joint. Test upper and lower pipe rams (7-5/8") to 250 psi low and 5000 psi high. Hold tests for 5 minutes, chart test. 01:30 02:00 0.50 7,490 7,490 INTRMI WELCTL OTHR P Rig down testing equipment, blow down test hose. Pull FMC test lu . 02:00 02:30 0.50 7,490 7,490 INTRM1 CASING RURD P Ri u to run 7-5/8" 29.7 f L-80 H /d 563 casing with TESCO casing running tool and Franks flush mounted sli s. F~y€~ 16 of 37 Time Logs Date From To Dur S De th_ E. Depth Phase Code Subcode T Comment _ __ _ _ 02:30 02:45 0.25 7,490 7,490 INTRM1 CASING SFTY P Pre job safety meeting on running casin . 02:45 06:00 3.25 7,490 7,490 INTRM1 CASING RNCS P Run 7-5/8" 29.7 ppf L-80 Hyd 563 casing_with TESCO casing running tool and Franks flush mounted slips. Run ' # bit/shoe EZC403ZX, ser # 7016146) and two TESCO crimp on centralizers (10' and 20' above shoe), another joint with a TESCO crimp on centralizer 5' above pin, Weatherford Model 402DS double valve float collar and then joint # 3. Circulate through shoe track. Pumping 250 gpm w/ 1330 psi- 36% flow out. PU wt 78k, SO wt 82k, Blocks 75k. Continue to run joiints with centralizers 5' above pin to joint # 24 (Total of 25 crimp on centralizers). Jt # 38 in the hole @ 0600 hrs. Pipe dis alcement correct. 06:00 06:30 0.50 7,490 7,490 INTRM1 CASING RNCS P Continue running 7 5/8" csg to Jt # 40 in the hole (1675'). At 1675', pumping 250 gpm, 1430 psi, 36% FO: PU 113, SOW 115, ROW 115, 3K Ft Ibs tq. Run in hole to jt # 42 1759' . 06:30 06:45 0.25 7,490 7,490 INTRM1 CASING SFTY P Crew Change PJSM on running csg 06:45 08:30 1.75 7,490 7,490 INTRM1 CASING RNCS P Continue running 7 5/8" casing with TESCO casing running tool and Franks flush mounted slips to Jt # 75 in the hole (3120'). Record Trq & Dra eve 20 Jts. 08:30 08:45 0.25 7,490 7,490 INTRM1 CASING CIRC P CBU @ 250 gpm, 1520 psi, 36% FO. Pumps on: PU 142K, SO 137K, ROT 140K TRQ 4K. Pumps Off: PU 148K, SO 139K, ROT 144K TRQ 4K 08:45 09:00 0.25 7,490 7,490 INTRMI CASING SFTY P Mid Job Safety Meeting 09:00 12:00 3.00 7,490 7,490 INTRMI CASING RNCS P Continue running 7 5/8" casing with TESCO casing running tool and Franks flush mounted slips to Jt # 130 in the hole (5412'). Record Trq & Dra eve 20 Jts. 12:00 12:45 0.75 7,490 7,490 INTRMI CASING CIRC P CBU @ 250 gpm, 1610 psi, 36% FO. Pumps on: PU 191 K, SO 158K, ROT 171 K TRQ 8K. Pumps Off: PU 202K, SO 161 K, ROT 182K TRQ 8K 12:45 13:00 0.25 7,490 7,490 INTRMI CASING RNCS P Continue running 7 5/8" casing with TESCO casing running tool and Franks flush mounted slips to Jt # 140 in the hole (5830'). Record Trq & Dra eve 20 Jts. 13:00 13:30 0.50 7,490 7,490 INTRM1 CASING CIRC P CBU @ 250 gpm, 1620 psi, 36% FO. Pumps on: PU 202K, SO 161 K, ROT 178K TRQ 9K. Pumps Off: PU 214K, SO 169K, ROT 189K TRQ 9K ~___.~ Page 17 s~f ~7 Time Logs ____ _ From To Dur S. De th E. Depth Phase Code Subcode T .Comment ____ Date _ _ 13:30 15:30 2.00 7,490 7,490 INTRM1 CASING RNCS P Continue running 7 5/8" casing with TESCO casing running tool and Franks flush mounted slips to Jt # 180 in the hole (7490'). Record Trq & Dra eve 20 Jts. 15:30 18:15 2.75 7,490 7,490 INTRM1 CASING CIRC P CBU @ 250 gpm, 1800 psi, 36% FO. Pumps on: PU 235K, SO 179K, ROT 202K TRO 13-14K. Pumps Off: PU 250K, SO 180K, ROT 210K TRO 14-15K. 1013 Total bbls um ed. 18:15 19:15 1.00 7,490 7,490 INTRM1 CASING RURD P Blow down the top drive and rig up for LOT. 19:15 19:45 0.50 7,490 7,490 INTRM1 DRILL LOT P Perform LOT- 9.6 MW 3149, TVD 2805' break over @ 445 psi EMW 19:45 20:00 0.25 7,490 7,490 INTRM1 CASING RURD P Rig down from LOT. 20:00 00:00 4.00 7,490 7,640 INTRM1 CASING DCSG P Drill with 7 5/8' casing from 7490' to 7640'. Drill with 250 gpm w/ 1540 psi on bottom, 1480 psi off bottom-36% flow out. Rotate 80 rpm w/ 18k ft Ibs of torque on bottom, 15k off bottom. Pumps off: PU wt 250k, SO wt 211k, Rot wt 225k. Pumps on: PU wt 215k, SO wt 211, Rot wt 220k. Note: Bit has (3) 10/32" nozzles and a 1"shear disc set for 4000 si. 1 /10/2009 Drill with 7-5/8" 29.7 ppf L-80 Hyd 563 casing from 7640' to 7656', circulate two bottom's up to even mud weight (9.6 ppg in and 9.6+ppg out), rig up to test formation, perform a leakoff test: Leak off at 705 psi = 14.4 ppg EMW, rig down testing equipment. Continue to drill with 7-5/8" 29.7 ppf L-80 Hyd 563 casing to 7698', circulate bottom's up (EPOCH gas was up to 963 units while drilling at 7698', TOTCO gas 4963 units), continue to drill with 7-5/8" 29.7 ppf L-80 Hyd 563 casing to 7781', circulate bottom's up for samples, drill to 7790', circulate for samples, drill to 7800', circulate for samples, drill to 7815', circulate for samples, drill to 7835', circulate for sam les, dis lace mud from 9.6 to 11.5 00:00 00:30 0.50 7,640 7,656 INTRM1 CASING DCSG P Drill with 7 5/8' casin from 7640' to 7656'. Weight on bit 6 to 9k. Drill with 250 gpm w/ 1540 psi on bottom, 1480 psi off bottom-36% flow out. Rotate 80 rpm w/ 18k ft Ibs of torque on bottom, 15k ft Ibs off bottom. Pumps off: PU wt 250k, SO wt 211 k, Rot wt 225k. Pumps on: PU wt 215k, SO wt 211, Rot wt 220k. EPOCH gas observed 280 units. Note: Bit has (3) 10!32" nozzles and a 1"shear disc set for 4000 si. 00:30 02:30 2.00 7,656 7,656 INTRM1 CASING CIRC P Circulate and condition mud and hole for Leak off test. Mud wt in 9.6, MW out 9.6+. Pumping 250 gpm w/ 1460 psi-36% flow out. Rotate 80 rpm w/ 15 k ft Ibs of torque. Circulated a total of two bottom's u 650 bbls). 02:30 03:00 0.50 7,656 7,656 INTRM1 DRILL LOT P Rig up to perform a leak off test @ 7656'. ~ ~ Paq~ 1~ ~t 3;' ~. ~._... _ ~ ~ 1~~~4~ S~as~ l J Time Logs _ Date From To Dur S De th E. De th Phase Code Subcode T Comment __ _ __ 03:00 03:30 0.50 7,656 7,656 INTRM1 DRILL LOT P Perform LOT: 9.6 MW, 3149 shoe de th & TVD 2805', break over (cil 760 si, leak off 705 si = EMW 14.4 pp . Note: Held 760 psi after 10 minutes. 03:30 03:45 0.25 7,656 7,656 INTRM1 DRILL LOT P Rig down after leak off test @ 7656'. 03:45 05:15 1.50 7,656 7,698 INTRM1 CASING DCSG P Drill with 7 5/8' casing from 7656' to 7698'.. Weight on bit 8 to 10k. Drill with 250 gpm w/ 1540 psi on bottom, 1490 psi off bottom-36% flow out. Rotate 80 rpm w/ 18k ft Ibs of torque on bottom, 16k ft Ibs off bottom. Pumps off: Rot wt 225k. Pumps on: PU wt 215k, SO wt 211, Rot wt 220k. EPOCH gas observed: 963 units. TOTCO gas observed: 4963 units. Note: Bit has (3) 10/32" nozzles and a 1"shear disc set for 4000 si. 05:15 06:15 1.00 7,698 7,698 INTRM1 CASING CIRC P Circulate. Mud wt in 9.6, MW out 9.6+. Pumping 250 gpm w/ 1490 psi-36% flow out. Rotate 80 rpm w! 15 k ft Ibs of torque. Circulated a total of one bottom's up (650 bbls). EPOCH as observed:963 units. 06:15 09:15 3.00 7,698 7,781 INTRM1 CASING DCSG P Drill with 7 5/8' casing from 7698' to 7781'. Weight on bit 7-14k. Drill with 250 gpm w/ 1540 psi on bottom, 1490 psi off bottom-36% flow out. Rotate 80 rpm w/ 18k ft Ibs of torque on bottom, 16k ft Ibs off bottom. Pumps off: Rot wt 225k. Pumps on: PU wt 215k, SO wt 211, Rot wt 220k. EPOCH gas observed: 830 units. TOTCO gas observed: 4990 units. Note: Bit has (3) 10/32" nozzles and a 1"shear disc set for 4000 si. 09:15 10:30 1.25 7,781 7,781 INTRM1 CASING CIRC P Circulate f/ samples. Mud wt in 9.6, MW out 9.6+. Pumping 250 gpm w/ 1490 psi-36% flow out. Rotate 80 rpm w/ 15 k ft Ibs of torque. Circulated a total of one bottom's up+ (415 bbls). EPOCH gas observed:448 units. 10:30 10:45 0.25 7,781 7,790 INTRM1 CASING DCSG P Drill with 7 5/8' casing from 7781' to 7790'. Weight on bit 7-14k.Drillwith 250 gpm w/ 1520 psi on bottom, 1470 psi off bottom-36% flow out. Rotate 80 rpm w/ 19k ft Ibs of torque on bottom, 15k ft Ibs off bottom. Pumps off: Rot wt 225k. Pumps on: PU wt 222k, SO wt 222, Rot wt 222k. EPOCH gas observed: 168 units. I ~ ~ Paq~ 19 at 37 ~~ IO~I~ ~~~~ Time Logs _ _ _ Date From To Dur S De th E. De th Phase Code Subcode T Comment _ - . _~ 10:45 12:00 1.25 7,790 7,790 INTRM1 CASING CIRC P Circulate f/ samples. Mud wt in 9.6, MW out 9.6+. Pumping 250 gpm w/ 1490 psi-36% flow out. Rotate 50 rpm w/ 12-13 k ft Ibs of torque. Circulated a total of one bottom's up (413 bbls). EPOCH gas observed:463 units. 12:00 12:30 0.50 7,790 7,800 INTRM1 CASING DCSG P Drill with 7 5/8' casing from 7790' to 7800'. Weight on bit 7-14k. Drill with 250 gpm w/ 1520 psi on bottom, 1470 psi off bottom-36% flow out. Rotate 80 rpm w/ 19k ft Ibs of torque on bottom, 15k ft Ibs off bottom. Pumps off: Rot wt 225k. Pumps on: PU wt 222k, SO wt 222, Rot wt 222k. EPOCH gas observed: 75 units. 12:30 13:45 1.25 7,800 7,800 INTRM1 CASING CIRC P Circulate f/ samples. Mud wt in 9.6, MW out 9.6+. Pumping 250 gpm w/ 1490 psi-36% flow out. Rotate 50 rpm w/ 12-13 k ft Ibs of torque. Circulated a total of one bottom's up+ (478 bbls). EPOCH gas observed:153 units. 13:45 14:15 0.50 7,800 7,815 INTRM1 CASING DCSG P Drill with 7 5/8' casing from 7800' to 7815'. Weight on bit 7-14k. Drill with 250 gpm w/ 1520 psi on bottom, 1470 psi off bottom-36% flow out. Rotate 80 rpm w/ 19k ft Ibs of torque on bottom, 15k ft Ibs off bottom. Pumps on: PU wt 222k, SO wt 222, Rot wt 222k. EPOCH gas observed: 271 units. 14:15 15:45 1.50 7,815 7,815 INTRM1 CASING CIRC P Circulate f/ samples. Mud wt in 9.6, MW out 9.6+. Pumping 250 gpm w/ 1500 psi-36% flow out. Rotate 50 rpm w/ 15 k ft Ibs of torque. Circulated a total of one bottom's up+ (531 bbls). EPOCH gas observed:196 units. 15:45 16:45 1.00 7,815 7,835 INTRM1 CASING DCSG P Drill with 7 5/8' casing from 7815' to 7835'. Weight on bit 7-14k. Drill with 250 gpm w/ 1520 psi on bottom, 1470 psi off bottom-36% flow out. Rotate 80 rpm w/ 19k ft Ibs of torque on bottom, 15k ft Ibs off bottom. Pumps on: PU wt 222k, SO wt 222, Rot wt 222k. EPOCH gas observed: 142 units. 16:45 18:00 1.25 7,835 7,835 INTRM1 CASING CIRC P Circulate f/samples. Mud wt in 9.6, MW out 9.6+. Pumping 250 gpm w/ 1510 psi-36% flow out. Rotate 50 rpm w/ 16 k ft Ibs of torque. Circulated a total of one bottom's up+ (425 bbls). EPOCH gas observed: 808 units. P~tg& 2Q cs$ 3i Time Logs Date From_ To Dur S. De th E.Depth Phase Code _ S_ubcode T Comment _ _ _ I 18:00 22:15 4.25 7,835 7,835 INTRM1 CASING CIRC P Start disolacing to 11.5 oog new mud. Pumping 250 gpm w/ 1510 psi-36% flow out. Rotate and reciprocate from 7835' to 7780'. Rotate 50 rpm w/ 16k ft Ibs of torque. Max gas observed 2748 units EPOCH. Circulated a total of 1520 bbls. New mud to surface @ 2145 hrs weighing 11.3 ppg. EPOCH gas still readin 3192 units. 22:15 00:00 1.75 7,835 7,835 INTRM1 CASING CIRC Start mixin barite to wei ht u from 11.5 to 11.8 PP,~Increase pump rate to 350 gpm with 3360 psi-43% flow out, to increase ECD's .2 ppg from 12.9 to 13.1 with 11.5 ppg. EPOCH gas lad midnight reading 1600 units and fallin .Rotate 50 rpm w/ 18k ft Ibs of torque. Pumped a total of 875 bbls since weighting up. Mud weighted to 11.8 ppg will be back to surface @ approx 0030 hrs 1/11/09. 1 /11 /2009 Continue to weight up from 11.5 ppg to 11.8 ppg while recip 7-5/8" casing f/ 7835' to 7780'- pumping 300 gpm w/ 2450 psi, monitor well- flowing, circulate bottom's up pumping 300 gpm w/ 2450 psi-39% flow out, rotating 50 rpm w/ 17k ft Ibs of torque. PUwt 220k, SO wt 220k, Rot wt 220k. While circulating 25' off bottom (7810'), lost 2300 psi of pump pressure. Stopped reciprocating, still rotating- w/ 2k torque and 95k Rotating weight. Tag TOP of fish @ 17' in on Jt # 189 (7841.72' shoe depth= 7835' while drilling). Try to screw into jt with no success. Monitor well for gain/loss (25 bbl gain- but pumps on/pumps off is 13 bb-s difference), lay down a joint (Jt # 189) of 7-5/8" casing, blow down the top drive. Well flowing slightly, shut well in with annular, using mud pump- apply 114 psi via kill line, bled down to 60 psi. Hold 60 psi while mixing 15.8 ppg pill to put on top of well. Bleed off 60 psi pressue, pump 67 bbls of 15.8 ppg mud to fill top of hole above parted pipe. Monitor well- appears to be flowing slightly. PJSM on laying down casing. Lay down 12 more joints of casing- pin end of joint # 177 left in box of joint (Joint #176 in the hole) (Top of fish 517'). Monitor well- flowing, closed blind rams. Change top pipe rams to 5". Rig down TESCO casing running tool, rig down Frank's flush mounted slips. Rig up to test top pipe rams and annular. Tested annular to 250 psi low and 3500 psi high, tested 5" upper pipe rams to 250 psi low and 5000 psi high. Chart test, hold each test 5 minutes. Rig down testing equipment. Make up Baker fishing assembly to 102', trip into 577', circulate out the 15.8 pppg mud on the top of the hole, slack off to engage fish. Tagged fish @ 595'. PU wt of fishing assembly 88K, SO 92k. Once engaged, pickup to 278k to pull free. Pick string up to 7825'. Initial pump pressure to 2500 psi with 20 spm, then press near normal. Started pumping 250 gpm w/ 1300 psi initial pressure-36% flow out. Max gas observed 2487 units. 00:00 05:30 5.50 7,835 7,835 INTRM1 CASING CIRC P Continue mixing barite to weight up from 11.5 ppg to 11.8 ppg. Circ & recip from 7835 to 7780, 300 gpm with 2450 psi-39% flow out, 50 rpm w/ 17k ft Ibs of torque. Max Gas observed 1613 EPOCH 05:30 05:45 0.25 7,835 7,835 INTRM1 CASING OTHR P Monitor Well - flowing, 05:45 07:30 1.75 7,835 7,835 INTRMI CASING CIRC P CBU - circ &recip from 7835' to 7810', 300 gpm, 2450 psi 39% flow, 50 rpm, 17K TQ, PU: 220K, SO: 220K, ROT: 220K. Max gas observed b EPOCH is 98 units. 1 r~~~~ 21 of ~~ Time Logs ----_ -- Date From To Dur S. De th E. De th Phase Code Subcode T Comment _ 07:30 08:00 0.50 7,835 7,835 INTRM1 CASING CIRC T C ntinue circ & reci lost 230. 0 psj . um ressure. Stopped blocks and shut down pumps, very noticeable 'um in the drill strin alon with with a load ban PU & SO wt went from 220K to 95K. Attem ted to rotate back into arted strin with no suc 08:00 08:30 0.50 7,835 7,835 INTRM1 WELCTL OWFF T Monitor well for gain loss (25 BBL gain) (13 bbls difference of pumps on to um s off) 08:30 09:00 0.50 7,835 7,835 INTRM1 WELCTL PULD T LD 1 Jnt of casing (#189), BD/TD and shut in well 09:00 10:30 1.50 7,835 7,835 INTRMI WELCTI KLWL T Pressure up annulus to 114 psi through kill line pressure bled down, pumped up again to 114 psi, bled down to 60 psi, held while building kill weight mud of 15.8 ppg. AOGCC Bob Nobile was notified 0915 of situatio . 10:30 11:00 0.50 7,835 7,835 INTRM1 WELCTL CIRC T Bleed off annulus pressure and open Hydril. Pumped 60 bbls of 15.8 ppg mud at 250 gpm, 130 psi 43% FO. 15.8ppg returns BDlfD and shut in well. 11:00 12:15 1.25 7,835 7,835 INTRM1 WELCTI CIRC T Monitor well while mixing additional kill wei ht mud 15.8 12:15 12:45 0.50 7,835 7,835 INTRM1 WELCTI CIRC T Bleed off annulus pressure and open Hydril. Pumped 60 bbls of 15.8 ppg mud at 250 gpm, 130 psi 43% FO. 15.8ppg returnes BD/TD 12:45 14:00 1.25 7,835 7,835 INTRM1 WELCTL CIRC T Monitor well (static after 15 min) while mixing additional kill weight mud 15.8 14:00 14:15 0.25 7,835 7,835 INTRM1 CASING SFTY T PJSM on pulling parted casing string 14:15 14:30 0.25 7,835 7,835 INTRM1 CASING RURD T RU to pull casing and finish mixing 15.8 mud 14:30 16:00 1.50 7,835 7,835 INTRM1 CASING TRIP T POOH LD casing. Amount of torque required to break connection as follows: Jnt # 188: 23K Jnt # 187 - # 184: 22K Jnt # 183: 32K Jnt # 182: 32K Jnt # 181: 28.5K Jnt # 180: 30.5K Jnt # 179: 36.5K Jnt # 178: 33.5K Jnt # 177: No Pin -pie arted on , last thread 16:00 16:15 0.25 7,835 7,835 INTRM1 WELCTI OWFF T Monitor well - flowin Sage 2~ ~t 3T I Time Logs Date -- From To Dur S. De th E. De th Phase Code Subcode T Comment 16:15 18:00 1.75 7,835 7,835 INTRMI WELCTL EQRP T Close blind rams Change out upper ms from 7 5/8 to 5". Rig down TESCO casing running tool. Rig down Frank's flush mounted slips. Rig up to run 5"drill pipe. Pickup Baker fishin BHA to ri floor. 18:00 18:30 0.50 7,835 7,835 INTRM1 WELCTL RURD T Rig up testing equipment to test BOPE. 18:30 19:15 0.75 7,835 7,835 INTRM1 WELCTL BOPS T Test Annular to 250 psi low and 3500, psi high. Test top pipe rams (5") to 250 psi low and 5000 psi high. Hold each test 5 minutes, chart test. 19:15 19:30 0.25 7,835 7,835 INTRM1 WELCTL RURD T Rig down testing equipment. 19:30 20:15 0.75 7,835 7,835 INTRM1 FISH PULD T Make up fishing assembly. 7-5/8" S ear with ackoff. 20:15 20:45 0.50 7,835 7,835 INTRMI FISH TRIP T Trip in the hole on 5"drill pipe to end of BHA inside of the 7-5/8" casing/ packoff 10' above top of fish, depth of 3-1/2" mule shoe 577'. 20:45 21:00 0.25 7,835 7,835 INTRM1 FISH CIRC T Circulate out the 15.8 ppg heavy mud in the top of the hole. Pumping 500 gpm w/ 280 psi-52% flow out. Circulated 12 ppg mud into the hole. PU wt 88k, SO wt 92k. 21:00 21:30 0.50 7,835 7,835 INTRM1 FISH FISH T Slack off, engage fish with spear (stop on top offish @ 517' )(3-1 /2" mule shoe @ 596' inside of 7-5/8" casing). Pickup to 278k moving casin u the hole. 21:30 00:00 2.50 7,835 7,835 INTRMI FISH CIRC T Circulate 7-5/8" casing, reciprocate from 7825' to 7815'. Pumping 250 gpm w/ initial pressure of 1300 psi and final of 510 psi-36% flow out. EPOCH max as 2487 units. 1/12/2009 Con't to circ 12.1 ppg mud to surf, pump 250 gpm w/ 510 psi-36% flow out, monitor well via trip tank w/gain of 2-1/2 bbl. Monitor visually- verify slight flow. Circ BU, weighting up to 12.3 ppg, monitor well- static. POOH with fish from 7825' to 7321'. LD fishing assembly, RU casing slips, RD 5" handling tools, RU TESCO casing running tool, establish circ- pumping 250 gpm w/ 530 psi-36% flow out. EPOCH drop a carbide sample-did not notice sample in returns, monitor well-static, pump another carbide sample with double volume -no signs in returns, monitor well- slight flow. BD top drive. POOH with 7-5/8" casing from 7321' to 7116' (jt # 171 in the hole). Clean & inspect threads-OK, monitor well- static, makeup/ RIH with 7-5/8" casing to 7796' Qt # 187 in the hole). Circ and cond mud and hole pumping 6 bpm w/ 550 psi-36% flow out/Recip from 7796' to 7756'. Install buttress x-o to jt # 187, continue to circ with TESCO pumping a total of 943 bbls. BD the top drive, R!D the TESCO tool. RU Dowell cement head. Continue to circulate and reciprocate casing from 7796' to 7756' (40' stroke). Pumping 250 gpm w/ 610 psi-38% flow out. PU wt 265k, SO wt 185k with pumps on. Pumped a total of 638 bbls thru cement head. Circa a total of 1581 bbls EPOCH max 132 units. PJSM on cement job while cirU then batch mix cement. Dowell pump 5 bbls of water, test lines to 4000 psi, mix and pump 40 bbls of 14 ppg mudPush, drop bottom plug, pump 84 bblsof 15.9 ppg "G" GasBlock cement at 6 bpm w/ 823 to 580 psi, drop top plug, follow with 10 bbls of water through tub. Full returns 39% flow out on the down stroke. Reciprocated pipe 40' from 7796' to 7756'. Last PU wt 245k, SO wt 175k. Rig displace with 12.3 ppg mud. Pump 6 bpm w/ 290 psi initial, with cement at the shoe 420 psi. Slow to 3 bpm after pumping 323 bbls with initial presure of 520 psi and final before bumping plug of 650 psi. Bump plug with 1150 psi @ 0033 hrs 1/13/09. Full returns. Hold ress 5 min, bleed off float- held. ._--- ~~_.. ~'acJe ~~ ~t 3? • Time Logs _ ___ Date___ _ From To Dur S Depth E, De th Phase Code Subcode T Comment _ ___ 00:00 01:30 1.50 7,835 7,835 INTRM1 _ FISH CIRC T Continue weighting up to 12.1 ppg. Circulate 7-5/8" casing, reciprocate from 7825' to 7815'. Pumping 250 gpm w/ 510 psi-36% flow out. EPOCH max as 2487 units. 01:30 02:00 0.50 7,835 7,835 INTRM1 FISH OTHR T Blow down the top drive. 02:00 03:15 1.25 7,835 7,835 INTRM1 WELCTI OWFF T Monitor well on the trip tank with um runnin .Gain of 2-1/4 bbls in an hour. Monitor with hole fill pump off and visual) veri sli ht flow. 03:15 06:15 3.00 7,835 7,835 INTRM1 FISH CIRC T Continue weighting uo to 12.3 ooa. Reciprocate from 7825' to 7765'. Circulate 7-5/8" casing, reciprocate from 7825' to 7815'. Pumping 250 gpm w/ 480 psi-36% flow out. EPOCH max as 2735 units. 06:15 06:45 0.50 7,835 7,835 INTRM1 FISH CIRC T BD/TD Monitor Well -static PJSM on ullin fish 06:45 08:00 1.25 7,835 7,835 INTRM1 FISH FISH T POOH with fish from 7825' to 7511'. Pump out from 7511 to 7321' @ 250 gpm, 540 psi, 36% FO. Monitor disp on tri tank PU 270K, SO 175K 08:00 08:30 0.50 7,835 7,835 INTRM1 FISH RURD T LD Fishing BHA. RU casing slips 08:30 09:00 0.50 7,835 7,835 INTRM1 CASING RURD T RD 5" handling equipment and RU TESCO 09:00 09:15 0.25 7,835 7,835 INTRM1 CASING CIRC T Establish circulation, 250 gpm, 530 Si, 36% FO 09:15 11:45 2.50 7,835 7,835 INTRM1 CASING CIRC T Drop carbide sample, pump down 250 gpm, 540 psi, 36% FO, PU 250K, SO 168K. Pressure dropped to 410 psi after 302 bbls. Total bbls pumped 901 bbls. No spike from carbide observed. 11:45 12:00 0.25 7,835 7,835 INTRM1 CASING CIRC T Monitor well Static 12:00 13:15 1.25 7,835 7,835 INTRM1 CASING CIRC T Drop second carbide sample(double volume) with dye, pump down @ 250 gpm, 430 psi, 37% FO, PU 250K, SO 168K. Pumped 450 bbls with no indication of carbide or d e. 13:15 13:30 0.25 7,835 7,835 INTRM1 CASING CIRC T Monitor well sli h 13:30 14:15 0.75 7,835 7,835 INTRM1 CASING RURD T BD/TD and clear floor of baker tools 14:15 15:45 1.50 7,835 7,835 INTRM1 CASING OTHR T POOH with 7-5/8" 29.7 ppf L-80 Hyd 563 casing from 7321 to 7116' (jt # 171 in the hole . 15:45 16:15 0.50 7,835 7,835 INTRM1 CASING OTHR T Blow down the top drive. Monitor well- static. Clean and inspect threads on the 7-5/8" casing pulled out. Looks ok. 16:15 17:15 1.00 7,835 7,835 INTRM1 CASING RNCS T Run 7-5/8" casin to 't#'t# 187 in the hole. 17:15 18:00 0.75 7,835 7,835 INTRM1 CASING CIRC P Circulate and reciprocate casin from 7796' to 7756' (40' stroke). Pumping 250 gpm w/ 550 psi-36% flow out. PU wt 250k, SO wt 175k. Max gas EPOCH 2300 units. E f'~~e 2~ ssf 3a i- _Time Lois Date _____ From To Dur S. De th E. De th Phase Code Subcode __T Comment ___ - ---- - - -- - -- 18:00 19:45 1.75 7,835 7,835 INTRM1 CASING CIRC P Continue to circulate and reciprocate casin from 7796' to 7756' (40' stroke .Pumping 250 gpm w/ 390 psi-36% flow out. PU wt 265k, SO wt 185k. 19:45 20:15 0.50 7,835 7,835 INTRMI CEMEN" CIRC P Install a crossover H d 563 in x BTC-mod box in the to of 't # 187 This 'oint is the landin ~oint. Continue to circulate and condition mud for cement job. MW in 12.3 ppg, MW out 12.3 ppg. Vis 54, PV/YP= 17/16, 10 min gel =6. Shut down pumps after condtioning a total of 943 bbls. E och as 83 units. 20:15 20:30 0.25 7,835 7,835 INTRM1 CEMEN" OTHR P Blow down the top drive. Rig down TESCO to drive casin runnin tool. 20:30 21:00 0.50 7,835 7,835 INTRM1 CEMEN- RURD P Rig up Dowell/Schlumberger cement head. Attach 2" cement hose. 21:00 22:45 1.75 7,835 7,835 INTRM1 CEMEN" CIRC P Continue to circulate and reciprocate casing from 7796' to 7756' (40' stroke). Pumping 250 gpm w/ 610 psi-38% flow out. PU wt 265k, SO wt 185k with pumps on. Pumped a total of 638 bbls through the cement head. Circulated a total of 1581 bbls. EPOCH max 132 units. Pre job safety meeting on cement job while circulating/ then batch mix cement. 22:45 23:30 0.75 7,835 7,835 INTRM1 CEMEN- OTHR P Dowell pump 5 bbls of water, test lines to 4000 psi, mix and pump 40 bbls of 14 ppg mudPush, drop bottom plug, pump 84 bblsof 15.9 "G" GasBlock cement at 6 b m w/ 823 to 580 psi, drop top plug, follow with 10 bbls of water through tub. Full returns 39% flow out on the down stroke. Reciprocated pipe 40'_ from 7796' to 7756'. Last PU wt 245k, SO wt 175k. 23:30 00:00 0.50 7,835 7,835 INTRM1 CEMEN" DISP P Rig displace with 12.3 ppg mud. Pumping 6 bpm w/ 290 psi initial pressure after catching plugs, with cement at the shoe 420 psi. Slow to 3 bpm after pumping 323 bbls with initial presure of 520 psi and final before bumping plug of 650 psi. Bump plug with 1150 psi 0033 hrs 1/13/09. Full returns. Hold pressure f/ 5 minutes. bled off pressure and floats held. No flow on nn Continued to reci rocate casin until 330 bbls of mud dis laced. Last PU wt 245k, SO wt 165k. Note: At midnight approx 175 bbls of diss lacement was um ed. P~~~ 25 €st 37 Time Logs _ _ __ ___ _ _ Date From To Dur S Depth E. Depth Phase Code Subcode T Comment 1/13/2009 24 hr Summary Displace intermediate cement, bumped plug, CIP @ 00:30. Set emergency slips. Flushed and freeze rotected 10-3/4" x 7-5/8" annulus. Chan ed out u er and lower rams and tested BOPE. 00:00 00:45 0.75 7,835 7,835 INTRM1 CEMEN' DISP P Rig displacing cement with 12.3 ppg mud. Pumping 6 bpm w/ 290 psi initial pressure after catching plugs, with cement at the shoe 420 psi. Slow to 3 bpm after pumping 323 bbls with initial presure of 520 psi and final before bumping plug of 650 psi. Bump plug with 1150 psi 0033 hrs 1/13/09. Full returns. Hold pressure f/ 5 minutes. bled off pressure and floats held. No flow on annulus. Continued to reciprocate casing until 330 bbls of mud dis laced. 00:45 01:00 0.25 7,835 7,835 INTRM1 CEMEN' RURD P Blow down cement line. 01:00 01:15 0.25 7,835 7,835 INTRM1 CEMEN- SFTY P PJSM -rigging down cement head. 01:15 01:30 0.25 7,835 7,835 INTRM1 CEMEN- RURD P Rig down cement head and crossover. 01:30 06:30 5.00 7,835 7,835 INTRM1 CASING NUND P Pre for settinn casing in slips. Suck mud out of casing to be cut off and nipple down flow line and riser. Sim ops: loading 4"drill pipe in shed, bring 4" floor sasfety valves and BHA to ri floor. 06:30 06:45 0.25 7,835 7,835 INTRMI CASING SFTY P PJSM -picking up BOP stack. 06:45 07:00 0.25 7,835 7,835 INTRM1 WELCTI NUND P Pick up stack to cut casing. 07:00 09:45 2.75 7,835 7,835 INTRM1 CASING OTHR P Clean and flush bowl for slips and packoff. Set slips with 65k on slips. Cut 7-5/8" casing and set packoff. La down cut 'oint. 09:45 10:30 0.75 7,835 7,835 INTRM1 WELCTI NUND P Nipple up BOP stack, bell nipple, riser, flowline and turn buckles. 10:30 11:00 0.50 7,835 7,835 INTRM1 CASING DHEQ P Test packoff to 3800 psi, hold for 10 minutes. Good test. 11:00 11:15 0.25 .7,835 7,835 INTRM1 WELCTI SFTY P PJSM -changing upper and lower rams. 11:15 12:30 1.25 7,835 7,835 INTRM1 WELCTI EQRP P Change out upper and lower rams. Install 3-1/2 x 6 in top and 2-7/8 x 5 in bottom. 12:30 13:45 1.25 7,835 7,835 INTRM1 CEMEN' LOT P Ri up to flush annulus, perform infectivity test and freeze protect 10-3/4" x 7-5/8" annulus. Flush annulus with 140 bbls water, initial pressure 600 psi, final pressure 800 psi. Pump 75 bbls of freeze protect diesel with Little Red Services. Sim ops: rig down casing elevators, long bails, tesco tools, pick up short bails and 5"elevators. 13:45 14:00 0.25 7,835 7,835 INTRM1 RIGMNT SFTY P PJSM -changing saver sub. 14:00 15:45 1.75 7,835 7,835 INTRM1 RIGMNT SVRG P Change saver sub. ~.® €'age 2fi of 3T Time Logs __ _ From To fur S De th E. De th Phase Code Subcode T Comment _ Date ___ 15:45 16:30 0.75 7,835 7,835 INTRM1 WELCTL BOPE P Rig up for BOPE test. Set test plug, fill stack. linese and manifold with water. 16:30 22:15 5.75 7,835 7,835 INTRM1 WELCTL BOPE P Test BOPE. 250 psi low, 3500 psi high on annular preventor and 250 low, 5000 high for the rest of the system. Tested annular preventor with 3-1/2" & 4-1 /2" test joints and both rams with 3-1/2", 4" & 4-1/2" test joints. Accumulator drawdown starting pressure 3025 psi. After functioning pressure 1500 psi. 28 seconds for 200 psi increase and 2 minutes 58 seconds to full pressure. Witness waived by AOGCC John Cris . 22:15 23:30 1.25 7,835 7,835 INTRM1 WELCTL BOPE P Rig down test equipment, blow down lines, pull test plug and set wear rin . 23:30 23:45 0.25 7,835 7,835 INTRM1 DRILL PULD P Install mouse hole in rotary for laying down 5"drill i e. 23:45 00:00 0.25 7,835 7,835 INTRM1 DRILL SFTY P PJSM -Laying down 5"drill pipe, HWDP and drill collars. 1 /14/2009 Lay down BHA and 5"drill pipe from derrick. Repair skate hydraulics. Pick up BHA and single in hole with 4" drill i e. 00:00 00:30 0.50 7,835 7,835 INTRM1 DRILL SFTY P PJSM -laying down BHA and drill pipe from derrick. Review lessons learned. 00:30 01:45 1.25 7,835 7,835 INTRM1 DRILL PULD P Lay down flex collars, jars, bumper sub and HWDP. 01:45 02:30 0.75 7,835 7,835 INTRM1 DRILL PULD P Lay down 5"drill pipe from derrick 02:30 02:45 0.25 7,835 7,835 INTRM1 RIGMN7 SVRG P Inspect and adjust brakes on drawworks. 02:45 07:45 5.00 7,835 7,835 INTRM1 DRILL PULD P Lay down 5"drill pipe from derrick 07:45 08:15 0.50 7,835 7,835 INTRM1 DRILL RURD P Change out handling equipment. 08:15 09:15 1.00 7,835 7,835 INTRM1 DRILL PULD P Pick up and make up BHA. 09:15 10:15 1.00 7,835 7,835 INTRM1 RIGMNI SVRG P Lubricate rig 10:15 17:00 6.75 7,835 7,835 INTRM1 RIGMN7 RGRP T Hydralic motor on skate quit. Make tem ora re airs. 17:00 17:45 0.75 7,835 7,835 INTRM1 DRILL PULD P Resume making up BHA. 17:45 18:45 1.00 7,835 7,835 INTRM1 DRILL PULD P Pick up and rack back 7 stands of 4" drill i e. 18:45 22:30 3.75 7,835 7,835 INTRM1 DRILL PULD P Single in hole with 4" drill pipe. PU wt 125k, SO wt 120k. 22:30 22:45 0.25 7,835 7,835 INTRM1 DRILL SFTY P Mid job safety meeting -review current activities. 22:45 00:00 1.25 7,835 7,835 INTRM1 DRILL PULD P Continue singling in hole with 4" dril i e. PU wt 145k, So wt 125k 1 /15/2009 Single in hole with 4" drill pipe. Wash down and tag cement. Circulate bottoms up and test casing. Drill up float equipment and EZCase bit. Circulate bottoms up, Weight up to 12.8 ppg to kill gas. Short trip 10 stands and circulate bottoms u to check for as. Good. Pum out of hole 3 stands. ~ ~ ~~~.~~ v ~~tJa 27 csf 37 ~ ~ Time Logs _ _ _ __ Date From To Dur S. Depth E_ De th Phase Code Subcode T Comment 00:00 02:45 2.75 7,835 7,835 INTRMI DRILL PULD P Continue singling in hole with 4" dril i e. PU wt 180k, So wt 140. 02:45 03:45 1.00 7,835 7,835 INTRM1 DRILL CIRC P Wash in hole pumping 2 bpm, 510 psi until tagging up on cement @ 7693' MD. Observed 200 psi increase and set down 10k. 03:45 04:15 0.50 7,835 7,835 INTRMI DRILL CIRC P Circulate bottoms up at 450 gpm, 3750 si, rotatin 50 r m. 04:15 04:30 0.25 7,835 7,835 INTRM1 DRILL OTHR P Blow down top drive. 04:30 05:00 0.50 7,835 7,835 INTRM1 CASING DHEQ P Rig up head pin, hoses, gauges and chart for casin test. 05:00 06:45 1.75 7,835 7,835 INTRM1 CASING DHEQ T Shut top rams, open HCR choke and pump at .5 bpm. Unable to build ressure. Trouble shoot surface system. Open rams establish circulation, close rams and attempt to pressure up. Switch pumps, no Chan e. Coutine troublin shootin . 06:45 07:45 1.00 7,835 7,835 INTRM1 CASING DHEQ P Pressure test casin to 2500 si for 30 minutes. Good test. 07:45 08:00 0.25 7,835 7,835 INTRM1 CASING DHEQ P Rig down test equipment and blow down lines. 08:00 11:45 3.75 7,835 7,835 INTRM1 CEMEN' DRLG P Drill u float egt;ioment and shoe Tag up on EZCase bit on depth and drill up. Work junk baskets and drill 6' out shoe. Pumping 300 gpm, 1940 psi, rotating 60 rpm, 12 WOB, 6k torque on bottom. 11:45 14:00 2.25 7,835 7,835 INTRM1 DRILL CIRC P Circulate bottoms up pumping 350 gpm, 2530 psi, rotating 60 rpm. Max Epoch gas 521 units. Weight up from 12.3 ppg to 12.5 ppg. PU wt 188k, SO wt 145k. 14:00 14:15 0.25 7,835 7,835 INTRM1 DRILL CIRC P Wash back to bottom. 14:15 14:45 0.50 7,835 7,835 INTRM1 DRILL OWFF P Monitor well -static, blow down top drive. 14:45 18:15 3.50 7,835 7,835 INTRM1 DRILL CIRC P Circulate bottoms up pumping 350 gpm, 2500 psi. Max Epoch gas 1670 units. Weight up to 12.8 ppg. Continue circulating at 250 gpm, 1440 si. 18:15 18:45 0.50 7,835 7,835 INTRM1 DRILL OWFF P Monitor well -static 18:45 20:00 1.25 7,835 7,835 INTRM1 DRILL CIRC P Circulate bottoms up at 250 gpm, 1540 psi, rotating 60 rpm. Max E och as 21 units. 20:00 20:15 0.25 7,835 7,835 INTRM1 DRILL OWFF P Monitor well -static, blow down top drive. 20:15 21:00 0.75 7,835 7,835 INTRM1 DRILL TRIP P POOH 10 stands. PU wt 175k, SO wt 130k 21:00 21:15 0.25 7,835 7,835 INTRM1 DRILL OWFF P Monitor well -slight flow to static. Blow down to drive. 21:15 22:00 0.75 7,835 7,835 INTRMI DRILL TRIP P TIH to bottom. PU wt 190k, SO wt 140k. 22:00 23:15 1.25 7,835 7,835 INTRM1 DRILL CIRC P Circulate bottoms up at 250 gpm, 1510 si. Max E och as 185 units. -- _ s ~ Pagfl 2B crf 3~ Time Logs Date From 'fo Dur S Depth _ E._Depth Phase Code__ _ Subcode T Cor7~ment ' _. - -- - - 23:15 23:45 0.50 7,835 7,835 INTRM1 DRILL OWFF P Monitor well -static, blow down top drive. 23:45 00:00 0.25 7,835 7,835 INTRM1 DRILL TRIP P Pump out of hole 3 stands. 1 /16/2009 Pull out of hole with drilling assembly. Rack back BHA and clean out junk baskets. Rig up and run gyro, densi and neutron orosit ,and USIT to in tools on eline. 00:00 01:00 1.00 7,835 7,835 INTRM1 DRILL TRIP P Pump out of hole 7 stands. 01:00 01:15 0.25 7,835 7,835 INTRM1 DRILL OTHR P Blow down top drive. 01:15 02:00 0.75 7,835 7,835 INTRM1 DRILL TRIP P POOH on elevators 10 stands. PU wt 150k, SO wt 122k 02:00 02:15 0.25 7,835 7,835 INTRM1 DRILL OWFF P Monitor well -static 02:15 02:30 0.25 7,835 7,835 INTRM1 DRILL CIRC P Pump 30 bbl dry job at 5 bpm, 810 si. 02:30 02:45 0.25 7,835 7,835 INTRM1 DRILL OTHR P Blow down top drive and install air sli s. 02:45 04:45 2.00 7,835 7,835 INTRM1 DRILL TRIP P POOH on elevators to BHA 04:45 05:00 0.25 7,835 7,835 INTRM1 DRILL OWFF P Monitor welt -static 05:00 05:15 0.25 7,835 7,835 INTRMI DRILL SFTY P PJSM -handling BHA 05:15 06:30 1.25 7,835 7,835 INTRM1 DRILL TRIP P Handle BHA, rack back HWDP, jars and drill collars. Clean out junk baskets. Got handful on metal and 3 cutters from EZCase bit. Lost 8.5 bbls Burin tri . 06:30 06:45 0.25 7,835 7,835 INTRM1 DRILL OWFF P Monitor well -static 06:45 07:00 0.25 7,835 7,835 INTRM1 EVALWE SFTY P PJSM -rigging up eline and monitorin well while to in . 07:00 07:45 0.75 7,835 7,835 INTRM1 EVALWE RURD P Rig up eline. 07:45 14:00 6.25 7,835 7,835 INTRM1 EVALWE ELOG P Run ro on eline to TD. 14:00 14:30 0.50 7,835 7,835 INTRM1 EVALWE RURD P Lay down gyro tools. 14:30 15:00 0.50 7,835 7,835 INTRM1 EVALWE SFTY P PJSM -running density and neutron orosit tools on wireline. 15:00 16:00 1.00 7,835 7,835 INTRM1 EVALWE RURD P Pick up logging tools. 16:00 19:00 3.00 7,835 7,835 INTRM1 EVALWE ELOG P Run density and neutron gor_osiiv . Work tools thru tight s ots from 5500' to 6500' MD 19:00 19:30 0.50 7,835 7,835 INTRM1 EVALWE RURD P Lay down logging tools. 19:30 20:00 0.50 7,835 7,835 INTRM1 EVALWE OTHR P Monitor well -static 20:00 20:45 0.75 7,835 7,835 INTRM1 EVALWE RURD P Pick up USIT logging tools. 20:45 00:00 3.25 7,835 7,835 INTRM1 EVALWE ELOG P Run USIT to in tools. Work tools thru tight spots from 5800' to 6100'. Can't work tools ast 6410' MD. Lo in u from 6410'. 1 /17/2009 Made 4 logging run with eline, USIT, Sonic, Resistivity and Multi-shot gyro. Rig down and release eline. Pick u 6-3/4" roduction hole drillin BHA. 00:00 01:15 1.25 7,835 7,835 INTRM1 EVALWE ELOG P POOH with USIT logging string. Lo in u from 6410' WLM. ~ ~~ ~ ~~a~~~ 29 €st 3~ ~ ~ Time Logs -- -- __ _ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 01:15 01:45 0.50 7,835 7,835 INTRM1 EVALWE PULD T _ _. Drop bow spring centralizers from USIT logging string and add weight bar. Monitorin well -static. 01:45 03:00 1.25 7,835 7,835 INTRM1 EVALWE ELOG T RIH with USIT. Tagged up hard at 6400' WLM. Worked tools down gaining about 10' with each try. Broke thru and ran to TD with no more troubles. 03:00 04:45 1.75 7,835 7,835 INTRM1 EVALWE ELOG T Log lower section of hole with USIT. Good cement to 6100' WLM. 04:45 05:00 0.25 7,835 7,835 INTRM1 EVALWE PULD T Lay down USIT logging tools. 05:00 05:15 0.25 7,835 7,835 INTRMI EVALWE OTHR P Monitor well -static 05:15 05:45 0.50 7,835 7,835 INTRM1 EVALWE PULD P Pick up Sonic logging tools. 05:45 09:30 3.75 7,835 7,835 INTRM1 EVALWE ELOG P RIH to 7780' WLM and to C sands. 09:30 10:15 0.75 7,835 7,835 INTRM1 EVALWE PULD P Lay down Sonic logging tools 10:15 10:30 0.25 7,835 7,835 INTRM1 EVALWE OTHR P Monitor well -static 10:30 11:15 0.75 7,835 7,835 INTRM1 EVALWE PULD P Pick up resistivity logging tools. 11:15 18:00 6.75 7,835 7,835 INTRM1 EVALWE ELOG P RIH to 7780' WLM and log C sands. 18:00 18:30 0.50 7,835 7,835 INTRM1 EVALWE PULD P Lay down resistivity logging tools 18:30 19:00 0.50 7,835 7,835 INTRM1 EVALWE OTHR P Monitor well -static 19:00 19:30 0.50 7,835 7,835 INTRM1 EVALWE PULD T Pick up multi-shot gyro tools to get 10' suroe s from 300' - 800' MD. 19:30 21:30 2.00 7,835 7,835 INTRM1 EVALWE ELOG T RIH and take gyro surveys from 800' to 300'. La down to in tools 21:30 21:45 0.25 7,835 7,835 INTRM1 EVALWE RURD P Rig down eline. 21:45 22:00 0.25 7,835 7,835 INTRM1 DRILL SFTY P PJSM -picking up drilling BHA. 22:00 00:00 2.00 7,835 7,835 INTRM1 DRILL PULD P Pick up BHA and start downloading MWD. 1 /18/2009 Pick up and run in hole with 6-3/4" bit and BHA. Circulate out old mud at 2500', 5000' & 7796'. Drill out cement and 20' of new hole for FIT test. Perform FIT test to 980 psi, 15.9 ppg EMW. Drill production hole to TD, 8210' MD. 00:00 00:15 0.25 7,835 7,835 INTRM1 DRILL PULD P Downloading MWD. 00:15 00:30 0.25 7,835 7,835 INTRM1 DRILL PULD P PU Batsonic MWD 00:30 00:45 0.25 7,835 7,835 INTRM1 DRILL SFTY P PJSM -Handling and loading nuclear sources. 00:45 01:15 0.50 7,835 7,835 INTRM1 DRILL PULD P Load sources 01:15 01:45 0.50 7,835 7,835 INTRM1 DRILL TRIP P TIH with drill collars, jars and HWDP from derrick 01:45 02:15 0.50 7,835 7,835 INTRM1 DRILL CIRC P Shallow pulse test MWD pumping 200 gpm, 1150 psi, rotating 30 rpm - ood test 02:15 03:00 0.75 7,835 7,835 INTRM1 DRILL TRIP P TIH on elevators monitoring displacement via trip tank. PU wt 115k SO wt 115. 03:00 03:45 0.75 7,835 7,835 INTRM1 DRILL CIRC P CBU displacing old mud from hole. Pump 225 gpm, 1610 psi, rotating 70 r m. P~ar~~ 3t3 cif 37 ~ ~ Time Logs _ _ __ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 03:45 05:00 1.25 7,835 7,835 INTRM1 DRILL TRIP P TIH on elevators monitoring displacement via trip tank. PU wt 148k SO wt 120. 05:00 06:15 1.25 7,835 7,835 INTRM1 DRILL CIRC P CBU displacing old mud from hole. Pump 225 gpm, 1830 psi, rotating 70 r m. 06:15 06:30 0.25 7,835 7,835 INTRMI DRILL OTHR P Blow down top drive. 06:30 07:45 1.25 7,835 7,835 INTRM1 DRILL TRIP P TIH on elevators to intermediate casing shoe monitoring displacement via trip tank. Hole took proper dis lacement over tri . 07:45 09:30 1.75 7,835 7,835 INTRM1 DRILL CIRC P CBU displacing old mud from hole. Stage pumps to 250 gpm, 2450 psi. PU wt 192k, SO wt 132k 09:30 10:00 0.50 7,835 7,835 INTRM1 CEMEN' DRLG P Drill out cement and shoe. 10:00 10:15 0.25 7,835 7,855 INTRM1 DRILL DDRL P Drill 20' of new hole. 10:15 11:00 0.75 7,855 7,855 INTRM1 DRILL CIRC P CBU pumping 250 gpm, 2500 psi. Max Epoch gas 1638 units. Circulate until as stable at 100 units. 11:00 11:15 0.25 7,855 7,855 INTRM1 DRILL OWFF P Monitor well -static, blow down top drive. Pull u into casin for LOT/FIT. 11:15 12:00 0.75 7,855 7,855 INTRM1 DRILL FIT P Ri up and perform FIT test. Pressured up to 980 psi, 15.9 EMW. Rig down test equipment and blow down lines. 12:00 12:30 0.50 7,855 7,855 PROD1 DRILL CIRC P CBU pumping 250 gpm, 2500 psi. Max E och as 60 units. 12:30 22:45 10.25 7,855 8,210 • PROD1 DRILL DDRL P Drill 6-3/4" production hole. 22:45 23:00 0.25 8,210 8,210 PROD1 DRILL OWFF P Monitor well -static, grease swivel ackin . 23:00 00:00 1.00 8,210 8,210 PROD1 DRILL CIRC P Circulate 40 bbl hi-vis sweep at 250 gpm, 2830 psi, rotating 120 rpm and continue circulating. Observed 15% increase in cuttings when sweep returned. PU wt 205k, SO wt 140k, rotatin wt 168k. 1 /19/2009 Circulate hole clean after TD. Short trip 10 stands and circulate to check for gas. No significant gas. Pump out of hole 10 stands and pull remaining string on elevators. Lay down BHA. Run 4-1/2" liner on 4"drill pipe to intermediate casin shoe. 00:00 01:00 1.00 8,210 8,210 PROD1 DRILL CIRC P Circulate 40 bbl hi-vis sweep at 250 gpm, 2830 psi, rotating 120 rpm and continue circulating. Observed 15% increase in cuttings when sweep returned. PU wt 205k, SO wt 140k, rotating wt 168k. Observed 15% increase in cuttings returned. Circulated 3 BU. 01:00 01:15 0.25 8,210 8,210 PROD1 DRILL OWFF P Monitor well -static 01:15 03:00 1.75 8,210 8,210 PROD1 DRILL TRIP P Short trip 10 stands. ~~~ ~ Pate 31 of ;~i Time Logs Date From To Dur S _De th E. Depth Phase Code Subcode T Comment 03:00 05:00 2.00 8,210 8,210 PROD1 DRILL CIRC P CBU to check for gas, max Epoch gas 240 units. Pump 40 bbl hi-vis sweep at 250 gpm, 2670 psi, rotating 120 rpm. Observed 15% increase in cuttings when sweep returned. PU wt 205k, SO wt 140k, rotating wt 165k. No significant increase in cuttings returned. Circulated 3 BU 05:00 05:15 0.25 8,210 8,210 PROD1 DRILL OWFF P Monitor well -static 05:15 06:45 1.50 8,210 8,210 PROD1 DRILL TRIP P Pump out of hole 10 stands, pumping 40 gpm. Dropped 2.33" rabbit on wire. 06:45 07:00 0.25 8,210 8,210 PROD1 DRILL OWFF P Monitor well -static. 07:00 07:15 0.25 8,210 8,210 PROD1 DRILL CIRC P Pump dry job and blow down top drive. 07:15 09:30 2.25 8,210 8,210 PROD1 DRILL TRIP P POOH on elevators to BHA. Hole took ro er fill over tri . 09:30 10:45 1.25 8,210 8,210 PROD1 DRILL PULD P Lay down HWDP, jars, and flex collars. Rabbit found on to of'ars. 10:45 11:00 0.25 8,210 8,210 PROD1 DRILL SFTY P PJSM -removing and handling sources. 11:00 11:15 0.25 8,210 8,210 PROD1 DRILL PULD P Remove and lay down sources. 11:15 11:30 0.25 8,210 8,210 PROD1 DRILL PULD P Lay down batsonic 11:30 12:15 0.75 8,210 8,210 PROD1 DRILL PULD P Download MWD 12:15 13:15 1.00 8,210 8,210 PROD1 DRILL PULD P Lay down MWD, stabilizer and motor. 13:15 13:45 0.50 8,210 8,210 COMPZ DRILL PULD P Clear and clean rig floor. 13:45 14:15 0.50 8,210 8,210 COMPZ CASING RURD P Rig up 4-1/2" handling tools 14:15 14:45 0.50 8,210 8,210 COMPZ CASING SFTY P PJSM -picking up liner, han er/ acker and runnin same. 14:45 17:30 2.75 8,210 8,210 COMPZ CASING RUNL P Pick up and run in hole with 4-1/2" liner, seal bore extension and liner hanger/packer. Fill pipe every 5 'oints. PU wt 82k, SO wt 78k 17:30 18:30 1.00 8,210 8,210 COMPZ CASING RUNL P Mix and pour Pal-mix in liner top acker and wait for it to setu . 18:30 19:30 1.00 8,210 8,210 COMPZ CASING CIRC P TIH with 1 stand of drill pipe and stage pumps to 5 bpm, 350 psi. PU wt 88k, SO wt 88k. 19:30 23:15 3.75 8,210 8,210 COMPZ CASING RUNL P TIH on elevators with 4-1 /2" liner on drill pipe. Record weigths every five stands and cirulate eve 25 stands. 23:15 00:00 0.75 8,210 8,210 COMPZ CASING CIRC P Circulate surface to surface volume before exitin intermediate cesin . 1 /20/2009 Tag bottom with liner. Make up cement head and circulate. Mix and pump cement. Plug bumped. Circulate out excess cement. Serviced ri .Pulled out of hole la in down drill i e. Tested liner to acker, ood test. 00:00 01:00 1.00 8,210 8,210 COMPZ CASING CIRC P Circulate bottoms up while picking up and rigging up lines and valves. Pum ed 6 b mat 1470 si. 01:00 01:45 0.75 8,210 8,210 COMPZ CASING RURD P Pick up cement head and tools. ~ Pace ~2 of 37 ~. Time Logs __ Date From To Dur S De th E. De th Phase Code Subcade T Comment 01:45 02:15 0.50 8,210 8,210 COMPZ CASING RUNL P TIH to bottom washing down last stand at 2 bpm, 400 psi. Tag bottom at 8214' MD. Pickup to up weight then pick up 4' (8208' MD) and mark i e. 02:15 03:00 0.75 8,210 8,210 COMPZ CASING RURD P Lay down single and pick up cement head. Make up lines with cement head in mouse hole. 03:00 03:45 0.75 8,210 8,210 COMPZ CEMEN" CIRC P Circulate thru cement head. Retag bottom, pick up and mark pipe. Reci rocatin i e 30' 03:45 04:15 0.50 8,210 8,210 COMPZ CEMEN" SFTY P PJSM - on cement job with Baker, Dowell, ri crew and truck drivers. 04:15 05:00 0.75 8,210 8,210 COMPZ CEMEN' CIRC P Continue circulating while batching up mud push, cement and priming um s. 05:00 05:45 0.75 8,210 8,210 COMPZ CEMEN" CMNT P Flood tines and pressure test to 4500 psi. Pump 20 bbls 13.8 ppg Mud Push at 4.1 bpm followed by 33 bbls of 16.0 ppg cement at 3.5 bpm. Pumping unit could not get to 5 bpm with cement. Shut safety valve and clear cement from lines. Drop plug, observed tattletale trip then open safety valve. Dowell displaced cement with 12.4 ppg mud at 5 bpm. 5 bbls into displacement caught up to plug. Observed drill pipe wiper dart hit liner wiper plug 77 bbls into displacement. Continued with displacement until 81.3 bbls cement away and slowed pumps to 3 bpm. Bumped plug 85.7 bbls into displacement. Pressured up to 2700 psi and held then up to 3900 psi to set hanger and release tool. Held pressure, bleed off and checked floats. 05:45 06:00 0.25 8,210 8,210 COMPZ CASING RUNL P Set down to get off of hanger. Hanger stilt on. Attempt to pressure up w/rig and blew o off. 06:00 06:30 0.50 8,210 8,210 COMPZ CASING RUNL P Switch back to Dowell and pressure up to 4200 psi, bleed off, check floats and slack offer Hanger not set. Pressure up to 4500 psi with Dowell. Bleed off and slack off to 90k. Hanger set. Pick up 5' to let packer setting dogs out. Set down to 90k to set packer. Pick up and set down two more time while rotatin . ~ f~ar~e 33 ~sf ~~ I ~ ~ ~\ • Time Logs _--- ----- -- Date From To Dur_ S. De th E. Depth Phase -- Code Subcode T CornmEnt 06:30 08:45 2.25 8,210 8,210 COMPZ CEMEN' CIRC P Pressure up to 500 psi with rig pumps and pick up 7' to clear seals. Maintained 500 psi as running tool cleared hanger. Increase rate and pumped 30 bbls. Shut down pumps, closed rams and reversed out cement at 3.5 bpm, 890 psi. ,Circulated out 30 bbls of cement/mud ush contaiminated mud. Shut down, open rams and circulated two bottoms up pumping down drill i e. 08:45 10:00 1.25 8,210 8,210 COMPZ CEMEN' PULD P Blow down lines, lay down double. Rig down lines and cement head. Break out crossovers. Lay down cement head. 10:00 10:15 0.25 8,210 8,210 COMPZ CASING RURD P Clear and clean rig floor. 10:15 10:30 0.25 8,210 8,210 COMPZ CASING SFTY P PJSM -laying down drill pipe. 10:30 11:30 1.00 8,210 8,210 COMPZ DRILL PULD P POOH laying down drill pipe PU wt 175k, SO wt 140k. 11:30 12:00 0.50 8,210 8,210 COMPZ RIGMNT SVRG P Install dog collar and hang blocks. 12:00 12:30 0.50 8,210 8,210 COMPZ RIGMNT SFTY P PJSM -slip and cut drilling line 12:30 14:00 1.50 8,210 8,210 COMPZ RIGMNT SVRG P Slip and cut drilling line, inspect rollers and ad~ust breaks. 14:00 14:45 0.75 8,210 8,210 COMPZ RIGMNT SVRG P Service crown, blocks, top drive and iron rou hneck. 14:45 22:00 7.25 8,210 8,210 COMPZ DRILL PULD P POOH laying down drill pipe. Lay down 4 stands from derrick. 22:00 23:15 1.25 8,210 8,210 COMPZ DRILL PULD P Lay down liner running tools. Sim ops: cleaning pits and unloading 4" drill i e from shed. 23:15 00:00 0.75 8,210 8,210 COMPZ CASING DHEQ P Ri and test liner too sacker to , 1500 si for 10 minutes. Good test. Ri down and blow down. 1 /21 /2009 Rig up and run 3-1/2"gas lift completion to TD. Displace well to seawater and spot corrosion inhibited brine on bottom. S ace out land tubin . Attem t to test tubin and 7-5/8" x 3-1/2"annulus. 00:00 00:30 0.50 8,210 8,210 COMPZ RPCOM RURD P Drain stack and pull wear bushing. 00:30 01:00 0.50 8,210 8,210 COMPZ RPCOM RURD P Pick up and rig up 3-1/2" handleing tools. Brin tubin han er to ri floor. 01:00 01:30 0.50 8,210 8,210 COMPZ RPCOM SFTY P PJSM -running completion string with Baker, GBR and crew. 01:30 02:00 0.50 8,210 8,210 COMPZ RPCOM RCST P - leti n st Pick up seal assembly and 1 joint of tubing. Casing tong safety interlock fittin leakin . 02:00 02:30 0.50 8,210 8,210 COMPZ RPCOM RCST T Replace hydraulic fitting on power ton s. 02:30 09:15 6.75 8,210 8,210 COMPZ RPCOM RCST P RIH with completion string recoding weights every 10 joints. PU wt 110k SO wt 100k. Power ton s failed. ~ ~~ Page 34 cf 37 ®®~ Time Lois _ Da_t_e_ FrornTo Dur S. De th E. De th Phase Code Subcode T Comment 09:15 11:30 2.25 8,210 8,210 COMPZ RIGMNT SVRG T Waiting on tongs from Deadhorse. Backups on location do not have safety interlock. Lubricate skate, iron roughneck, blocks and top drive. Pick up space out pups, rig up on wellhead for casing test, clear and clean ri floor. 11:30 12:00 0.50 8,210 8,210 COMPZ RPCOM RURD T Pick up and rig up power tongs. 12:00 14:15 2.25 8,210 8,210 COMPZ RPCOM RCST P RIH with completion string recording weights every 10 joints. PU wt 138k SO wt 110k. 14:15 14:45 0.50 8,210 8,210 COMPZ RPCOM RCST P Rig up head pin on joint #234. 14:45 15:30 0.75 8,210 8,210 COMPZ RPCOM RCST P RIH with completion pumping .5 bpm, 210 psi. Observed 30 psi increase in pressure as seals enter seal bore receptacle. Shut down pump and continued in hole until to in no o. 15:30 16:45 1.25 8,210 8,210 COMPZ RPCOM CIRC P Pull out of hole and displace well to seawater pumping 8.5 bpm, 2600 si. 16:45 18:15 1.50 8,210 8,210 COMPZ RPCOM RCST P Lay down 3 joints and pick up space out pups. Pick up joint #232 and tubin han er. 18:15 18:45 0.50 8,210 8,210 COMPZ RPCOM RCST P RIH pumping .5 bpm until seals en a ed. Sto um sand ick u 2'. 18:45 19:30 0.75 8,210 8,210 COMPZ RPCOM CIRC P Pump 5 bbls corrosion inhibited brine followed by 66 bbls of seawater at 5 b m, 360 si. 19:30 20:00 0.50 8,210 8,210 COMPZ RPCOM RCST P Land completion and run in lock down screws 20:00 20:15 0.25 8,210 8,210 COMPZ RPCOM RURD P Pull landing joint and rig up test e ui ment. 20:15 21:15 1.00 0 0 COMPZ RPCOM DHEO P Pressure u tubin to 2500 psi using mud pump 1 pumping down kill line, blinds closed. Hold for 15 minutes. Bleed down tubing to 2000 psi and hold while pressuring annulus. Pressure uo 7-5/8" x 3-1/2" annulus using mud pump 2 pumping down secondary kill line. Observed sharp 700 psi pressure increase in tubing pressure as annulus pressure 2 si. A ears tubin and annulus ressure a ualized. Shut in annulus at 3000 psi. Pressure bleeding off both tubing and annulus at about 25 psi /minute. Inspect and troubleshoot surface system for leaks. Bleed off annulus. 21:15 23:00 1.75 8,210 8,210 COMPZ RPCOM DHEQ T Continue troubling shooting. Pick up landing joint and make up lines to head pin. Found curfacp system leakin off so between kill line and seconds kill line. Discussin o tions with town. ~~ #~;~~~ ~5 of 37 ~~ Time Logs _ _ ____ Date From - To - Dur _ _ S De th E. De th _ Phase Code Subcode T Comment 23:00 00:00 __ 1.00 0 0 - COMPZ RPCOM DHEQ T pr~re up tubing to 2500 psi using mud pump 1 pumping through mud line. Hold for 15 minutes then bleed off to 2000 psi and hold while pressuring annulus. Line up mud pump 1 on annulus and stage up pressure. Held 2000 and 2500 psi for 2 minutes. At 2600 psi pressure between annulus and tubin e ualized. Continued on u to 3000 psi and held. Discuss with town while holding pressure on tubing and annulus. 1 /22/2009 Test tubing and 7-5/8" x 3-1/2" annulus. Shear out GLM and establish circulation. Nipple down BOP stack and nipple up tree. Test pack-off and tree. Freeze protect well and release rig. Moved camp to 3H pad. RIG RELEASE 18:00 00:00 01:30 1.50 0 0 COMPZ RPCOM DHEQ T Discuss with town while holding pressure on tubing and annulus. Decision made to bleed off tubing and shear out GLM. 01:30 01:45 0.25 0 0 COMPZ RPCOM DHEQ T Bleed off tubing pressure. Both tubing and casing pressure dropped together. No obvious indication that valve shear. 01:45 02:00 0.25 0 0 COMPZ RPCOM CIRC T Pump down annulus at .5 bpm 200 psi taking returns up tubing to confirm there is communication between annulus and tubin . 02:00 03:00 1.00 0 0 COMPZ RPCOM CIRC T Pressure u on well umpinq down tubin to 3000 psi to confirm integrity of wellbore. Pressure held. 03:00 03:15 0.25 0 0 COMPZ RPCOM RURD P Pull landing joint, rig down test e ui ment and blow down lines. 03:15 03:30 0.25 0 0 COMPZ RPCOM RCST P Set two-way check valve in tubing han er. 03:30 05:15 1.75 0 0 COMPZ WELCTL NUND P Nipple down BOP stack. 05:15 09:00 3.75 0 0 COMPZ RPCOM NUND P Pick up and nipple up tubing head ada ter and tree. 09:00 09:30 0.50 0 0 COMPZ RPCOM DHEQ P Pressure test tubing hanger void and packoff to 250 psi & 5000 psi. Hold each for 10 minutes. Good test. 09:30 10:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM -pressure testing tree 10:00 12:45 2.75 0 0 COMPZ RPCOM DHEQ P Rig up and test tree using Little Red. Test to 250 psi & 5000 psi holding each for 10 minutes. Good test. Sim ops: cleaning pits, preparing to move ri . 12:45 13:15 0.50 0 0 COMPZ RPCOM SFTY P PJSM -free protecting tubing and annulus. v` 'CWG. 13:15 16:00 2.75 0 0 COMPZ RPCOM FRZP P Freeze protec well pumping 100 bbls down annulus at 1 bpm. Final pumping pressure 280 psi. Sim ops: re arin to move rockwasher. ~ P~~~ 36 of 37 i Time Logs - - _- -_ Date From To Dur S. De th-.E. De th Phase Code Subcode T Comment 16:00 17:00 1.00 0 0 COMPZ RPCOM FRZP P Put annulus and tubing in communication at surface and allow well to U-tube diesel into tubin . 17:00 18:00 1.00 0 0 COMPZ RPCOM RCST P Close annulus and tree valves, install gauges and record pressures., Install BPV (pressures 10-3/4" x 7-5/8" annulus 250 psi, 7-5/8" x 3-1 /2" annulus 0 psi, tubing 0 psi) Sim ops: move rockwasher. RIG RELEASE 18:00 HOURS __._ ~. Page 37 of 3? • 2A-26 Post Rig Well Events Summary • DATE SUMMARY 2/2/09 TAGGED WITH 2.775" G/R @ 7836' WLM. PULLED SOV, SET DV @ 7458' RKB. TESTED TBG 2500 PSI, IA 3000 PSI, GOOD. READY FOR CTU. 2/10/09 PERFORM MUD SWAP TO PBTD @ 8080 CTMD, WELL IS FLUID PACKED WITH DIESEL, READY FOR E-LINE. 2/13/09 DRIFT TBG W/ 20' OF 2.67", TAGGED @ 8210' SLM, NO SAMPLE OBTAINED, JOB COMPLETE. 2/14/09 RAN SFRT CASED HOLE RESISTIVITY LOG FROM 8080-7805' WITH 2' VERTICAL RESOLUTION. REPEATED SFRT FROM 7910-7805' WITH 1' VERTICAL RESOLUTION. AGREEMENT WITH OPEN HOLE LOG NOTED. 2/16/09 PERFORATE INTERVAL FROM 7860' TO 7875' WITH 2.5" HYPERJET 2506. API DATA: ENTRANCE HOLE=0.43", PENETRATION=13.1", 6 SPF, 60 DEGREE PHASING STATIC BOTTOM HOLE PRESSURE SURVEY AT 7867.5': 3940.9 PSI, 159.8 DEG F SBHP 7458': 3808.6 PSI, 145 DEG F "*NOTE: PRESSURE TESTED BOTH TBG & IA TO 3500 PSI SEPERATELY PRIOR TO PERFORATING BOTH PASSED*" 2/21/09 COMPLETED A SAND HYDRAULIC FRACTURE STIMULATION. FRAC SCREENED OUT WITH 80 BBLS OF THE 170 BBL 8 PPA STAGE BEHIND PIPE. PUMPED A TOTAL OF 116,533# OF 16/20 CARBOLITE PLACING 99,104# INTO THE FORMATION. RECOVERED 25% OF THE TREESAVER ELEMENTS. 2/23/09 PERFORMED FCO TO PBTD @ 8109' CTMD, WITH SSW AND FLOW ZAN. MADE A UP AND DOWN PASS AT EACH MANDREL, HAD GOOD ONE FOR ONE RETURNS, HEAVY SAND RETURNS, LEFT WELL SHUT IN, FREEZE PROTECTED WITH SLICK DIESEL, READY FOR SLICK LINE. 2/24/09 TAGGED @ 8074' SLM. PULLED DVs @ 7458' AND 6830' RKB. SET 1/4" OV @ 7458' RKB. IN PROGRESS. 2/25/09 PULLED DVs @ 5637', 4215', AND 2621' RKB. SET GLVs @ 2621', 4215', 5637', AND 6832' RKB. ATTEMPTED SET 2.81 CAT SV (2.84 NO-GO) AT 7515' RKB; UNABLE TO PASS DS NIPPLE @ 511' RKB. CONTINUED TROUBLESHOOTING IDENTIFIED NIPPLE SIZES ON HANDOVER FORM IN ERROR: APPEARS TO BE 2.81" DS @ 508', 2.75" D @ 7515'. SET 2.75" CAT SV @ 7515' RKB, TESTED TBG 2500 PSI, GOOD. COMPLETE. • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2A Pad 2A-26 Permit to Drill: 208-094 API: 50-103-20575-00 ~Spe~rry C~r~11~n~ ;+e~rv~e Definitive Survey Report 09 February, 2009 Tr-1,A,1..~1'~ UI R Tt7l~ €~pt~~*~y Drillir-g ~er~vice Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2A Pad Wel I: 2A-26 Wel Ibore: 2A-26 Design: 2A-26 ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: We112A-26 TVD Reference: 2A-26 (40.35+92.1) @ 132.45ft (Doyon 15} MD Reference: ZA-26 (40.35+92.1) @ 132.45ft (Doyon 15) North Reference: True ' Survey Calculation Method: Minimum Curvature Database: CPAI EDM Production Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor 'Well 2A-26 -_ _ _ _ _ Well Position +N/-S 0.00 ft Northing: 5,959,948.06 ft Latitude: 70° 18' 7.859 N +E/-W 0.00 ft Easting: 1,638,653.34 ft Longitude: 150° 0' 51.419 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 92.10ft Wellbore 2A-26 __ _ __ Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2007 12/21/2008 22.26 80.78 57,633 Design 2A-26 ___. Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 40.35 Vertical Secti on: Depth From (TVD) +NI-S +FJ-W Direction (ft) (ft) (ft) (°) 40.35 0.00 0.00 132.62 Survey Program Date 1/28/2009 From To (ft) (ft) Survey (Wellbore) Tool Name Description 100.00 730.00 2A-26 Rig Gyro (0-730) (2A-26) CB-GYRO-SS Camera based gyro single shot 781.80 7,448.95 2A-26 Rig MWD (781.8-7448.95) (2A-26; MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,490.00 7,770.00 2A-26 Gyro (7490-7770) (2A-26) GYD-CT-CMS Gyrodata cont.casing m/s 7,828.61 8,17220 2A-26 Rig MWD (7828.61-8172.2 (2A-26 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey MD Inc Azi TVD TVDSS (ft) (°) (°) (ft) (ft) 40.35 0.00 0.00 40.35 -92.10 100.00 0.54 354.52 100.00 -32.45 168.00 0.64 358.28 168.00 35.55 263.00 1.61 150.53 262.99 130.54 355.00 4.06 151.40 354.87 222.42 445.00 5.17 144.98 444.57 312.12 500.00 7.00 140.84 499.26 366.81 600.00 10.46 137.12 598.09 465.64 665.00 12.24 137.82 661.81 529.36 730.00 12.58 141.90 725.30 592.85 781.80 13.65 141.44 775.75 643.30 Survey Date 1 /2/2009 12: 112/2009 12: 1112!2009 1: 1 /19/2009 1: Map Map Vertical +N!-S +E/-W Northing Easting DLS Section (ft) (ft) (ft} (ft) (°/100') (ft) Survey Tool Name 0.00 0.00 5,959,948.06 1,638,653.34 0.00 0.00 UNDEFINED 0.28 -0.03 5,959,948.34 1,638,653.31 0.91 -0.21 CB-GYRO-SS (1) 0.98 -0.07 5,959,949.04 1,638,653.27 0.16 -0.71 CB-GYRO-SS (1) 0.35 0.57 5,959,948.41 1,638,653.91 2.31 0.19 CB-GYRO-SS (1) -3.64 2.77 5,959,944.42 1,638,656.11 2.66 4.50 CB-GYRO-SS (1) -9.76 6.62 5,959,938.30 1,638,659.96 1.36 11.48 CB-GYRO-SS (1) -14.39 10.16 5,959,933.67 1,638,663.49 3.42 17.22 CB-GYRO-SS (1) -25.77 20.19 5,959,922.29 1,638,673.52 3.50 32.30 CB-GYRO-SS (1) -35.20 28.83 5,959,912.86 1,638,682.16 2.75 45.05 CB-GYRO-SS (1) -45.87 37.82 5,959,902.18 1,638,691.15 1.45 58.89 CB-GYRO-SS (1) -55.09 45.11 5,959,892.96 1,638,698.44 2.08 70.50 MWD+IFR-AK-CAZ-SC (2) 2/9/2009 9:30:05AM Page 2 COMPASS 2003.16 Build 42F • ConocoPhillips Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: We112A-26 Project: Kuparuk River Unit TVD Reference: 2A-26 (40.35+92.1) @ 132.45ft (Doyon 15) Site: Kuparuk 2A Pad MD Reference: 2A-26 (40.35+92.1) @ 132.45ft (Doyon 15) Well: 2A-26 North Reference: True Wellbore: 2A-26 Survey Calculation Method: Minimum Curvature Design: 2A-26 Database: CPAI EDM Production Survey ~~ Map Map Vertical ', MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Fasting DLS Section (ft) (°) (°) (ft) (ft} (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 877.15 15.67 143.43 867.99 735.54 -74.23 59.80 5,959,873.82 1,638,713.12 2.18 94.27 MWD+IFR-AK-CAZ-SC (2) 972.17 15.61 144.50 959.49 827.04 -94.95 74.87 5,959,853.11 1,638,728.18 0.31 119.38 MWD+IFR-AK-CAZ-SC (2) 1,067.60 15.59 145.86 1,051.40 918.95 -116.01 89.52 5,959,832.04 1,638,742.83 0.38 144.43 MWD+IFR-AK-CAZ-SC (2) 1,163.12 18.10 144.78 1,142.82 1,010.37 -138.76 105.29 5,959,809.29 1,638,758.58 2.65 171.43 MWD+IFR-AK-CAZ-SC (2) 1,257.95 19.25 144.84 1,232.65 1,100.20 -163.58 122.78 5,959,784.47 1,638,776.07 1.21 201.11 MWD+IFR-AK-CAZ-SC (2) 1,353.32 20.98 142.88 1,322.20 1,189.75 -190.05 142.14 5,959,758.00 1,638,795.42 1.95 233.28 MWD+IFR-AK-CAZ-SC (2) 1,447.78 24.16 141.92 1,409.42 1,276.97 -218.75 16428 5,959,729.29 1,638,817.55 3.39 269.01 MWD+IFR-AK-CAZ-SC (2) 1,543.17 26.04 140.60 1,495.80 1,363.35 -250.30 189.61 5,959,697.74 1,638,842.87 2.06 309.01 MWD+IFR-AK-CAZ-SC (2) 1,640.00 28.93 137.53 1,581.69 1,449.24 -284.01 218.92 5,959,664.03 1,638,872.17 3.32 353.40 MWD+IFR-AK-CAZ-SC (2) 1,734.78 30.18 137.11 1,664.14 1,531.69 -318.38 250.61 5,959,629.66 1,638,903.85 1.34 400.00 MWD+IFR-AK-CAZ-SC (2) 1,829.59 31.39 138.75 1,745.59 1,613.14 -354.40 283.12 5,959,593.63 1,638,936.34 1.55 448.31 MWD+IFR-AK-CAZ-SC (2) 1,924.51 34.49 139.26 1,825.24 1,692.79 -393.36 316.96 5,959,554.66 1,638,970.18 3.28 499.59 MWD+IFR-AK-CAZ-SC (2) 2,019.12 33.96 138.35 1,903.47 1,771.02 -433.40 352.01 5,959,514.62 1,639,005.21 0.78 552.49 MWD+IFR-AK-CAZ-SC (2) 2,114.51 35.14 138.12 1,982.03 1,849.58 -473.75 388.04 5,959,474.27 1,639,041.23 1.24 606.33 MWD+IFR-AK-CAZ-SC (2) 2,210.11 34.92 138.30 2,060.32 1,927.87 -514.67 424.61 5,959,433.35 1,639,077.79 0.25 660.95 MWD+IFR-AK-CAZ-SC (2) 2,305.64 34.98 138.68 2,138.62 2,006.17 -555.65 460.88 5,959,392.36 1,639,114.04 0.24 715.38 MWD+IFR-AK-CAZ-SC (2) 2,400.65 34.74 138.35 2,216.58 2,084.13 -596.33 496.85 5,959,351.68 1,639,150.00 0.32 769.40 MWD+IFR-AK-CAZ-SC (2) 2,496.32 35.19 137.81 2,294.98 2,162.53 -637.12 533.48 5,959,310.88 1,639,186.62 0.57 823.98 MWD+IFR-AK-CAZ-SC (2) 2,591.05 34.95 135.47 2,372.52 2,240.07 -676.69 570.84 5,959,271.30 1,639,223.97 1.44 878.26 MWD+IFR-AK-CAZ-SC (2) 2,686.56 35.68 134.73 2,450.45 2,318.00 -715.80 609.82 5,959,232.19 1,639,262.93 0.89 933.42 MWD+IFR-AK-CAZ-SC (2) 2,781.07 37.71 136.82 2,526.23 2,393.78 -756.28 649.18 5,959.191.71 1,639,302.28 2.52 989.80 MWD+IFR-AK-CAZ-SC (2) 2,877.08 39.82 136.57 2,601.09 2,468.64 -800.02 690.41 5,959,147.96 1,639,343.50 2.20 1,049.76 MWD+IFR-AK-CAZ-SC (2) 2,970.97 41.47 135.73 2,672.36 2,539.91 -844.09 732.76 5,959,103.89 1,639,385.83 1.79 1,110.76 MWD+IFR-AK-CAZ-SC (2) 3,066.45 42.42 135.46 2,743.41 2,610.96 -889.65 777.39 5,959,058.31 1,639,430.44 1.07 1,174.46 MWD+IFR-AK-CAZ-SC (2) 3,103.62 42.59 134.60 2,770.81 2,638.36 -907.42 795.14 5,959,040.54 1,639,448.19 1.63 1,199.55 MWD+IFR-AK-CAZ-SC (2) 3,133.79 43.61 134.36 2,792.84 2,660.39 -921.86 809.85 5,959,026.10 1,639,462.89 3.42 1,220.15 MWD+IFR-AK-CAZ-SC (2) 3,214.64 46.12 133.77 2,850.14 2,717.69 -961.52 850.83 5,958,986.44 1,639,503.86 3.15 1,277.16 MWD+IFR-AK-CAZ-SC (2) 3,310.27 48.54 133.00 2,914.95 2,782.50 -1,009.81 901.93 5,958,938.14 1,639,554.94 2.60 1,347.46 MWD+IFR-AK-CAZ-SC (2) 3,404.58 48.66 132.78 2,977.32 2,844.87 -1,057.96 953.76 5,958,889.99 1,639,606.76 0.22 1,418.21 MWD+IFR-AK-CAZ-SC (2) 3,499.42 48.73 134.30 3,039.92 2,907.47 -1,107.03 1,005.40 5,958,840.90 1,639,658.38 1.21 1,489.44 MWD+IFR-AK-CAZ-SC (2) 3,595.25 49.70 130.01 3,102.53 2,970.08 -1,155.69 1,059.18 5,958,792.24 7,639,712.15 3.54 1,561.96 MWD+IFR-AK-CAZ-SC (2) 3,690.17 48.21 729.43 3,164.86 3,032.41 -1,201.44 1,114.24 5,958,746.48 1,639,767.19 1.64 1,633.46 MWD+IFR-AK-CAZ-SC (2) 3,785.38 48.31 128.91 3,228.25 3,095.80 -1,246.31 1,169.32 5,958,701.60 1,639,822.25 0:42 1,704.37 MWD+IFR-AK-CAZ-SC (2) 3,880.71 47.94 130.18 3,291.88 3,159.43 -1,291.50 1,224.06 5,958,656.40 1,639,876.97 1.07 1,775.25 MWD+IFR-AK-CAZ-SC (2) 3,976.08 49.43 127.48 3,354.85 3.222.40 -1,336.39 1,279.86 5,958,611.50 1,639,932.76 2.64 1,846.71 MWD+IFR-AK-CAZ-SC (2) 4,066.32 50.83 126.54 3,412.70 3,28025 -1,378.08 1,335.17 5,958,569.81 1,639,988.05 1.75 1,915.63 MWD+IFR-AK-CAZ-SC (2) 4,162.40 51.97 127.46 3,472.64 3,340.19 -1,42327 1,395.13 5,958,524.61 1,640,048.00 1.40 1,990.36 MWD+IFR-AK-CAZ-SC (2) 4,261.03 51.87 125.26 3,533.48 3,401.03 -1,469.29 1,457.64 5,958,478.57 1,640,110.49 1.76 2,067.52 MWD+IFR-AK-CAZ-SC (2) 4,357.35 51.59 127.58 3,593.14 3,460.69 -1,514.18 1,518.49 5,958,433.68 1,640,171.32 1.91 2,142.69 MWD+IFR-AK-CAZ-SC (2) 4,452.29 51.54 131.42 3,652.17 3,519.72 -1,561.47 1,575.85 5,958,386.38 1,64Q228.67 3.17 2,216.93 MWD+IFR-AK-CAZ-SC (2) 2/9/2009 9:30:05AM Page 3 COMPASS 2003.16 wild 4214 • C onocoi' hillips Definitive Survey Report Company: ConocoPhillips (Alaska) I nc. -Kup2 Local Co-ordinate Refe rence: Well 2A-26 Project: Kuparuk River Unit TVD Refer ence: 2A-26 (40.3 5+92.1) @ 132.45ft (Doyon 15) Site: Kuparuk 2A Pad MD Refere nce: 2A-26 (40.3 5+92.1) @ 132.45ft (Doyon 15) Well: 2A-26 North Reference: True Wellbore: 2A-26 Survey Ca lculation Met hod: Minimum Curvature Design: 2A-26 Database: CPAI EDM Production Survey I Map Map Vertical MD (ft) Inc (°) Azi (°) TVD (ft) TVDSS (ft) +N/-S (ft) +FJ-W (ft) Northing (ff) Easting DLS (ft) (°i100') Section (ft) Survey Tool Name 4,547.48 51.34 131.68 3,711.51 3,579.06 -1,610.84 1,631.56 5,958,337.00 1,640,284.36 0.30 2,291.35 MWD+IFR-AK-CAZ-SC (2} 4,642.15 51.02 132.06 3,770.85 3,638.40 -1,660.07 1,686.49 5,958,287.76 1,640,339.27 0.46 2,365.10 MWD+IFR-AK-CAZ-SC (2) 4,737.71 50.83 131.30 3,831.09 3,698.64 -1,709.40 1,741.89 5,958,238.42 1,640,394.66 0.65 2,439.27 MWD+IFR-AK-CAZ-SC (2) 4,834.31 51.79 131.74 3,891.47 3,759.02 -1,759.38 1,798.34 5,958,188.43 1,640,451.09 1.06 2,514.66 MWD+IFR-AK-CAZ-SC (2) 4,929.79 51.65 133.09 3,950.62 3,818.17 -1,809.93 1,853.68 5,958,137.88 1,640,506.41 1.12 2,589.61 MWD+IFR-AK-CAZ-SC (2) 5,023.16 51.51 133.41 4,008.65 3,876.20 -1,860.05 1,906.96 5,958,087.74 1,640,559.67 0.31 2,662.76 MWD+IFR-AK-CAZ-SC (2) 5,118.18 51.63 129.93 4,067.72 3,935.27 -1,909.53 1,962.55 5,958,038.26 1,640,615.24 2.87 2,737.16 MWD+IFR-AK-CAZ-SC (2) 5,212.97 51.27 130.30 4,126.79 3,994.34 -1,957.29 2,019.24 5,957,990.49 1,640,671.92 0.49 2,811.22 MWD+IFR-AK-CAZ-SC (2) 5,307.48 51.54 129.74 4,185.75 4,053.30 -2,004.79 2,075.81 5,957,942.98 1,640,728.47 0.54 2,885.01 MWD+IFR-AK-CAZ-SC (2) 5,403.19 51.24 130.41 4,245.47 4,113.02 -2,052.94 2,133.04 5,957,894.83 1,640,785.68 0.63 2,959.73 MWD+IFR-AK-CAZ-SC (2) 5,496.39 50.78 131.36 4,304.11 4,171.66 -2,100.35 2,187.80 5,957,847.41 1,640,840.43 0.93 3,032.13 MWD+IFR-AK-CAZ-SC (2) 5,593.58 51.90 130.29 4,364.83 4,232.38 -2,149.96 2,245.23 5,957,797.79 1,640,897.84 1.44 3,107.98 MWD+IFR-AK-CAZ-SC (2) 5,689.22 51.57 130.18 4,424.06 4,291.61 -2,198.46 2,302.56 5,957,749.28 1,640,955.15 0.36 3,183.01 MWD+IFR-AK-CAZ-SC (2) 5,783.79 51.40 130.04 4,482.95 4,350.50 -2,246.14 2,359.15 5,957,701.60 1,641,011.73 0.21 3,256.94 MWD+IFR-AK-CAZ-SC (2) 5,879.31 51.44 130.07 4,542.51 4,410.06 -2,294.19 2,416.31 5,957,653.53 1,641,068.87 0.05 3,331.53 MWD+IFR-AK-CAZ-SC (2) 5,973.56 51.40 130.22 4,60129 4,468.84 -2,341.69 2,472.63 5,957,606.02 1,641,125.17 0.13 3,405.14 MWD+IFR-AK-CAZ-SC (2) 6,068.59 51.18 130.56 4,660.72 4,52827 -2,389.74 2,529.11 5,957,557.96 1,641,181.63 0.36 3,479.24 MWD+IFR-AK-CAZ-SC (2) 6,164.24 50.81 130.69 4,720.92 4,588.47 -2,438.14 2,585.52 5,957,509.56 1,641,238.03 0.40 3,553.52 MWD+IFR-AK-CAZ-SC (2) 6,259.67 50.91 131.07 4,781.16 4,648.71 -2,486.58 2,641.48 5,957,461.11 1,641,293.98 0.33 3,627.51 MWD+IFR-AK-CAZ-SC (2) 6,354.88 50.90 132.01 4,841.20 4,708.75 -2,535.58 2,696.79 5,957,412.10 1,641,34927 0.77 3,701.38 MWD+IFR-AK-CAZ-SC (2) 6,449.09 49.18 130.18 4,901.71 4,769.26 -2,583.05 2,751.20 5,957,364.62 1,641,403.65 2.36 3,773.56 MWD+IFR-AK-CAZ-SC (2) 6,544.98 47.61 128.94 4,965.38 4,832.93 -2,628.72 2,806.46 5,957,318.95 1,641,458.91 1.90 3,845.16 MWD+IFR-AK-CAZ-SC (2) 6,640.46 45.16 128.72 5,03123 4,898.78 -2,672.06 2,860.31 5,957,275.60 1,641,512.73 2.57 3,914.13 MWD+IFR-AK-CAZ-SC (2) 6,735.52 41.43 129.09 5,100.41 4,967.96 -2,712.99 2,911.03 5,957,234.66 1,641,563.44 3.93 3,979.17 MWD+IFR-AK-CAZ-SC (2) 6,830.64 38.66 130.42 5,173.22 5,040.77 -2,752.10 2,958.09 5,957,195.54 1,641,610.49 3.05 4,040.28 MWD+IFR-AK-CAZ-SC (2) 6,901.71 37.13 129.52 5,229.30 5,096.85 -2,780.15 2,991.54 5,957,167.49 1,641,643.92 2.29 4,083.88 MWD+IFR-AK-CAZ-SC (2) 6,996.47 34.09 130.37 5,306.34 5,173.89 -2,815.56 3,033.84 5,957,132.07 1,641,686.22 3.25 4,138.99 MWD+IFR-AK-CAZ-SC (2) 7,091.56 30.88 130.50 5,386.54 5,254.09 -2,848.67 3,072.71 5,957,098.95 1,641,725.07 3.38 4,190.02 MWD+IFR-AK-CAZ-SC (2) 7,186.90 27.97 133.71 5,469.57 5,337.12 -2,880.02 3,107.48 5,957,067.60 1,641,759.84 3.47 4,236.83 MWD+IFR-AK-CAZ-SC (2) 7,282.13 25.41 132.46 5,554.65 5,422.20 -2,909.25 3,138.71 5,957,038.36 1,641,791.05 2.75 4,279.60 MWD+IFR-AK-CAZ-SC (2) 7,328.86 25.17 132.80 5,596.90 5,464.45 -2,922.77 3,153.39 5,957,024.84 1,641,805.73 0.60 4,299.56 MWD+IFR-AK-CAZ-SC (2) 7,377.27 24.92 132.14 5,640.76 5,508.31 -2,936.61 3,168.51 5,957,011.00 1,641,820.84 0.77 4,320.06 MWD+IFR-AK-CAZ-SC (2) 7,448.95 24.50 133.23 5,705.88 5,573.43 -2,956.92 3,190.54 5,956,990.69 1,641,842.86 0.86 4,350.02 MWD+IFR-AK-CAZ-SC (2) 7,490.00 24.54 133.70 5,743.22 5,610.77 -2,968.64 3,202.90 5,956,978.97 1,641,855.22 0.49 4,367.05 GYD-CT-CMS (3) 7,590.00 22.27 133.85 5,834.99 5.702.54 -2,996.12 3,231.58 5,956,951.48 1,641,883.90 227 4,406.76 GYD-CT-CMS (3) 7,690.00 20.78 133.00 5,928.01 5,795.56 -3,021.34 3,258.22 5,956,92625 1,641,910.53 1.52 4,443.45 GYD-CT-CMS (3) 7,770.00 20.49 134.15 6,002.88 5,870.43 -3,040.78 3,278.65 5,956,906.82 1,641,930.95 0.62 4,471.64 GYD-CT-CMS (3) 7,828.61 19.31 135.67 6,057.99 5,925.54 -3,054.85 3,292.78 5,956,892.74 1,641,945.07 2.20 4,491.57 MWD+IFR-AK-CAZ-SC (4) 7,924.43 19.21 135.69 6,148.45 6,016.00 -3,077.47 3,314.86 5,956,870.12 1,641,967.15 0.10 4,523.13 MWD+IFR-AK-CAZ-SC (4) 8,019.42 19.00 136.05 6,238.21 6.105.76 -3,099.78 3,336.51 5,956,847.81 1,641,988.79 025 4,554.17 MWD+IFR-AK-CAZ-SC (4) 2!9/2009 9:30;05AM Page 4 COMPASS 2003.16 Build 42F Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2A Pad Wel I: 2A-26 Wel Ibore: 2A-26 Design: 2A-26 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2A-26 2A-26 (40.35+92.1) @ 132.45ft (Doyon 15) 2A-26 (40.35+92.1) @ 132.45ft (Doyon 15) True Minimum Curvature CPAI EDM Production Map Map Vertical MD Inc Azi TVD TVDSS +N/~ +E/-W Northing Easting DLS Section (ft} (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,111.41 18.72 136.03 6,325.26 6,192.81 -3,121.19 3,357.15 5,956,826.40 1,642,009.43 0.30 4,583.85 MWD+IFR-AK-CAZ-SC (4) 8,172.20 18.66 137.17 6,382.84 6,250.39 -3,135.34 3,370.54 5,956,812.24 1,642,022.80 0.61 4,603.29 MWD+IFR-AK-CAZ-SC (4) 8,210.00 • 18.66 137.17 6,418.66 6,286.21 -3,144.21 3,378.76 5,956,803.37 1,642,031.02 0.00 4,615.34 PROJECTED to TD 2/9/2009 9:30:05AM Page 5 COMPASS 2003.18 Build 42F J, ~--- $~~Ib~l~'~i' Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth -~ ~ ~~ ~~ 02/23/09 N0.5105 ~ ~~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 2B-06 AYS4-00031 INJECTION PROFILE C ~ ~ 02/02/09 1 2A-26 B04C-000011 SFRT 02/14/09 1 3F-07 AZED-00009 INJECTION PROFILE - 12/26/08 1 1 F-02 604C-00010 INJECTION PROFILE: 02/13/09 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 02/09/09 ~r tF ~ _ _ , ~i~f~lfl~~r~i _.. ^ ~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 ,, :, ,. Anchorage, AK 99503-2838 ATTN: Beth NO. 5063 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 1 L-13 11978475 PRODUCTION PROFILE ~- L $- 08/16/08 1 1 2A-26 AZJZ-00010 USIT ~- i5 01/16/09 1 1 1D-141A ANHY-00041 FLOWING BHP 01/21/09 1 1 3K-15 B04C-00004 INJECTION PROFILE ' ~ 01/21/09 1 1 1E-105 AZED-00019 INJECTION PROFILE 01/23/09 1 1 1 E-119 AYS4-00023 INJECTION PROFILE ~ 01/23/09 1 1 3J-01 AYS4-00024 INJECTION PROFILE , 'r - 01/24/09 1 1 2V-06 AZED-00022 INJECTION PROFILE I$3- 1 01/26/09 1 1 2K-22 AZED-00024 LDL r~-,~ j 01/28/09 1 1 2L-301 AZED-00025 SBHP SURVEY - 01/29/09 1 1 1 R-03A ANHY-00045 INJECTION PROFILE '(' ~~- $` ~ 02/09/09 1 1 2B-11 AZED-00028 INJECTION PROFILE 02/01/09 1 1 2F-16 AZED-00029 INJECTION PROFILE U 02/02/09 1 1 3J-05 AZED-00030 INJECTION PROFILE 02!03/09 1 1 3G-07A AYS4-00033 PRODUCTION PROFILE j 02/04/09 1 1 1 D-03 ANHY-00042 LDL ~~ .- - 02/05/09 1 1 p Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. / ,{'" _ _ _ ... ~~ _ ~~.~ ~~~ (~ ~`~~~~s'~ ov23ios NO. 5056 __d_ Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 18-05 ANHY-0030 INJECTION PROFILE ~ (~ 01/09/09 1 1 2L-325 ANHY-00031 LDL _ 01/10/09 1 1 3M-03A AZJZ-00011 SFRT - (~- 01/11/09 1 1 2T-10 ANHY-00033 INJECTION PROFILE - 01/11/09 1 1 2L-301 AZJZ-00013 USIT 01/12/09 1 1 2A-26 AZJZ-00010 SONIC SCANNER _ - 01/15/09 1 1 2A-26 AZJZ-00010 SFRT Cj / 01/17/09 1 1 18-18 ANHY-00039 INJECTION PROFILE ~ ~ 01/19/09 1 1 2V-04 ANHY-00040 INJECTION PROFILE ~ ~ 01/20/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. l~ FW: 2A-26 AOGCC Well shut notification . Page 1 of 3 Maunder, Thomas E (DOA) From: McKeever, Steve {Steve.McKeever@conocophillips.com] Sent: Tuesday, January 13, 2009 3:46 PM To: Grimaldi, Louis R (DOA) Cc: Regg, James B (DOA); Greener, Mike R.; Maunder, Thomas E (DOA); Crisp, John H (DOA) Subject: RE: 2A-26 AOGCC Well shut in notification Attachment: 2A-26 Operations on 1.11 and 1.12.pdf Lou - Following up with you regarding the waiver from the requirements of (20 AAC 25.035, Paragraph (10) (C)) that you granted on Sunday, please find attached a report of the operations we've completed over the past couple of days on well 2A-26. Following the parting of the casing, we controlled the well with a heavy mud cap and were able to pull the 5 joints above the point of parting, install and test drill pipe rams, test the annular preventer, run in the hole with a spear on drill pipe, engage the fish, circulate kill weight mud into the well bore through the fish, and pull the casing below the parting to the rig floor. We laid down the bottom of the parted joint, then ran back in the hole with good casing to a shoe depth of 7796', where we cemented the casing in place. You asked if "Once you have retrieved the fish will you screw back into it with your FOSV and head pin to secure and change your upper rams back to 7 5/8", test and rerun the casing?". When the casing parted we had two sets of 7-5/8" rams in the stack. While fishing the casing with drill pipe we had one set of 7-5/8" rams and one set of 5" drill pipe rams in the stack. Once we decided that we were not going to drill ahead with casing any more, but instead just run back to setting depth with our casing, there was no longer a requirement to have two sets of 7-5/8" rams in the stack -only one was required, as is the case on any conventional casing job. Today, with the casing successfully cemented, we are installing rams to cover our pipe sizes for the next hole section and will complete a full bi-weekly BOP test. Please call if you have any questions or concerns. Steve McKeever Drilling Superintendent, Greater Kuparuk ConocoPhillips Alaska, Inc. office: 907.265.6826 cell: 907.351.5004 home: 907.345.1229 Units of Conversion: 6/13/2009 FW: 2A-26 AOGCC Well shinnotification 1000 aches: 1 kilohurtr Page 2 of 3 From: Grimaldi, Louis R (DOA) [mailto:lou.grimaldi@alaska.gov] Sent: Sunday, January li, 2009 8:01 PM To: McKeever, Steve Cc: Regg, James B (DOA); Greener, Mike R.; Maunder, Thomas E (DOA); Doyon 15 Company Man; Crisp, John H (DOA) Subject: RE: 2A-26 AOGCC Well shut in notification Steve, As we discussed this seems fine to me. Once you have retrieved the fish will you screw back into it with your FOSV and head pin to secure and change your upper rams back to 7 5/8", test and rerun the casing? I expect you will communicate to our office at some point with some more details on what led up to this. I don't need to know. If all this is how you see the forward operations then we are good. Lou From: McKeever, Steve [mailto:Steve.McKeever@conocophillips.com] Sent: Sunday, January 11, 2009 2:21 PM To: Grimaldi, Louis R (DOA) Cc: Regg, James B (DOA); Greener, Mike R.; Maunder, Thomas E (DOA); Doyon 15 Company Man Subject: FW: 2A-26 AOGCC Well shut in notification Lou - Further to our conversation, you have granted Conoco Phillips a waiver from the requirement (20 AAC 25.035, Paragraph (10) (C)) to function pressure test components used for well control before the next well bore entry for upcoming operations on well 2A-26. See below. This morning, while circulating and weighting up the mud system through the casing drilling string to gain a stable well bore, our casing string parted at +/- 650 feet. Following the casing failure, we began operations to lay in a heavy mud cap pill (15.6 ppg) in the top 650 feet of the well bore. While mixing that pill the well was shut in with the annular preventer, choke and kill valves and top drive drill string valve so that the top drive could be blown down. Approximately 2 hours after the well was shut in, 50 psi showing on the annulus was quickly bled off through the choke and the heavy mud cap pill was pumped into the top 650 feet of the well bore. Currently the well is not flowing with the mud cap pill in place, we are pulling out of the hole with the 650 feet of casing above the failure point. We plan to then change the upper set of pipe rams from 7-5/8" to 5", test those rams to 250 psi and 5000 psi and the annular to 250 psi and 3000 psi. Then we will pick up a casing spear with a pack off, run in to the fish with 5" drill pipe, displace the heavy mud cap pill from the top portion of the well with 12.2 ppg fluid, engage the spear and circulate down the fish out the bottom (i.e. the entire well bore) with 12.2 ppg fluid. Prior to picking up the spear we do not intend to test the other components (choke and kill line valves, and drill string valves), and you have agreed to this course of action. We will test these valves at the time of our next bi-weekly BOP test, now scheduled for on or before January 17th. 6/13/2009 FW: 2A-26 AOGCC Well shinnotification ~ Page 3 of 3 If you are in agreement with our plan to test only the 5" pipe rams and annular, and not the other components used to shut the well in, can you please so indicate with a response to this email? Thanks Steve McKeever Drilling Superintendent, Greater Kuparuk ConocoPhillips Alaska, Inc. office: 907.265.6826 cell: 907.351.5004 home: 907.345.1229 Units of Conversion: 1000 aches: 1 kilohurtz From: Doyon 15 Company Man Sent: Sunday, January 11, 2009 9:48 AM To: McKeever, Steve; Greener, Mike R.; Allsup-Drake, Sharon K; AOGCC; Bob Fleckenstein; Doyon 15 Company Man; Doyon 15 Tour Pusher; Eggemeyer, Jerome C.; Jim Regg; Thomas, Randy L Subject: 2A-26 AOGCC Well shut in notification Gentlemen, As requested by AOGCC Bob Noble notified at 9:20 AM. We have shut the well in on 2A-26 at 8:50 AM. We were in the process of driAing with 7-5/8" casing and toped the A-Sand. Circ and increased mud weight from 9.5 ppg to 11.8 ppg due to gas. We were going to increase mud weight to 12.0 ppg when the casing parted at calculated 633'. The plan is to put a 15.7 ppg cap on the well to achieve required bottom hole pressure prior to laying down casing. The well showed a slight flow, with pumps down with 11,8 ppg. Mike Thornton / Granville Rizek Doyon 15 Company man Office; 907-659-1755 Fax; 907-659-7364McKeever, Steve 6/13/2009 !' s ARAH PAL/N, GOVERNOR COI~SEB~~0 n ~cS~+I~ 333 W 7th AVENUE, SUITE 100 ~•jj 1.~~~~~..aaii~~iill--a-7-7 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Randy Thomas FAx (so7) 27sasaz Drilling Team Leader ConocoPhillips Alaska Inc. PO Box 100360 Anchorage AK 99510-360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2A-26 ConocoPhillips Alaska Inc. Permit No: 208-094 Surface Location: 776' FSL, 227' FWL, SEC. 13, T11N, R8E, UM Bottomhole Location: 2415' FNL, 1588' FEL, SEC. 24, T11N, R8E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required 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 iri accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerel Daniel T. Seamount, Jr. Chair DATED this 1 ?day of June, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~~~f f ~' ALASKA OIL AND GAS CONSERVATION COMMISSIONA~~k~ ~• `~uN Q 5 ~~08 PERMIT TO DRILL /~~ Gas ~o~ 20 AAC 25.005 ~llC '~' ~IJP}'j~1;~,~ir. hnP~„_ 1 a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^/ r Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number. 2A-26 r 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 8197' ~ ND: 6384' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 776' FSL, 227' FWL, Sec. 13, T11N, R8E, UM 7. Property Designation: ADL 25570 Kuparuk Oil Pool , Top of Productive Horizon: 2277' FNL, 1750' FEL, Sec. 24, T11N, R8E, UM 8. Land Use Permit: ALK 2668 13. Approximate Spud Date: 7/1/2008 Total Depth: 2415' FNL, 1588' FEL, Sec. 24, T71 N, R8E, UM d 9. Acres in Property: 2560 14. Distance to Nearest Property: > 2 miles 4b. Location of Well (State Base Plane Coordinates): Sp~ /~~ `•/( Surface: x- 498621 ~ y- I•i5980T3S'"(I Zone- 4 10. KB Elevation ~~ .3 (Height above GL): 114' AMSL fe€t !~• 15. Dis ce to Nearest (Well within Pool: 2A-16 , 1643' r~ 8197' 16. Deviated wells: Kickoff depth: 400' ft. Maximum Hole Angle: 48° . deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2718 psig - Surface: 2054 psig 18. Casing Program if i Setting Depth Quantity of Cement Size icat ons Spec Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (inGuding stage data) 24" 16" 62.5# H-40 Welded 80' 30' 30' 110' 110' Driven 13.5" 10.75" 45.5# L-80 BTC 3176' 30' 30' 3176' 2800' 590 sx AS Lite, 200 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 Hydril 563 7754' 30' 30' 7754' 5982' 370 sx Class G wlGasBLOK 6.75" 4.5" 12.6# L-80 IBTM 643' 7554' 5809' 8197' 6384' 120 sx Class G w/GasBLOK 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ^ BOP Sketch Drilling Program / Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^~ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 :' Printed Name Randy Thomas Title Drilling Team Leader Signature ~ ~ Phone -L65- ~ ~ 3 ~ Date 6 ~ ry~/O a Commission Use Only Permit to Drill QQ Number: L-~/C~ ~©~ ~ API Numbe/r:~ ~ /~ 50- fC,/ ,~ r G.+f/ ~~~ Permit Approval Date: • ~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed me hane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No Mud log req'd: Yes ^ No Other: H2S measures: Yes [~ No ^ Directional svy req'd: Yes [~/]+ No ^ ~,~' ~~ ~ APPROVED BY THE COMMISSION jQ DATE: ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~ ~ E ~ t t ~ ~ ~.. t(/yam /S/u~b"mit in,D/uplicate Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com May 19, 2008 Alaska Oil and Gas Conservation Commission 333 West 7'i' Avenue, Suite 100 Anchorage, Alaska 99501 ~r-riili ~~ V ~~~ 0 5 2008 RE: Application for Permit to Dri112A-26 ~~Ca QII & GAS ()CIS. COP11Ct1ission Dear Commissioners, AC1CIlOCBg@ ConocoPhillips Alaska, Inc hereby applies for a Permit to Drild for the onshore production we112A-26. The well will be drilled and completed using Doyon Rig #15. The planned spud date for 2A-26 is July 1st, 2008. Please fmd attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information, please contact Mike Greener at 907-263-4820. Sincerely, "v Randy Thomas Kuparuk Drilling Team Leader ~ation for Permit to Drill, Well 2A-26 Saved: 21-May-08 .~ Permit It - Kuparuk We112A-26 • ~ ,,, Application for Permit to Drill Document ~~'~ ~ ~~ px mia.@ 1Nr~ll ltpl{7q Table of Contents 1. Well Name .................................................................................................................................2 Requirements of 20 AAC 25.005 (fl ........................................................................................................................ 2 2. Location Summary ...................................................................................................................2 q f ()() ...................................................................................................................2 Re uirements o 20 AAC 25.005 c 2 2 Requirements of 20 AAC 25.050(b) ........................................................................................................................ 3. Blowout Prevention Equipment Information ........................................................................3 9 .f ()() .............................................................. Re uirements o 20 AAC 25.005 c 3 3 ..................................................... 4. Drilling Hazards Information .................................................... .............................................3 9 .f ()() ............................................................. Re uirements o 20 AAC 25.005 c 4 3 ..................................................... 5. Procedure for Conducting Formation Integrity Tests ............ .............................................3 Requirements of 20 AAC 25.005 (c)(S) ............................................................. ..................................................... 3 6. Casing and Cementing Program ............................................... .............................................4 Requirements of 20 AAC 25.005(c)(6) ............................................................. ...................................................... 4 7. Diverter System Information ..................................................... .............................................5 R' .f ()() ............................................................. Re uirements o 20 AAC 25.005 c 7 ...................................................... S S. Drilling Fluid Program ............................................................................................................5 q f ()() ............................................................. Re uirements o 20 AAC 25.005 c 8 ...................................................... 5 9. Abnormally Pressured Formation Information ....................................................................5 Requirements of 20 AAC 25.005 (c)(9) ............................................................ ...................................................... S 10. Seismic Analysis .......................................................................................................................6 Requirements of 20 AAC 25.005 (c)(10) .......................................................... ...................................................... 6 11. Seabed Condition Analysis .......:..............................................................................................6 Requirements of 20 AAC 25.005 (c)(11) .......................................................... ...................................................... 6 12. Evidence of Bonding ................................................................................................................6 Requirements of 20 AAC 25.005 (c)(12) .......................................................... ...................................................... 6 13. Proposed Drilling Program ....................................................... ..............................................6 Requirements of 20 AAC 25.005 (c)(13) .......................................................... ...................................................... 6 2A-26 APD Page 1 of 7 i Printed: 21-May-08 u cation for Permit to Drill, Well 2A-26 Saved: 21-May-08 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .......................................8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................................ 8 15. Attachments ..............................................................................................................................8 Attachment 1 Directional Plan .............................................................................................................................. 8 Attachment 2 Drilling Hazards Summary ............................................................................................................. 8 Attachment 3 Well Schematic ................................................................................................................................ 8 Attachment 4 Cement Summary ............................................................................................................................. 8 1. Well Name Requirements of 20 AAC 25.005 (~ Each well must be identified by a unique name designated by the operator and a unigare API mrmber assigned by tlxe commission under 20 AAC 25.040(6). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the Warne designated for the well by t{ae operator and to the number assigned to the ii+ell by the commission. The well for which this application is submitted will be designated as 2A-26. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in tlae application: (2) a plat ident~ing the property and the property's owners and showing (A)che coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the ~~~ational Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 776' FSL, 227' FWL, Sec 13, T11N, R8E, UM 1vAD 1927 RKB Elevation 114' AMSL Northings: S, 960,138 Eastings: 498, 621 Pad Elevation 94.3' AMSL Location at Top of Productive Interval (Ku aruk) 2,277' FNL, 1,750' FEL, Sec 24, T11N, R8E, UM Nad 1927 Measured Depth, RKB: 7,693' Northings: 5,957,145 Eastings: 501,924 Total Vertical Depth, RKB: 5,927' Total Vertical Depth, SS: 5,793' Location at Total De th 2,415' FNL, 1,588' FEL, Sec 24, T11N, R8E, UM Nad 1927 Measured De th, RKB: 8,197' Northings: 5,957,007 Eastings: 502,087 Total Vertical De th, RKB: 6,384' Total Vertical Depth, SS: 6,250' mid (D) other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(6) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, shrnving the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all swells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are Iniown or discoverable in public records, and show that each named operator has been furnished a copy of the application by certifred mail; or (B) state that the applicant is the only affected oia~ner. 2 -26 AP Page 2 of 7 `' ~ ~ ^ Printed: 21-May-OS • cation for Permit to Drill, Well 2A-26 Saved: 21-May-08 The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drilt mast be accompanied by each of the following items, except for an item already on file with the commission and ident fled in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 SAC 25.036, or 20 AAC 25.037, as appticable; Please reference BOP schematics on file for Doyon 15. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identfied in the application: (4J information on drilling hasm~ds, including (A) the maximum doiwnhole pressure that maybe encountered, criteria used to deternsine it, and maximum potential surface pressure based on a methane gradient; The closest offset well data for the Kuparuk "A" sand shows a max BHP of 3,550 psi at 6,016' TVD. Equivalent Mud Weight @ TD = 3,550 / (6,016*.052) = 11.4 ppg .~._®o, The maximum potential surface pressure (MPSP) while drilling 2A-26 is calculated using the predicted 3,550 psi reservoir pressure, a 0.11 psi/ft gas gradient, and an Kuparuk A sand top TVD of 6,041'. _... MPSP = (6,041 ftTVD)*(0.45 - 0.11 psi/ft) = 2,054 psi Note: Expected Kuparuk "C" sand pressure is 8.3 ppg at 5,927' TVD (B) data on potential gas pones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnorma]ly geo-pressured strata, lost circulation pones, and pones that have a propensiA~ for differential sticking; Please see Attachment 2 -Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and ident fled in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.03f)(fl; Drill out surface casing shoe and perform LOT test or FIT in accordance with the Kuparuk LOT /FIT procedure that ConocoPhillips Alaska has on file with the Commission. 2A-26 APD Page 3 of 7 y Printed: 21-May-08 I~ ~ation for Permit to Drill, Well 2A-26 Saved: 21-May-08 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c) (6) An applicatioia for a Permit to Drill nsust be accompanied by each of the follolcing items, except for an item already on file with the commission and identified in the application: (6J a complete proposed casing m7d cementing program as required by 20 ABC 25.030, and a description of any slotted liner, pre perforated liner, or screen to be installed; (if LOT on "C" sand shows that "smear" proved to be unsuccessful in strengthening the wellbore) (O tion 1) Casin and Cementin Pro ram ( to set the Ku aruk "A" Sand) Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD in (in) Ib/ft) Grade Conn. (ft) ft ft Cement Pro ram Driven 16 24 62.5 H-40 Welded 80' Surf 110' / 110' Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 BTC 3,176' Surf 3,176' / 2,800' 590 sx ASLite Lead, 200 sx Dee CRETE Tail Cement Top planned @ 6,500' MD / 7-5/8 9-7/8" 29.7 L-80 Hydril 7,754' Surf 7,754' / 5,982' 5,025' ND. Cemented w/ 563 370 sx GasBLOK Class "G" Cement Top planned @ 7,241' MD / 4-1/2 6-3/4 12.6 L-80 IBTM 643' 7,554' / 5,801' 8,197' / 6,384' 5,535' ND. Cemented w/ 120 sx GasBLOK w/ Class "G" (if LOT on "C" sand shows th `smear' is successful in strengthening the wellbore) (O tion 2 Casin an d Cemen tin Pro ram for Drill in of Intermediate Strin Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD in (in Ib/ft Grade Conn. ft ft ft Cement Pro ram Driven 16 24 62.5 H-40 Welded 80' Surf 110' / 110' Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 BTC 3,180' Surf 3,180' / 2,800' 590 sx ASLite Lead, 200 sx Dee CRETE Tail Cement Top planned @ 6,800 ' MD / 7-5/8 9-7/8" 29.7 L-80 Hydril 8,197' Surf 8,197'/ 6,384' S,225'ND. Cemented w/ 563 410 sx GasBLOK Class "G" A-26 PD Page 4 of 7 Printed: 21-May-08 a cation for Permit to Drill, Well 2A-26 Saved: 21-May-08 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) Aga application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h) (2); Please reference diverter schematic on file for Doyon 15. 8. Drilling Fluid Program Requirements of 20 AAC 2S.OOS(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file smith the commission and ident~ed in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done using mud systems having the following properties: Sur ace 110' -1,600' 1,600' - 3,180' Density (p 8.8 - 9.2 9.2 - 9.6 Funnel Viscosity (seconds) 150 - 250 200 - 300 Yield Point (cP) 50 - 70 30 - 50 Plastic Viscosity (lb/100 s~ 30 - 55 15 - 20 pH 9.0 - 9.5 9.0 - 9.5 API Filtrate(cc) NC - 8.0 8.0 Chlorides (m /l) <1000 <1000 Intermediate (Cs Drl O tion 3,180' - 7, 754' 7, 754' - 8,370' Density (ppg) 9.2 -10.0 11.5 Yield Point (cP) 18 -24 16 - 20 Plastic Viscosity (lb/100 s~ 12 - 18 29 - 32 pH 9-10.0 9.5-10.5 API filtrate <6 <6 MBT <18 <15 Solids (%) <6 <6 Production (To Set "A"Sand) 7,754'-8,197' Density (p 11.5 Yield Point (cP 16 - 22 H 9.5 - 10 API filtrate 4 - 6 Solids (%) 6 - 7 Diagram of Doyon 15 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 2S. 005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, exceptfor an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out floe depths of predicted abnormally geo pressured strata as required by 20 AAC 25.0330; N/A -Application is not for an exploratory or stratigraphic test well. ORIGINAL -26 A D Page 5 of 7 Printed: 21-May-08 cation for Permit to Drill, Well 2A-26 Saved: 21-May-08 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file witlx the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 ~1AC 25.061(a); N/A -Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) ~In application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in tlae application: (11) for a well drilled from an offshore platform, mobile bottom founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as regutred by 20 AAC 25.061(b); N/A -Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the follox~ing items, ea:cept for an item ab~eady on file with the commission and identified in the application: (12) evidence shoH~ing that the requirements of 20 AAC 2.025 {Bonding}have been n2et; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompm~ied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Doyon 15 on 2A-26 Conductor. 2. NU and function test diverter system and prepare spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. 4. Spud and directionally drill 13-1/2" hole to 10-3/4" surface casing point (3,176' MD/ 2,800' TVD) according to directional plan. Run MWD /LWD logging tools in drill string as required for directional monitoring and formation data gathering. 5. Run and cement 10-3/4" 45.5# L-80 BTC casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Perform top job if required to bring cement to surface. 6. Nipple down diverter, remove warning signage, and install wellhead and test to 5000 psi. Nipple up BOPE and test to 3,500 psi. Record results. 7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results. 8. Drill out cement and 20' minimum to 50' maximum of new hole. Perform LOT. 9. Directionally dri119-7/8" hole to 7,641' MD / 5,880' TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. ~ 5 ~$~ r ~~~ ~~~~~~~ 10. POOH with DP and rack back. Run 7-5/8" 29.7# L-80 Hydri1563 casing fitted with an EZCase bit to 7,641' MD / s,88o' TVD. ~ '~v`\ s~ ~~~ p E ~ ~ ~^-c~~ ~ ~~ It ~ 11. Drill ahead rotating casing between 80 to 100 rpm with 250 to 350 gpm. Stop drilling at +/- 7,754' MD / 5,982' TVD. 12. Perform LOT to see if so called "smear" effect has increased wellbore strength (we need to strengthen wellbore to a minimum of 12.5 ppg but no higher than surface LOT). Based on results we will do either: 2A-2 APD Page 6 of 7 Printed: 21-May-OS a. Failed "Smear Effect" LOT Test cation for Permit to Drill, Well 2A-28 Saved: 21-May-08 1) Set 7-5/8" casing at +/- 7,754' MD / 5,982' TVD. 2) Pump cement and displace with mud, land casing hanger and bump plug. 3) Change out rams in BOP to accommodate 4" DP and test. 4) PU 4-3/4" LWD/MWD drilling assembly and 6-3/4" bit and clean out to shoe. Shut in BOP and test casing to 3,000 psi. Record results. Dri1120' minimum to 50' maximum of new hole. Perform LOT. 5) Directionally dri116-3/4" hole to 8,197' MD / 6,384' TVD. Run MWD/LWD logging tools in drill string. 6) POOH and lay down BHA. 7) Run 4-1/2" liner completion with +/- 200' overlap into intermediate casing and cement same. 8) Run 3-1/2" tubing with GLM's and land 3-1/2" completion tubing string in the seal bore in the 4-1/2" liner top and pressure test to 3000 psi. Record results. 9) Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 10) Pressure up to shear out valve in lowest GLM and freeze protect outer annulus with diesel to below the permafrost. Set BPV. Release rig. 11) Clean location and RDMO. 12) MIRU coiled tubing. Displace mud from well with brine. 13) RU E-Line, perforate well. Flow test well. 14) RU Dowell, frac well. 15) RD Dowell, secure well, handover to production. b. Successful "Smear Effect" LOT Test 1) Continue to drill with 7-5/8" casing to final well TD of 8,197' MD / 6,384' TVD. 2) Pump cement and displace with mud, land casing hanger and bump plug. 3) Run 3-1/2" tubing with GLMs and packer. Set packer at 7,640' MD / 5,880' TVD. Pressure test to 3000 psi. Record results. 4) Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 5) Pressure up to shear out valve in lowest GLM and freeze protect outer annulus with diesel to below the permafrost. Set BPV. Release rig. 6) Clean location and RDMO. 7) MIRU coiled tubing. Displace mud from well with brine. ~ ~Ll _ 8 RU E-Line, g ro well to tie in with MWD log, perforate well. Flow test well. N ~Q ~t 9) RU Dowell, frac well. -~J ~ 10) RD Dowell, secure well, handover to production. a~ Ct~' G~,~- ' ~,<~ ~~ ~ °~ ~6~ ~ 2A-2 PD Page 7 of 7 Panted: 21-May-08 ORIGINAL cation for Permit to Drill, Well 2A-26 Saved: 21-May-08 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on frle with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator i~atends to reguest authorisation under ZO AAC 25.080 for an annular disposal operation !n the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska does intend to request authorization for the use of this well for annular disposal operations at a later date provided the well meets the regulatory requirements. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary -26 D Page 8 of 7 Printed: 21-May-08 r ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2A Pad Plan: 2A-26 -Slot 2A-26* 2A-26 Plan: 2A-26 (wp05) Standard Proposal Report O6 May, 2008 HAL.LIBUR Sperry Drilling Services ORIGINAL Sperry Drilling 5®rvices 0 500- 1000 1500 2000 ~ 2500 0 0 0 L 3000 a m 3500 N 3 ~ 4000 5500 6500 0° 500 10° 10p0 zy 1~p0 --Base Permafrost - - - - WELL DETAILS: Plan: 2A-26 NAD 1927 (NADCON CONUS) Alaska Zone 04 Ground Level: 94.30 +N/-S +E/-W Northing Fasting Latittude I-ongitude Slot 0 00 0.00 5960197.54 498621.01 70° 18' 8.951 N 150° 0' 40.211 W 2A-26* FORMATION TOP DETAILS NDPath TVDssPath MDPath Formation 1492.30 1358.00 1556.25 Base Permafrost 2786.30 2652.00 3156.53 Base West Sak 5840.30 5706.00 7596.92 K1 5927.30 5793.00 7692.91 Kup C4 5968.30 5834.00 7738.15 Kup B 6041.30 5907.00 7818.70 A4 6066.30 5932.00 7846.28 A3 v ~,~~ Surface Csg @ 3176' MD, 2800' ND: 184' FNL, 1072' FWL -Sec24-T11 N-R08E ~5~~ OHO ~~ - - - - - - - - - - - - - - - - - - - - - - ~p0 Base West Sak ' `5 10 3/4" ~. CASING DETAILS TVD TVDSS MD Size Name 2800.00 2665.70 3175.87 10-3/4 l0 3/4" 5880.00 5745.70 7640.72 7-5/8 7 5/8" 63sa 29 6249.99 8197.15 4-1/2 4 I/2" ~ Int. Csg @ 7641' MD, 5880' ND: 2262' FNL, 1767' FEL -Sec24-T11N-ROSE ~~O i O~ ' / ~O ~O~ ~' Top Kup_C @ 7693' MD, 5927' ND: 2277' FNL, 1750' FEL -Sec24-T11N-ROSE ~~ O ~ '~ .~0~ i Np ~~ Top Kup_A4 @ 7819' MD, 6041' ND: 2311' FNL, 1710' FEL -Sect ,1 75/8" 1~~ -___ ~'va---------------- ---------- -- ----______="===2A-26(wp05)T'r-==' A3 19~ BHL @ 8197' MD 6384' ND: 2415' FNL, 1588' FEL -Sec24-T1 1000 -500 0 500 1000 1500 2000 2500 41/2"-- ~'-------------- 2A-26 (wp05) 3000 3500 4000 4500 5000 5500 6000 6500 7000 750n annn usnn Vertical Section at 132.62° (1000 ft/in) ConocoPhillips A 1N Project: Kuparuk River Unit Site: Kuparuk 2A Pad Well: PIan:2A-26 Wel Ibore: 2A-26 Design: 2A-26 (wp05) r - - - - - - SHL: 776' FSL, 22T FWL - Sec13-T11 N-R08 Hss,~~slQUr~TOOv Sp®rry Drilllnp Swwicrr tooo 750 500 250 -0 -250 -500 -750 looo ~c -1250 0 + -1500 C -1750 -2000 -2250 -2500 -2750 -3000 SI-IL: 776' FSL, 227' FWL- Sec13-T11N-ROSE Project: Kuparuk River Unit Site: Kuparuk 2A Pad Well: PIan:2A-26 Wellbore: 2A-26 Plan: 2A-26 (wp05) 2t\ '-6 (wp05) llD-Polygmi 2A-26 (wp05) (ieo-Polygon T M Azimuths to True North Magnetic North: 22.68° Magnetic Field Strength: 57614.3snT Dip Angle: 80.77° Date: 3/13/2008 Model: BGGM2007 WE1J. DETAll.S: Plan: 2A-26 Ground Level: 94.30 +N/-S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 5960197.54 498621.01 70° 18' 8.951 N 150° 0' 40.21 I W 2A-26• REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan: 2A-26 -Slat 2A-26', True North Vertical (TVD) Reference: RK8 @ 134.30ft (015 (40+g4.3)) Measuretl Depfh Reference: RKB @ 734.30f1 (075 (40+g4.3)) Calculation Method: Minimum Curvature CASING DETAILS TVD TVDSS MD Size Nance 2800.00 2665.70 3175.87 10-3/4 10 3/4" 5880.00 5745.70 7640.72 7-5/8 7 5/8" 6384.29 6249.99 8197.15 4-I/2 4 U2" o~~ o~w ,1~4 `~~ ¢owFi oti'C ~ ~ 'S`\? 5~ y~,c° `ryp• ow4~ 4 ~; ~ `^~~ `^`'g o w G'Lat ~~V ~yti ~~` c,~ b~j, 1Y` ~y' 4Qy titi rytiA ~~ 5~~ J~ ~' tip' ~ ~ 5 5q ~ ~5 ;C~ ~O O,o~p q,~P 1~ 1~q~ 9~ t*~ LJS~~ G~i v~1 ~,y4 a ,So4. ,Y~4' 4~q ,So4 ~~yG ,~K ~~ i h1 4 1 /2" ~ ~3Cn ryb ,yP III 111111 Ii ii iiiii~~~~~~ I I ~ i 1000 -750 -500 -250 -0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 4750 5000 5250 5500 5750 6~ 6750 West(-)/East(+) (750 ft/in) C011000P~'t1~~Ip5 Alaska • ~'.' Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2A Pad Well: PIan:2A-26 Wellbore: 2A-26 Design: 2A-26 (wp05) r- Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Local Co-ordinate Reference: Well Plan: 2A-26 -Slot 2A-26* ND Reference: RKB @ 134.30ft (D15 (40+94.3)) MD Reference: RKB @ 134.30ft (D15 (40+94.3)) North Reference: True Survey Calculation Method: Minimum Curvature Site Kuparuk 2A Pad Site Position: From: Map Position Uncertainty: 0.00 ft Northing: Easting: Slot Radius: 5,960,138.24ft Latitude: 498,621.OOft Longitude: 0" Grid Convergence: 70° 18' 8.367 N 150° 0' 40.211 W -0.01 ° Well Plarr 2A-26 -Slot 2A-26` Well Position +N/-S 0.00 ft Northing: 5,960,197.54 ft ~' Latitude: 70° 18' 8.951 N +E/-W 0.00 ft Easting: 498,621.01 ft Longitude: 150° 0' 40.211 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 94.30ft Wellbore - 2A-26 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2007 3/13/2008 22.68 80.77 57,614 Design 2A-26 (wp05) Audit Notes: Version: Phase: PLAN Tie On Depth: 40.00 Vertical Section: Depth From (ND) +N/-S +E/-W Direction ° (ft) lft) (ft) ( ) 40.00 _ 0.00 0.00 132.62 Plan Sections Measured Vertical ND Depth Inclination Azimuth Depth System (ft) (°) (°) (ft) ft 40.00 0.00 0.00 40.00 -94.30 300.00 0.00 0.00 300.00 165.70 701.31 8.03 140.00 700.00 565.70 1,565.52 33.95 140.00 1,500.00 1,365.70 2,565.52 33.95 140.00 2,329.50 2,195.20 3,336.61 48.06 130.36 2,910.53 2,776.23 6,989.64 48.06 130.36 5,352.25 5,217.95 7,566.03 25.00 130.36 5,812.30 5,678.00 7,662.02 25.00 130.36 5,899.30 5,765.00 8,197.16 25.00 130.36 6,384.30 6,250.00 +N/-S (ft) 0.00 0.00 -21.50 -256.61 -684.45 -1,037.24 -2,796.82 -3,017.49 -3,043.76 -3,190.22 Dogleg Build Turn +El-W Rate Rate Rate Tool Face (ft) (°/100ft) (°/100ft) (°1100ft) (°) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 18.04 2.00 2.00 0.00 140.00 215.32 3.00 3.00 0.00 0.00 574.32 0.00 0.00 0.00 0.00 933.42 2.00 1.83 -1.25 -27.93 3,003.80 0.00 0.00 0.00 0.00 3,263.46 4.00 -4.00 0.00 -180.00 3,294.37 0.00 0.00 0.00 0.00 3,466.70 0.00 0.00 0.00 0.00 5/6/2008 6:45:01PM Page 2 COMPASS 2003.16 Build 42F ~RI~I~AL Halliburton -Sperry Standard Proposal Report • ::.~:.1 , ~:: .:~:. Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2A Pad Well: PIan:2A-26 Wellbore: 2A-26 Design: 2A-26 (wp05) Planned Survey Halliburton -Sperry Standard Proposal Report Local Co-ordinate Reference: Well Plan: 2A-26 -Slot 2A-26` TVD Reference: RKB @ 134.30ft (D15 (40+94.3)) MD Reference: RKB @ 134.30ft (D15 (40+94.3)) - North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) -94.30 40.00 0.00 0.00 40.00 -94.30 0.00 0.00 5,960,197.54 498,621.01 0.00 00 00 0 01 0 40 40 01 -94.29 0.00 0.00 5,960,197.54 498,621.01 0.00 . . . . SHL: 776' FSL, 227' FWL - Sec13-T11N-R08E 100.00 0.00 0.00 100.00 -34.30 0.00 0.00 200.00 0.00 0.00 200.00 65.70 0.00 0.00 300.00 0.00 0.00 300.00 165.70 0.00 0.00 400.00 2.00 _ 140.00 399.98 265.68 -1.34 1.12 500.00 4.00 140.00 499.84 365.54 -5.35 4.49 600.00 6.00 140.00 599.45 465.15 -12.02 10.09 700.00 8.00 140.00 698.70 564.40 -21.36 17.92 701.31 8.03 140.00 700.00 565.70 -21.50 18.04 800.00 10.99 140.00 797.32 663.02 -33.98 28.51 900.00 13.99 140.00 894.95 760.65 -50.54 42.41 1,000.00 16.99 140.00 991.30 857.00 -71.00 59.57 1,100.00 19.99 140.00 1,086.13 951.83 -95.28 79.95 1,200.00 22.99 140.00 1,179.17 1,044.87 -123.34 103.49 1,300.00 25.99 140.00 1,270.17 1,135.87 -155.09 130.13 1,400.00 28.99 140.00 1,358.87 1,224.57 -190.44 159.80 1,500.00 31.99 140.00 1,445.03 1,310.73 -229.30 192.41 1,556.25 33.67 140.00 1,492.30 1,358.00 -252.66 212.01 Base Perm afrost 1,565.52 33.95 140.00 1,500.00 1,365.70 -256.61 215.32 1,600.00 33.95 140.00 1,528.60 1,394.30 -271.36 227.70 1,700.00 33.95 140.00 1,611.55 1,477.25 -314.15 263.60 1,800.00 33.95 140.00 1,694.50 1,560.20 -356.93 299.50 1,900.00 33.95 140.00 1,777.45 1,643.15 -399.72 335.40 2,000.00 33.95 140.00 1,860.40 1,726.10 -442.50 371.30 2,100.00 33.95 140.00 1,943.35 1,809.05 -485.28 407.20 2,200.00 33.95 140.00 2,026.30 1,892.00 -528.07 443.10 2,300.00 33.95 140.00 2,109.25 1,974.95 -570.85 479.00 2,400.00 33.95 140.00 2,192.20 2,057.90 -613.64 514.90 2,500.00 33.95 140.00 2,275.15 2,140.85 -656.42 550.80 2,565.52 33.95 140.00 2,329.50 2,195.20 -684.45 574.32 2,600.00 34.56 139.43 2,358.00 2,223.70 -699.26 586.87 2,700.00 36.35 137.87 2,439.45 2,305.15 -742.79 625.20 2,800.00 38.15 136.45 2,519.05 2,384.75 -787.16 666.37 2,900.00 39.97 135.13 2,596.70 2,462.40 -832.31 710.32 3,000.00 41.80 133.91 2,672.30 2,538.00 -878.19 756.99 3,100.00 43.65 132.77 2,745.75 2,611.45 -924.74 806.35 3,156.53 44.70 132.16 2,786.30 2,652.00 -951.34 835.41 Base West Sak 3,175.86 45.06 131.96 2,800.00 2,665.70 -960.47 845.53 Surface Csg @ 3176' MD, 2800' TVD: 184' FNL, 1072' FWL - Sec2 4-T11 N-R08E 3,175.87 45.06 131.96 2,800.00 2,665.70 -960.48 845.54 10 314" - Vert Section 0.00 0.00 ,960,197.54 498,621.01 0.00 0.00 5,960,197.54 498,621.01 0.00 0.00 5,960,197.54 .498,621.01 0.00 0.00 5,960,196.21 498,622.13 2.00 1.73 5,960,192.20 498,625.49 2.00 6.92 5,960,185.52 498,631.09 2.00 15.56 5,960,176.19 498,638.93 2.00 27.65 5,960,176.05 498,639.04 2.00 27.83 5,960,163.56 498,649.52 3.00 43.99 5,960,147.00 498,663.41 3.00 65.43 5,960,126.54 498,680.56 3.00 91.91 5,960,102.26 498,700.94 3.00 123.35 5,960,074.20 498,724.47 3.00 .159.67 5,960,042.45 498,751.10 3.00 200.78 5,960,007.09 498,780.76 3.00 246.54 5,959,968.23 498,813.35 3.00 296.85 5,959,944.87 498,832.95 3.00 327.10 5,959,940.92 498,836.27 3.00 332.21 5,959,926.17 498,848.64 0.00 351.31 5,959,883.38 498,884.53 0.00 406.70 5,959,840.59 498,920.42 0.00 462.08 5,959,797.81 498,956.31 0.00 517.47 5,959,755.02 498,992.19 0.00 572.86 5,959,712.23 499,028.08 0.00 628.25 5,959,669.45 499,063.97 0.00 683.64 5,959,626.66 499,099.86 0.00 739.02 5,959,583.88 499,135.75 0.00 794.41 5,959,541.09 499,171.64 0.00 849.80 5,959,513.06 499,195.15 0.00 886.09 5,959,498.25 499,207.70 2.00 905.35 5,959,454.72 499,246.01 2.00 963.03 5,959,410.34 499,287.17 2.00 1,023.37 5,959,365.19 499,331.10. 2.00 1,086.28 5,959,319.30 499,377.77 2.00 1,151.70 5,959,272.74 499,427.11 2.00 1,219.54 5,959,246.15 499,456.16 2.00 1,258.93 5,959,237.01 499,466.28 2.00 1,272.57 5,959,237.01 499,466.29 2.00 5 1,272.57 5/8/2008 6:45:01PM Page 3 COMPASS 2003.16 Build 42F ORIGINAL • Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2A Pad Well: PIan:2A-26 Wellbore: 2A-26 Design: 2A-26 (wp05) Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton -Sperry Standard Proposal Report Well Plan: 2A-26 -Slot 2A-26' RKB @ 134.30ft (D15 (40+94.3)) RKB @ 134.30ft (D15 (40+94.3)) True Minimum Curvature Planned Survey Measured Depth Incl Vertical ination Azimuth Depth NDss +Nl-S +E/-W Map Northing Map Easting DLS Vert Section (ft) (~) (~) (ft) ft (ft) (ft) (ft) (ft) 2 ,682.68 200.00 3 45.51 131.71 2,816.98 2,682.68 -971.91 858.31 5,959,225.57 499,479.06 2.00 1,289.72 , 300.00 3 47.37 130.71 2,885.89 2,751.59 -1,019.64 912.83 5,959,177.84 499,533.56 2.00 1,362.15 , 336.61 3 48.06 130.36 2,910.53 2,776.23 -1,037.24 933.42 5,959,160.23 499,554.14 2.00 1,389.22 , 400.00 3 48.06 130.36 2,952.90 2,818.60 -1,067.78 969.34 5,959,129.70 499,590.06 0.00 1,436.33 , 500.00 3 48.06 130.36 3,019.74 2,885.44 -1,115.94 1,026.02 5,959,081.52 499,646.72 0.00 1,510.65 , 600.00 3 48.06 130.36 3,086.58 2,952.28 -1,164.11 1,082.69 5,959,033.35 499,703.38 0.00 1,584.97 , 700.00 3 48.06 130.36 3,153.42 3,019.12 -1,212.28. 1,139.37 5,958,985.18 499,760.04 0.00 1,659.30 , 800.00 3 48.06 130.36 3,220.26 3,085.96 -1,260.45 1,196.05 5,958,937.00 499,816.71 0.00 1,733.62 , 900.00 3 48.06 130.36 3,287.10 3,152.80 -1,308.61 1,252.72 5,958,888.83 499,873.37 0.00 1,807.94 , 4 000.00 48.06 130.36 3,353.94 3,219.64 -1,356.78 1,309.40 5,958,840.66 499,930.03 0.00 1,882.26 , 100.00 4 48.06 130.36 3,420.78 3,286.48 -1,404.95 1,366.07 5,958,792.48 499,986.69 0.00 1,956.58 , 200.00 4 48.06 130.36 3,487.63 3,353.33 -1,453.12 1,422.75 5,958,744.31 500,043.35 0.00 2,030.90 , 300.00 4 48.06 130.36 3,554.47 3,420.17 -1,501.28 1,479.43 5,958,696.14 500,100.01 0.00 2,105.22 , 400.00 4 48.06 130.36 3,621.31 3,487.01 -1,549.45 1,536.10 5,958,647.97 500,156.67 0.00 2,179.54 , 500.00 4 48.06 130.36 3,688.15 3,553.85 -1,597.62 1,592.78 5,958,599.79 500,213.33 0.00 2,253.87 , 600.00 4 48.06 130.36 3,754.99 3,620.69 -1,645.79 1,649.45 5,958,551.62 500,270.00 0.00 2,328.19 , 700.00 4 48.06 130.36 3,821.83 3,687.53 -1,693.95 1,706.13 5,958,503.45 500,326.66 0.00 2,402.51 , 4 800.00 48.06 130.36 3,888.67 3,754.37 -1,742.12 1,762.80 5,958,455.27 500,383.32 0.00 2,476.83 , 900.00 4 48.06 130.36 3,955.51 3,821.21 -1,790.29 1,819.48 5,958,407.10 500,439.98 0.00 2,551.15 , 000.00 5 48.06 130.36 4,022.35 3,888.05 -1,838.46 1,876.16 5,958,358.93 500,496.64 0.00 2,625.47 , 100.00 5 48.06 130.36 4,089.20 3,954.90 -1,886.62 1,932.83 5,958,310.75 500,553.30 0.00 2,699.79 , 200.00 5 48.06 130.36 4,156.04 4,021.74 -1,934.79 1,989.51 5,958,262.58 500,609.96 0.00 2,774.11 , 300.00 5 48.06 130.36 4,222.88 4,088.58 -1,982.96 2,046.18 5,958,214.41 500,666.63 0.00 2,848.44 , 400.00 5 48.06 130.36 4,289.72 4,155.42 -2,031.13 2,102:86 5,958,166.23 500,723.29 0.00 2,922.76 , 500.00 5 48.06 130.36 4,356.56 4,222.26 -2,079.29 2,159.54 5,958,118.06 500,779.95 0.00 2,997.08 , 600.00 5 48.06 130.36 4,423.40 4,289.10 -2,127.46 2,216.21 5,958,069.89 500,836.61 0.00 3,071.40 , 700.00 5 48.06 130.36 4,490.24 4,355.94 -2,175.63 2,272.89 5,958,021.72 500,893.27 0.00 3,145.72 , 800.00 5 48.06 130.36 4,557.08 4,422.78 -2,223.80 2,329.56 5,957,973.54 500,949.93 0.00 3,220.04 , 900.00 5 48.06 130.36 4,623.93 4,489.63 -2,271.96 2,386.24 5,957,925.37 501,006.59 0.00 3,294.36 , 000.00 6 48.06 130.36 4,690.77 4,556.47 -2,320.13 2,442.91 5,957,877.20 501,063.25 0.00 3,368.68 , 100.00 6 48.06 130.36 4,757.61 4,623.31 -2,368.30 2,499.59 5,957,829.02 501,119.92 0.00 3,443.01 , 200.00 6 48.06 130.36 4,824.45 4,690.15 -2,416.47 2,556.27 5,957,780.85 501,176.58 0.00 3,517.33 , 300.00 6 48.06 130.36 4,891.29 4,756.99 -2,464.63 2,612.94 5,957,732.68 501,233.24 0.00 3,591:65 , 400.00 6 48.06 130.36 4,958.13 4,823.83 -2,512.80 2,669.62 5,957,684.50 501,289.90 0.00 3,665.97 , 500.00 6 48.06 130.36 5,024.97 4,890.67 -2,560.97 2,726.29 5,957,636.33 501,346.56 0.00 3,740.29 , 00 600 6 48.06 130.36 5,091.81 4,957.51 -2,609.14 2,782.97 5,957,588.16 501,403.22 0.00 3,814.61 . , 700.00 6 48.06 130.36 5,158.65 5,024.35 -2,657.30 2,839.65 5,957,539.98 501,459.88 0.00 3,888.93 , 00 800 6 48.06 130.36 5,225.50 5,091.20 -2,705.47 2,896.32 5,957,491.81 501,516.55 0.00 3,963.25 . , 900.00 6 48.06 130.36 5,292.34 5,158.04 -2,753.64 2,953.00 5,957,443.64 501,573.21 0.00 4,037.57 , 989.64 6 48.06 130.36 5,352.25 5,217.95 -2,796.82 3,003.80 5,957,400.46 501,624.00 0.00 4,104.20 , 000.00 7 47.64 130.36 5,359.21 5,224.91 -2,801.79 3,009.65 5,957,395.48 501,629.85 3.99 4,111.87 , 100.00 7 43.64 130.36 5,429.11 5,294.81 -2,848.08 3,064.12 5,957,349.18 501,684.30 4.00 4,183.30 , 200 00 7 39.64 130.36 5,503.82 5,369.52 -2,891.10 3,114.74 5,957,306.16 501,734.91 4.00 4,249.68 . , 300.00 7 35.64 130.36 5,582.99 5,448.69 -2,930.64 3,161.27 5,957,266.61 501,781.43 4.00 4,310.69 , 7,400.00 31.64 130.36 5,666.23 5,531.93 -2,966.51 3,203.47 5,957,230.74 501,823.62 4.00. 4,366.03 5/6/2008 6:45:O1PM Page 4 COMPASS 2003.16 Build 42F ~~~ ~~ • :. :r- ~ e,.,: Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 ND Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 2A Pad North Reference: Well: Plan: 2A-26 Survey Calculation Method: Wellbore: 2A-26 Design: 2A-26 (wp05) Halliburton -Sperry Standard Proposal Report Well Plan: 2A-26 -Slot 2A-26` RKB @ 134.30ft (D15 (40+94.3)) RKB @ 134.30ft (D15 (40+94.3)) True Minimum Curvature Planned Survey Measured Vertical Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing (ft) (°) (°) (ft} ft (ft) (ft) (ft) 7,500.00 27.64 130.36 5,753.13 5,618.83 -2,998.53 3,241.15 5,957,198.71 7,566.03 25.00 130.36 5,812.30 5,678.00 -3,017.49 3,263.46 5,957,179.76 7,596.92 25.00 130.36 5,840.30 5,706.00 -3,025.95 3,273.41 5,957,171.30 K1 7,600.00 25.00 130.36 5,843.09 5,708.79 -3,026.79 3,274.40 5,957,170.46 7,640.72 25.00 130.36 5,880.00 5,745.70 -3,037.93 3,287.51 5,957,159.31 Int. Csg @ 7641' MD, 5880' TVD: 2262' FN L, 1767' FE L -Sec24-T1 1 N-R08E - 7 518" 7,662.02 25.00 130.36 5,899.30 5,765.00 -3,043.76 3,294.37 5,957,153.48 2A-26 (wp05) T1 7,692.91 25.00 130.36 5,927.30 5,793.00 -3,052.22 3,304.32 5,957,145.03 C @ 7693 Top Kup ' MD, 5927' TVD: 2277 ' FNL, 1750 ' FEL -Sec24-T11 N-R08E - Kup C4 _ 7,700.00 25.00 130.36 5,933.72 5,799.42 -3,054.16 3,306.60 5,957,143.09 7,738.15 25.00 130.36 5,968.30 5,834.00 -3,064.60 3,318.89 5,957,132.64 Kup B 7,800.00 25.00 130.36 6,024.35 5,890.05 -3,081.53 3,338.80 5,957,115.71 7,818.69 25.00 130.36 6,041.29 5,906.99 -3,086.64 3,344.82 5,957,110.60 A4 @ 781 Top Kup 9' MD, 6041' TVD: 231 1' FNL, 171 0' FEL -Sec 24-T11 N-R08E _ 7,818.70 25.00 130.36 6,041.30 5,907.00 -3,086.64 3,344.83 5,957,110.60 A4 7,846.28 25.00 130.36 6,066.30 5,932.00 -3,094.19 3,353.71 5,957,103.05 A3 7,900.00 25.00 130.36 6,114.98 5,980.68 -3,108.89 3,371.01 5,957,088.34 8,000.00 25.00 130.36 6,205.61 6,071.31 -3,136.26 3,403.21 5,957,060.97 8,100.00 25.00 130.36 6,296.25 6,161.95 -3,163.63 3,435.41 5,957,033.60 8,197.15 25.00 130.36 6,384.29 6,249.99 -3,190.22 3,466.70 5,957,007.01 BHL @ 8197' MD, 6384' TVD: 2415' FNL, 1588' FEL - Sec24-T11 N-R08E - 4 1/2" . 8,197.16 25.00 130.36 6,384.30 _.6,250.00 -3,190.22 3,466.70 5,957,007.01 Map Fasting DLS Vert Section (ft) 5,618.83 501,861.29 4.00 4,415.44 501,883.59 4.00 4,444.69 501,893.53 0.00 4,457.74 501,894.53 0.00 4,459.04 501,907.64 0.00 4,476.24 501,914.49 0.00 4,485.23 501,924.44 0.00 4,498.28 501,926.72 0.00 4,501.27 501,939.00 0.00 4,517.38 501,958.91 0.00 4,543.50 501,964.93 0.00 4,551.39 501,964.93 0.00 4,551.39 501,973.82 0.00 4,563.04 501,991.11 0.00 4,585.73 502,023.30 0.00 4,627.96 502,055.50 0.00 4,670.18 502,086.78 0.00 4,711.21 502,086.78 0.00 4,711.21 5/6/2008 6:45:01PM Page 5 COMPASS 2003.16 Build 42F ORIGINAL Halliburton -Sperry Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan: 2A-26 -Slot 2A-26" Company: ConocoPhillips (Alaska) Inc. -Kup2 ND Reference: RKB @ 134.30ft (D15 (40+94.3)) Project: Kuparuk River Unit MD Reference: RKB @ 134.30ft (D15 (40+94.3)) Site: Kuparuk 2A Pad North Reference: True Well: Plan: 2A-26 Survey Calculatio n Method: Minimum Curvature Wellbore: 2A-26 Design: 2A-26 (wp05) Targets Target Narne ~ - hiLhniss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ftl (ft) Ift) 2A-26 (wp05) T1 0.00 0.00 5,899.30 -3,043.76 3,294.37 5,957,153.48 501,914.49 - plan hits target - Point 2A-26 (wp05) DD-Polygon 0.00 0.00 5,899.30 -3,078.74 3,463.40 5,957,118.48 502,083.49 - plan misses by 160.30ft at 7726.02ft MD (5957.31 TVD, -3061.28 N, 3314.98 E) - Polygon Point 1 5,899.30 -3,069.36 3,416.76 5,957,127.86 502,036.86 Point 2 5,899.30 -3,058.32 3,414.14 5,957,138.90 502,034.24 Point 3 5,899.30 -3,048.66 3,410.16 5,957,148.56 502,030.26 Point4 5,899.30 -3,033.86 3,402.56 5,957,163.36 502,022.67 Point 5 5,899.30 -3,019.44 3,392.88 5,957,177.78 502,012.99 Point6 5,899.30 -3,008.16 3,383.03 5,957,189.06 502,003.15 Point 7 5,899.30 -2,995.80 3,369.03 5,957,201.43 501,989.15 Point 8 5,899.30 -2,986.12 3,355.05 5,957,211.11 501,975.17 Point 9 5,899.30 -2,975.76 3,334.29 5,957,221.47 501,954.42 Point 10 5,899.30 -2,967.37 3,304.15 5,957,229.86 501,924.28 Point 11 5,899.30 -2,966.10 3,275.24 5,957,231.14 501,895.37 Point 12 5,899.30 -2,970.55 3,251.18 5,957,226.69 501,871.32 Point 13 5,899.30 -2,978.68 3,233.70 5,957,218.57 501,853.84 Point 14 5,899.30 -2,992.40 3,218.40 5,957,204.85 501,838.53 Point 15 5,899.30 -3,010.61 3,207.71 5,957,186.65 501,827.84 Point 16 5,899.30 -3,033.21 3,201.80 5,957,164.05 501,821.93 Point 17 5,899.30 -3,054.20 3,200.77 5,957,143.06 501,820.89 Point 18 5,899.30 -3,080.76 3,205.75 5,957,116.50 501,825.87 Point 19 5,899.30 -3,087.38 3,212.99 5,957,109.88 501,833.11 Point 20 5,899.30 -3,089.37 3,221.49 5,957,107.89. 501,841.61 Point 21 5,899.30 -3,089.98 3,248.90 5,957,107.28 501,869.01 Point 22 5,899.30 -3,089.96 3,354.42 5,957,107.28 501,974.52 Point 23 5,899.30 -3,089.25 3,392.90 5,957,107.98 502,013.00 Point 24 5,899.30 -3,087.14 3,405.51 5,957,110.09 502,025.61 Point 25 5,899.30 -3,082.67 3,413.10 5,957,114.56 502,033.20 Point 26 5,899.30 -3,075.48 3,416.59 5,957,121.74 502,036.69 Point 27 5,899.30 -3,069.36 3,416.76 5,957,127.86 502,036.86 2A-26 (wp05) Geo-Polygon 0.00 0.00 5,899.30 -3,078.74 3,463.40 5,957,11.8.48 502,083.49 - plan misses by 160.30ft at 7726.02ft MD (5957.31 TVD, -3061.28 N, 3314.98 E) - Polygon Point 1 5,899.30 -3,078.73 3,463.39 5,957,118.48 502,083.49 Point 2 5,899.30 -3,052.73 3,461.39 5,957,144.48 502,081.50 Point 3 5,899.30 -3,029.43 3,455.05 5,957,167.78 502,075.16 Point 4 5,899.30 -2,995.81 3,438.38 5,957,201.40 502,058.49 Point 5 5,899.30 -2,974.98 3,421.71 5,957,222.23 502,041.83 Point 6 5,899.30 -2,954.02 3,396.70 5,957,243.20 502,016.83 Point? 5,899.30 -2,937.32 3,363.36 5,957,259.90 501,983.49 Point 8 5,899.30 -2,929.67 3,330.03 5,957,267.55 501,950.16 Point9 5,899.30 -2,929.68 3,296.68 5,957,267.55 501,916.82 Point 10 5,899.30 -2,937.34 3,263.35 5,957,259.90 501,883.49 Point 11 5,899.30 -2,954.05 3,230.02 5,957,243.20 501,850.16 Point 12 5,899.30 -2,975.03 3,205.02 5,957,222.23 501,825.16 Point 13 5,899.30 -2,995.86 3,188.36 5,957,201.40 501,808.50 Point 14 5,899.30 -3,029.49 3,171.69 5,957,167.78 501,791.82 Point 15 5,899.30 -3,052.79 3,165.36 5,957,144.48 501,785.50 Point 16 5,899.30 -3,078.80 3,163.37 5,957,118.48 501,783.50 Point 17 5,899.30 -3,102.80 3,165.37 5,957,094.48 501,785.49 Point 18 5,899.30 -3,128.10 3,171.71 5,957,069.18 501,791.83 Point 19 5,899.30 -3,128.04 3,455.07 5,957,069.18 502,075.16 Point 20 5,899.30 -3,102.74 3,461.40 5,957,094.48 502,081.49 5/6/2008 6:45:01PM Page 6 COMPASS 2003.16 Build 42F . ~+ .(~~ ~~ ;~ •~ _ . ~ ~: W ~~ ' k ._•i ..: ~ ~ ~ ,:.~ ice:. y, Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2A Pad Well: PIan:2A-26 W e I I bore: 2A-26 Design: 2A-26(wp05) Point 21 Gasing Points Measured Vertical Depth Depth (ft) (ft) 3,175.87 2,800.00 10 3/4" 7,640.72 5,880.00 7 5/8" 8,197.15 6,384.29 4112" Formations Measured Depth (ft) 7,692.91 7,846.28 3,156.53 7,818.70 7,596.92 1,556.25 7,738.15 ~ Plan Annotations Measured Depth (ft) 40.01 3,175.86 7,640.72 7,692.91 7,818.69 8,197.15 Vertical Vertical Depth Depth SS (ft) ft 5,927.30 6,066.30 2,786.30 6,041.30 5,840.30 1,492.30 5,968.30 Halliburton -Sperry Standard Proposal Report Local Co-ordinate Reference: Well Plan: 2A-26 -Slot 2A-26' TVD Reference: RKB @ 134.30ft (D15 (40+94.3)) MD Reference: RKB @ 134.30ft (D15 (40+94.3)) North Reference: True Survey Calculation Method: Minimum Curvature 5,899.30 -3,078.73 3,463.3 Name 5,957,118.48 502,083.49 Casing Hole Diameter (~~) Diameter (~~) 10-3/4 12-1/4 7-5/8 9-7/8 4-1/2 ,1 6-3/4 Name Kup C4 A3 Base West Sak A4 K1 Base Permafrost Kup B Vertical Local Coordinates Depth +N/-S +E/-W (ft) (ft) (ft) 40.01 0.00 0.00 2,800.00 -960.47 845.53 5,880.00 -3,037.93 3,287.51 5,927.30 -3,052.22 3,304.32 6,041.29 -3,086.64 3,344.82 6,384.29 -3,190.22 3,466.70 Lithology Dip pip Direction (°) (~) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Comment SHL: 776' FSL, 227' FWL - Sec13-T11 N-RO8E Surface Csg @ 3176' MD, 2800' TVD: 184' FNL, 1072' FWL -Sec24-T11 N-F Int. Csg @ 7641' MD, 5880' TVD: 2262' FNL, 1767' FEL -Sec24-T11 N-R08E Top Kup_C @ 7693' MD, 5927' TVD: 2277' FNL, 1750' FEL -Sec24-T11 N-F Top Kup_A4 @ 7819' MD, 6041' ND: 2311' FNL, 1710' FEL -Sec24-T11 N- BHL @ 8197' MD, 6384' TVD: 2415' FNL, 1588' FEL -Sec24-T11 N-R08E 5/6/2008 6:45:01PM Pa 7 COMPASS 2003.16 Build 42F ..~ ~~. ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2A Pad Plan: 2A-26 2A-26 2A-26 (wp05) r ~"" ~~ er*r .r~1~c~I rv+Gre ~... ~, ;, ~- Clearance Summary :~ ~~~ Anticollision Report .~ 06 May, 2008 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2A Pad -Plan: 2A-26 - 2A-26 - 2A-26 (wp05) Well Coordinates: 5,959,948.07 N, 1,638,653.54E (70° 18' 07.86" N, 150° 00' 51.41" W) Datum Height: RKB @ 134.30ft (D15 (40+94.3)) Scan Range: 0.00 to 8,197.47 ft. Measured Depth. Scan Radius is 1,015.75 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 LLIBtJTIiV Sperry Driillnp S®rvices Date: SURVEY PROGRAM OS-04-O1T00:00:00 Validated: Yes Version: Depth From Oepth To Survey/Plan Tool 40.00 300.00 2A-26 (wp05) (2A-26) CB-GYRO-SS 300.00 8197.15 2A-2G (wp05) (2A-2G) M~VD+IFR-AK-CA~SC 0 2A-0 2A-2 2A-1 vo ConocoPhillips (Alaska) Inc. -Kup2 Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based 90 ~ From Colour To MD ~ 40 250 250 500 500 750 750 1000 1000 - " ~ 2500 2500 -- ~M" 3500 3500 4000 4000 4500 4500 _, -_ _. _ 5000 5000 5500 180 90 Travelling Cylinder Azimuth (TFO+AZI) [°) vs Centre to Centre Separation i50 ft/inJ 160 2A-1 Travelling Cylinder Azimuth (TFO+AZI) ~°~ vs Centre to Centre Separation X200 ft/ink Details: Plan: 2A-26 NoRh American Datum 1981 Alaska Zone 4 Ground Level: 94.30 +N/-S +FJ-W Northing Easting Latittude Longitude Slot 0.00 0.00 5959948.07 1638653.54 70° 18' 7.859 N 150° 0' 51.413 W 2A-26" REFERENCEINFORMATION Co-ordinate (NIE) Reference: Well Plan: 2A-26 -Slot 2A-26`, True North VeRical(TVD) Reference: RKB @ 134.30ft (D15(40+94.3)) Section (VS) Reference: Slot - 2A-26•(O.OON, O.OOE) Measured Depth Reference: RKB @ 134.30ft (D15(40+94.3)) Calculation Method: Minimum Curvature Interpolation Method: MD, interval: 50.00 Depth Range From: 40.00 To 8197.47 Centre Distance: 1015.75 Reference: Plan: 2A-26 (wpD5)(Plan: 2A-26/2A-26) SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg 7Face VSec Target 1 ao.oo 6.0o a.oo ao.0o o.oo o.oo o.oo o.oo 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 701.31 8.03 140.00 700.00 -21.50 18.04 2.00 140.00 27.83 4 1565.52 33.95 140.00 1500.00 -256.61 215.32 3.00 0.00 332.21 5 2565.52 33.95 140.00 2329.50 -684.45 574.32 0.00 0.00 686.09 6 3336 66 48.06 130.36 2910.56 -1037.25 933.45 2.00 -27 94 1389.25 7 6989.63 46.06 130.36 5352.25 -2796.67 3003.92 0.00 0.00 4104.18 8 02 25.00 130.36 5812.30 -3017.33 3263.59 7566 4.00 180.00 4444.68 9 . 7662.01 25.00 130.36 5899.30 -3043.60 3294.50 0.00 0.00 4485.21 2A-26 (wp05) T7 10 8197.15 25.00 130.36 6384.30 -3190.06 3466.83 0.00 0.00 4711.20 HALLIBURTON Anticollision Report for Plan: 2A-26 - 2A-26 (wp05) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2A Pad -Plan: 2A-26 - 2A-26 - 2A-26 (wp05) Scan Range: 0.00 to 8,197.47 ft. Measured Depth. Scan Radius is 1,015.75 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Site Name Depth Distance Depth Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) Kuparuk 2A Pad 2A-01 - 2A-01 - 2A-01 807.05 38.12 807.05 2A-01 - 2A-01 - 2A-01 831.51 38.49 831.51 2A-01A - 2A-01A - 2A-01A 806.97 35.49 806.97 2A-01A - 2A-01A - 2A-01A 831.42 35.93 831.42 2A-02 - 2A-02 - 2A-02 1,013.09 76.18 1,013.09 2A-02 - 2A-02 - 2A-02 1,036.84 76.72 1,036.84 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Ellipse @Measured Clearance Summary Based on Separation Depth Factor Minimum (ft) ft 23.28 800.00 23.17 825.00 17.39 800.00 17.24 825.00 52.93 1,000.00 52.84 1,025.00 2.568 Centre Distance 2.512 Clearance Factor 1.961 Centre Distance 1.922 Clearance Factor 3.276 Centre Distance 3.213 Clearance Factor 2A-03 - 2A-03 - 2A-03 2A-03 - 2A-03 - 2A-03 2A-04 - 2A-04 - 2A-04 2A-04 - 2A-04 - 2A-04 2A-16 - 2A-16 - 2A-16 1,120.67 1,143.94 811.63 919.21 3,894.26 116.52 1,120.67 116.76 1,143.94 222.25 811.63 223.41 919.21 169.42 3,894.26 90.59 90.17 204.62 203.32 54.44 1,100.00 1,125.00 775.00 875.00 4,150.00 4.494 Centre Distance 4.391 Clearance Factor 12.606 Centre Distance 11.120 Clearance Factor 1.473 Clearance Factor 2A-18 - 2A-18 - 2A-18 2A-22 - 2A-22 - 2A-22 650.89 549.66 29.96 15.09 650.89 549.66 20.04 6.55 650.00 550.00 3.018 1.767 Clearance Factor Clearance Factor Kuparuk 3F Pad Kuparuk 3R Pad Survev tool Aroaram From (ft) 40.00 300.00 Separation Warning Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk To (ft) 300.00 2A-26 (wp05) 8,197.15 2A-26 (wp05) Survey/Plan Survey Tool CB-GYRO-SS MWD+IFR-AK-CAZ-SC O6 May, 2008 - 16:43 Page 2 of 5 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 NALL.IBURT~N Kuparuk River Unit Anticollision Report for Plan: 2A-26 - 2A-26 (wp05) Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor =Distance Between Profiles / (Distance Between Profiles -Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. r1 L J „~ .~ A,~~ „~ -,. L~ 06 May, 2008 - 16:43 Page 3 of 5 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 HALLIBURTON Anticollision Report for Plan: 2A-26 - 2A-26 (wp05) Kuparuk River Unit Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to RKB @ 134.30ft (D15 (40+94.3)). Northing and Easting are relative to Plan: 2A-26 -Slot 2A-26*. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is -150.00°, Grid Convergence at Surface is: -0.01 °. • 06 May, 2008 - 16:43 Page 4 of 5 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 HALLI6URTON Kuparuk River Unit Anticollision Report for Plan: 2A-26 - 2A-26 (wp05) Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor IOAO- 835- _ia0- 5 "..1 _ r ''~/+~ ~ - U tL ~ C 5A0- O w>,_ I3'~'~ ca I-" n ~ ~ 3~5- 2a0- 1 S - OAO D ;50 1500 2250 3000 ~ ~ 1 a ~ ! ., .: 1 < :. . . ^a ,. ,_. a il a 6 ~ .- M . ~ ,. - .-. ~~x 1 r ~~. ~. i. t ,1 t t ~ ~ _ _ ~ ~ ,~ _ _~ .' _ _ ~ •# ~ ' . a ~, ,e A } ~ _ ~ d ~ - _J __ __ - _~, 5 j .... ...:. -, r j ; i j 1 I 06 May, 2008 - 16:43 3:50 1500 .250 6000 Measured Depth (1544 ftAn) 6; 5U ; 500 8250 9000 Page 5 of 5 LEGEND -03, 2iL03, 2A-D3 V1 -02, 2l~02, 2A-03 V1 -01A, 2A-D tA, 2A-O to V3 t -118, 1D-118. Plan Itlt V1 -18, 3A 18, 2A 18 V1 -04, 2104, 2A-04 V1 1 -174, PIan:1C•174a, 1C-174a(~pDt)V2 Ian 1J-124, Plan 1J-124, 1J•134(wp05)V4 -18. Plan 4, 3F-18AL1-01, Plan IM4 \A •16, Plan 4, 3F-18AL1-02, Plan IM4 W -D 1, 21~01,2A-D1 1!2 -23, 2A22, 3A-22 V1 Ian Winstar Oliktok, Win star Oliktok Pt State "ff H30'YM11~ Otiktc 18, 2~k18,3A-18 W 38 (w p05) COMPASS ' ~ • ' Schlumberger CemCADE Preliminary Job Design 7.625" Topset CONTINGENCY Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: Client: ConocoPhillips Alaska, Inc. Revision Date: 5/15/2008 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com Previous Csg. < 10 3/4", 45.5# casing at 3,176' MD < Top of Tail at "~~ 6,500' MD < 7 5/8", 29.7# casing in 9 7/8" OH TD at 7,641' MD (5,880' TVD) Volume Calculations and Cement Systems Volumes are based on 50% excess. Tail slurry is designed for 1141' MD above the intermediate casing shoe (cement type as per client's request). Maximum dynamic pressure experienced during cement job is expected to be 14.7 ppg. Tail Slurry Minimum thickening time: 200 min. (Pump time plus 120 min.) GasBLOK w/ Class G + 2 gps D600G + 0.1 % B155 + 0.2 gps D047 + 0.35% D065 @ 15.8 ppg - 1.17 ft3/sk 2148 ft3/ft x 1141' x 1.50 (50% excess) = 0 367.6 ft3 . 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 367.6 ft3 + 20.6 ft3 = 388.2 ft3 388.2 ft3/ 1.17 ft3/sk = 331.8 sks Round up to 340 sks BHST = 127, Estimated BHCT = 879=. (BHST calculated using a gradient of 2.29=/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Stage Cumulative Rate Volume Time Time Stage (bpm) (bbl) (min) (min) Comments Drop Bottom Plug 10.0 10.0 MudPUSH II 6 40 6.7 16.7 Start Pumping Spacer Tail Slurry 6 71 11.8 28.5 Mix and Pump Tail Slurry Drop Top Plug 5.0 33.5 Switch to Rig Pump 5.0 38.5 Displacement 6 327 54.5 93.0 Start Displacement Slow Rate 3 20 6.7 99.7 Slow Rate to Bump Plug MUD REMOVAL Recommended Mud Properties: 11.3 ppg, Pv < 15, TY < 22. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.5 ppg MudPUSH" II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 2 per joint across zones of interest for proper cement placement. ~onocv-Phillips ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 2A Pad ._. _ ..~ ~~ Plan: 2A-26 (wp05) ~~ 1/4 Mile Pool Scan -~` Sperry Drilling Services May 5, 2008 A~.~ ~- £~psrry milling ~+srvic~s i Closest in POOL ,e W. ~°`' ~„~1 ~ Closest A roach: Reference Well: 2A-26 w 05 Plan Offset Well: 2A-16 3-D ctr- ctr ~ Meas Subsea Coords. -ASP View VS Meas. Subsea Coords. -ASP View VS ° Distance. . De th Incl. An le TRUE Azi. ND N + /S - E + /W - 132.62° Comments De th Incl. An le TRUE Azi. ND N + /S - E + /W - 132.62 Comments POOL Min Distance POOL Min Distance (1642.86 ft) in POOL (1642.86 ft) in POOL (5765 - 6249.8 (5765 - 6249.8 NDss) to 2A-16 NDss) to 2A-26 (5755 - 6247.57 (wp05) Plan (5755 - 1642.86 `~p;;~' 8197.15 25.00 130.36 6249.80 5956757.16 1642119.85 4711.39 NDss) 9150.00 51.05 147.32 5747.17 5955234.13 1642475.84 6336.95 6247.57 NDss) Closest A roach: Reference Well: 2A-26 w 05 Plan Offset Well: 2A-03 3-D ctr- ctr Meas. Subsea Coords. -ASP View VS Meas. Subsea Coords. -ASP View VS ° Distance. De th Incl. An le TRUE Azi. ND N(+ /S - E + /W(-) 132.62° Comments De th Incl. An le TRUE Azi. ND N + /S - E + /W - 132.62 Comments POOL Min Distance POOL Min Distance (2025.33 ft) in POOL (2025.33 ft) in POOL (5765 - 6249.8 (5765 - 6249.8 NDss) to 2A-03 NDss) to 2A-26 (5755 - 6082.05 (wp05) Plan (5755 - 2025.33 7687.01 25.00 130.35 5787.46 5956896.81 1641955.60 4495.96 NDss) 7230.00 45.83 145.53 6082.05 5957495.39 1640043.30 2683.62 6082.05 NDss) Closest A roach: Reference Well: 2A-26 w 05 Plan Offset Well: 2A-04 3-D ctr- ctr Meas. Subsea Coords. -ASP View VS Meas. Subsea Coords. -ASP View VS ° Distance. De th Incl. An le TRUE Azi. ND N + /S - E + NV - 132.62° Comments De th InG. An le TRUE Azi. ND N + /S - E + /W - 132.62 Comments POOL Min Distance POOL Min Distance (2767.51 ft) in POOL (2767.51 ft) in POOL (5765 - 6249.8 (5765 - 6249.8 NDss) to 2A-04 NDss) to 2A-26 (5755 - 6166.08 (wp05) Plan (5755 - 2767.51 7687.01 25.00 130.35 5787.46 5956896.81 1641955.60 4495.96 NDss) 7650.00 35.22 166.41 5751.38 5955332.14 1639673.15 3714.39 6166.08 NDss) 1r~ u POOL Summary Template1 5/5/2008 4:04 PM .~,~I Sperry Oriiling Services -1250 9 ~/8" -2250 °o -2750 0 -3000 -3zso -3 -4000 T M Azimuths to True North Magnetic North: 22.68° Magnetic Field Strength:57613.2snT -4250 Dip Angle: 60.77° Date: 3/13/2008 Model: BGGM2007 Project: Kuparuk River Unit Site: Kuparuk 2A Pad Well: Plan: 2A-26 Wellbore: 2A-26 Plan: 2A-26 (wp05) 0 250 500 750 ~n ~ ~ tiP REFERENCE INFORMATION WELL DETAILS: Plan: 2A-26 North American Datum 1983 Alaska Zone 4 Co-ordinate (N/E) Reference: Well Plan: 2A-26 -Slot 2A-26', True North Ground Level: 94.30 Vertical (fVD) Reference: RKB ~ 134.30fl (D15 (40+94.3p +N/-S +E/-W Northing Fasting Latittude I-ongi[ude Slo[ Measured Depth Reference: RKB ~ 134.30ft (D15 (40+g4.3)) 54 70° 18' 7.859 N 07 1638653 00 5959948 0 00 0 I50° 0' 51.41 3 W 2A-26* Calculation Method: Minimum Curvature . . . . CASING DETAILS TVD TVDSS MD Size Nazue 2800.00 2665.70 3175.86 10-3/4 l0 3/4" 5880.00 5745.70 7640.72 7-5/8 7 5/8" C,33d.39 6249.99 8197.15 4-1/2 41/2" 7 5/8" - 41/2" 0~1 y~4 b~ ;L ti~ -pA --- -_ , .2A-16 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 West(-)/East(+) (500 ft/in) ~'~ ConocoPhillips Conoco`Phillips -~m~~M~~ :,~ ~~ Ground bevel: 94.30 Sperry Orillfng Services RKB: RKB ~ 134.30ft (~15 (40194.3)( Nnrlhing/ASP Y: 5959948.07 [aslinglASP X: 1638653.54 U .-i•" I QQQ . _.. 9 5/8" 9 5/8" J~ I 10 3/ 2QQQ - - - - 9 5/8 3Q0~ .,.. O : ~-= 5~Q 2A-03 7"--- 0 ~'~ 7 5/8' 60~ ~0 2A-o4 4 1 /2"-.. 2A-26 (wp05) ..~~~~~.~ .~ : ! ~~~~ _ ~ ._ `~°o ~ o 00 o ~' - ~% 00 `~°oo ~ ~~o 00 ~~o 00 ~so °o • 2A-26 Drilling Hazards Summary 13-1/2" Hole / 10-3/4" Casing Interval Event Risk Level Miti anon Strate Broach of Conductor Low Monitor cellar continuousl Burin interval. Gas Hydrates Moderate If observed -control drill, reduce pump rates, reduce drilling fluid tem eratures, Additions of Lecithin. Gravel /Sand Sloughing Moderate Increase mud weight /viscosity, High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill (use of Trips trip sheets), Pumping out of hole as needed. Lost Circulation Low Prevent by keeping hole clean. If losses occur -reduce ump rates and mud rheology, use LCM 9-7/8" Hole / 7-5/8" Casing Interval Event Risk Level Miti anon Strate Shale stabili in HRZ and K-1 Moderate Control with hi er MW and ro er drillin ractices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Pump and rotate out on tri s as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling ay interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheolo y, LCM. Use GKA LC decision tree. 6-3/4" Hole / 4-1/2" Liner Interval Event Risk Level Miti anon Strate Differential Sticking Moderate Periodic wiper trips. Do not leave pipe static for extended period of time. Lube pills will be ready to be s otted if a stuck pipe incidents occurs. Difficulties getting liner to bottom Moderate Pump out of hole on final trip out prior to running liner to with swell packers ensure hole is clean. Spot Lube pills in open and cased hole if needed. Lost Circulation Moderate Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, pre-treat with LCM prior to drilling fault crossin s. 2A-26 Hazards.doc Prepared by Mike Greener Page 1 of 1 ~~~~ ~~_. • 2A-26 Producer Top Set "A" Sand If 7-5/8" is not drilled in 3 '/z" EUE 8rd tubing • ,. ~~~ Directional Plan 06 3 '/2" Camco DS nipple w/2.875" No-Go profile @ 500' 30" x 16" 62.6# @ +/- 110' MD 10-3/4" 45.5# L-80 BTC -/- 3,176' MD / 2,800' TVD TOC @ +/- 6,500' MD / 5,024' TVD 7-5/8" 29.7# L-80 Hydril 563 @ 7,754' MD / 5,982' TVD NOTE: After cmt job on 7-5/8", flush 7-5/8" x 10-3/4" Annulus with total of 126 bbls fresh water. Then freeze protect the Annulus w/ 100 bbls diesel. TO BE DETERMINED GLM #1 at +/- x,xxx' MD / x,xxx' TVD (Dummy Valve & RK latch) GLM #2 at +/- x,xxx' MD / x,xxx' TVD (Dummy Valve & RK latch) GLM #3 at +/- x,xxx' MD / x,xxx' TVD (Dummy Valve & RK latch) GLM #4 at +/- x,xxx' MD / x,xxx' TVD (Dummy Valve & RK latch) GLM #5 at+/- x,xxx' MD / x,xxr' TVD (DCR-1 Shear Valve & RK latch) • 2A-26 Producer Casing Drill to TD If 7-5/8" casing IS drilled in 3 '/2" EUE 8rd tubing • ~: ~~~5 3 '/2" Camco 'DS' nipple w/ 2.875" No-Go Profile. Set at 500' 30" x 16" 62.6# @ +/- 110' MD 10-3/4" 45.5# L-80 BTC -/- 3,180' MD / 2,800' TVD NOTE: After cmt job on 7-5/8", flush 7-5/8" x 10-3/4" Annulus with total of 126 bbls fresh water. Then freeze protect the Annulus w/ 100 bbls diesel. TO BE DETERMINED GLM #1 at +/- x,xxx' MD / x,xxx' TVD (Dummy Valve & RK latch) GLM #2 at +/- x,xxx' MD / x,xxx' TVD (Dummy Valve & RK latch) GLM #3 at +/- x,xxx' MD / x,xxx' TVD (Dummy Valve & RK latch) GLM #4 at +/- x,xxx' MD / x,xxx' TVD (Dummy Valve & RK latch) GLM #5 at+/- x,xxx' MD / ~,xsc' TVD {DCR-1 Shear Valve & RK latch) 2.813" no-go located above seal assembly 3-'/2" X 7-5/8" Premier Packer w/ 80-40 PBR pinned to shear @ 40K 3-''/z" Camco `DS' nipple w/ 2.813" No-Go profile one joint below packer 3-''/z" Wirleline Entry Guide w/ Full muleshoe 7-5/8" 29.7# L-80 Hydril 563 @ 8,197' MD / 6,384' TVD ORIGINAL • ~chlumberger CemCADE Preliminary Job Design 10 3/4" Surface Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: Client: ConocoPhillips Alaska, Inc. Revision Date: 5/9/2008 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com < TOC at Surface Previous Csg. < 16", 62.6# casing at 110' MD < Base of Permafrost at ~I 1,556' MD (1,490' ND) < Top of Tail at 2,380' MD < 10 3/4", 45.5# casing in 13 1/2" OH TD at 3,180' MD ~2,soo' TVD) Mark of Schlumberger Volume Calculations and Cement Systems Volumes are based on 300% excess in the permafrost and 50% excess below the permafrost. The top of the tail slurry is designed to be at 2,380' MD. Lead Slurry Minimum pump time: 270 min. (pump time plus 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 0.6381 ft3/ft x (110') x 1.00 (no excess) = 70.2 ft3 0.3637 ft3/ft x (1556' - 110') x 4.00 (300% excess) = 2103.6 ft3 0.3637 ft3/ft x (2380' - 1556') x 1.50 (50% excess) = 449.5 ft3 70.2 ft3 + 2103.6 ft3+ 449.5 ft3 = 2623.3 ft3 2623.3 ft3 / 4.45 ft3/sk = 589.5 sks Round up to 590 sks Have 310 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 200 min. (pump time plus 120 min.) DeepCRETE @ 12.0 ppg - 2.46 ft3/sk 0.3637 ft3/ft x (3180' - 2380') x 1.50 (50% excess) = 436.4 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 43.2 ft3 436.4 ft3 + 43.2 ft3 = 479.6 ft3 479.6 ft3/ 2.46 ft3/sk = 195 sks Round up to 200 sks BHST = 59~, Estimated BHCT = 66`i=. (BHST calculated using a gradient of 2.2`1=/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) bbl) (min) min) CW 100 5 50 10.0 10.0 Drop Bottom Plug 15.0 25.0 MudPUSH II 6 50 8.3 33.3 Lead Slurry 6 468 78.0 111.3 Tail Slurry 7 88 12.6 123.9 Drop Top Plug 5.0 128.9 Water 5 20 4.0 132.9 Switch to Rig Pumps 5.0 137.9 Displacement 6 258 43.0 180.9 Slow Rate 3 20 6.7 187.6 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 17-21, TY = 20-25 Centralizers: Recommend 1 per joint across zones of interest, and 2 per joint for bottom 8 joints for proper cement placement. • Schlumberger CemCADE Preliminary Job Design 7.625" Lon strin reliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: Client: ConocoPhillips Alaska, Inc. Revision Date: 5/15/2008 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com Volume Calculations and Cement Systems Volumes are based on 50% excess. Tail slurry is designed for 1397' MD above the intermediate casing shoe (cement type as per client's request). Maximum dynamic pressure experienced during cement job is expected to be 14.7 ppg. Tail Slurry Minimum thickening time: 210 min. (Pump time plus 120 min.) GasBLOK w/ Class G + 2 gps D600G + 0.1 % B155 + 0.2 gps D047 + 0.35% D065 @ 15.8 ppg - 1.17 ft3/sk 0.2148 ft3/ft x 1397' x 1.50 (50% excess) = 450.1 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 450.1 ft3 + 20.6 ft3 = 470.7 ft3 470.7 ft3/ 1.17 ft3/sk = 402.3 sks Previous Gsg. Round up to 410 sks < 10 3/4", 45.5# casing BHST = 138`F, Estimated BHCT = 97`F. at 3,17x' MD (BHST calculated using a gradient of 2.2`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Stage Cumulative Rate Volume Time Time Stage (bpm) (bbl) (min) (min) Comments Drop Bottom Plug 10.0 10.0 MudPUSH II 5 40 8.0 18.0 Start Pumping Spacer Tail Slurry 6 85 14.2 32.2 Mix and Pump Tail Slurry Drop Top Plug 5.0 37.2 ~ < Top of Tail at Switch to Rig Pump 5.0 42.2 ~~3 x,soo' MD Displacement 6 353 58.8 101.0 Start Displacement "I Slow Rate 2 20 10.0 111 Slow Rate to Bump Plug .i .,.~ `- ~ MUD REMOVAL < 7 5/8°, 29.7# casing Recommended Mud Properties: 12.5 ppg, Pv < 15, TY < 22. As thin and light as possible in 9 7/8" off to aid in mud removal during cementing. ~• ~ Spacer Properties: 15.5 ppg MudPUSH* II, Pv = 19-22, TY = 22-29 ,i Centralizers: Recommend 2 per joint across zones of interest for proper cement TD at 8,197 MD placement. ,~ (x,384' TVD) ConocoPhillips has requested the addition of: - Nut plug fine - Nut plug medium - CaCO (safecarb 250) Add as per ConocoPhillips design • • ' Schlumberger CemCADE Preliminary Job Design 7.625" To set CONTINGENCY reliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: Client: ConocoPhillips Alaska, Inc Revision Date: 5/15/2008 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com Volume Calculations and Cement Systems Volumes are based on 50% excess. Tail slurry is designed for 1254' MD above the intermediate casing shoe (cement type as per client's request). Maximum dynamic pressure experienced during cement job is expected to be 14.7 ppg. Tail Slurry Minimum thickening time: 200 min. (Pump time plus 120 min.) GasBLOK w/ Class G + 2 gps D600G + 0.1 % B155 + 0.2 gps D047 + 0.35% D065 @ 15.8 ppg - 1.17 ft3/sk 0.2148 ft3/ft x 1254' x 1.50 (50% excess) = 404.0 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 404.0 ft3 + 20.6 ft3 = 424.6 ft3 424.6 ft3/ 1.17 ft3/sk = 362.9 sks Previous Csg. Round up to 370 sks < 10 3/4", 45.5# casing gHST = 129, Estimated BHCT = 87~. at 3,17s' MD (gHST calculated using a gradient of 2.2/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Stage Cumulative Rate Volume Time Time Stage (bpm) (bbl) (min) (min) Comments Drop Bottom Plug 10.0 10.0 MudPUSH II 6 40 6.7 16.7 Start Pumping Spacer Tail Slurry 6 77 12.8 29.5 Mix and Pump Tail Slurry Drop Top Plug 5.0 34.5 < Top of Tail at Switch to Rig Pump 5.0 39.5 s,5oo' MD Displacement 6 332 55.3 94.8 Start Displacement Slow Rate 3 20 6.7 101.5 Slow Rate to Bump Plug MUD REMOVAL < 7 5/8", 29.7# casing Recommended Mud Properties: 11.3 ppg, Pv < 15, TY < 22. As thin and light as possible in 9 7/8"off to aid in mud removal during cementing. Spacer Properties: 13.5 ppg MudPUSH'` II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 2 per joint across zones of interest for proper cement TD at 7,754' MD placement. (5,982' ND) ~~~~~~ ~ °+, ~.r~ t~._ • • ~ Schlumberger CemCADE Preliminary Job Design 4 1/2" Liner Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: Client: ConocoPhillips Alaska Revision Date: 5/15/2008 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com Top of Tail at < 7,241' MD < Liner Top at ' MD ~~ ,s6'1 Previous Csg. 7 5/8", 29.7# casing ate' MD 7, 7~'t Volume Calculations and Cement Systems Volumes are based on 50% excess. Displacement is calculated with a 4.0"- 14.0# drill string. Cement job is designed to seal off liner top by bringing cement 200' above liner top, with 15.8 ppg G cement (cement type as per client's request). Maximum dynamic pressure experienced during cement job is expected to be 15.0 ppg. Tail Slurry Minimum thickening time: 140 min. (pump time plus 120 min.) GasBLOK w/ Class G + 2 gps D600G + 0.1 % B155 + 0.2 gps D047 + 0.35% D065 @ 15.8 ppg - 1.17 ft3/sk Liner Cap: 3 0.1705 ft3/ft x 200' x 1.00 (no excess) = 34.1 ft Liner Lap: 3 0.1473 ft3/ft x (7754' - 7554') x 1.00 (no excess) = 29.5 ft Annular Volume: 3 0.0942 ft3/ft x (8197' - 7754') x 1.50 (50% excess) = 62.6 ft Shoe Volume: 3 0.0854 ft3/ft x 80' x 1.00 (no excess) = 7.7 ft Totals: 34.1 ft3+29.5ft3+62.6ft3+7.7ft3= 133.9 ft3 133.9 ft3/ 1.17 ft3/sk = 114.4 sks Round up to 120 sks BHST = 138`F, Estimated BHCT = 114`F. (BHST calculated using a gradient of 2.2`F/100 ft. below the permafrost) PUMP SCHEDULE 44444444 Pump Stage Stage Cumulative Rate Volume Time Time < 4 1/2", 12.6# casing Stage (bpm) (bbl) (min) (min) Comments in 6 1/8" OH MudPUSH II 5 20 4.0 4.0 Start Pumping Spacer Tail Slurry 6 25 4.2 8.2 Mix and Pump Tail Slurry Drop Wiper Dart 3.0 11.2 Displacement 6 70 11.7 22.9 Start Displacement Slow Rate 3 20 6.7 29.6 Slow Rate to Bump Plug MUD REMOVAL Recommended Mud Properties: 12.5 ppg, Pv < 15, TY < 22. As thin and light as possible to aid in mud removal during cementing. TD at 8,197' MD Spacer Properties: 13.5 ppg MudPUSH* II, Pv ~ 19-22, TY = 22-29 Centralizers: Recommend 2 perjoint across zones of interest for proper cement (x,384' TvD) placement. h Mark of Schlumberger ~~~ 6050000 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 800000 Page 1 of 1 ~ ~ Maunder, Thomas E (DOA) From: Greener, Mike R. [Mike.R.Greener@conocophillips.com] Sent: Monday, June 16, 2008 6;46 AM To: Maunder, Thomas E (DOA) Cc: Thomas, Randy L Subject: RE:2A-26 Attachments: Greener, Mike R..vcf Yes the full string of 7-5/$" will be run for the "smear" interval. The rams will be installed after we drill to the depth of 7,641' and then POOH with the conventional. bit. Mike Greener From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, June 12, 2008 4:34 PM To: Greener, Mike R. Cc: Thomas, Randy L Subject: 2A-26 Mike and Randy, I am reviewing the permit application for the subject well. 1. Will a full string of 7-5/8" be run to drill the "smear" interval? 2. I do not see that 7-5/8" rams are installed for that operation. Thanks in advance. Tom Maunder, PE AOGCC 6/16/2008 ~ ! TRANSMITTAL/LETTER CHECKLIST WELL NAME `` ~~ Z~'ZfO PTD# ?~~ 'b`~ ~` Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well -- ' (If fast two digits in permit No. ,API No. 50- - API number ~'e production should continue to be reported as a function of the between 60-69) original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- -^~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION ZS.O55. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing s the exception. , _ assume liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for dame of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Nnme) must contact the Commission to obtain advance approval of such water well testing ro am. Rev: 7/132007 YVECL PERMIT CHECKLIST. Field & Pool KUPARUK RIVER, KUPARUK RIVOIL - 490100 Well Name: KUPARUK RIV UNIT 2A-26 Program DEV Well bore seg ^ PTD#:2080940 Company c'.ON000PHILLIPSALASKA INC Initial ClasslType DEV! PEND GeoArea 890 Unit 11160 On1Off Shore ~_ Annular Disposal ^ Administration 1 Petmitfee>~ttached ---- ----- - - - ------- --- --- ~' - --- - - -- ----- - -------- ------ -- -- - ---- 2 Lease number approROate- - - - - - - - - - - - - - - - - Yes - - - Ertite well in ADL Q2557Q - - - - - - - - - - - - - - - - - - - - - - - - 3 Uniqueweltnameandnumber --- --- -- ----- - --- --- Yes-- --- - ---- - -- -- ------- --- - - - --- - ----- 4 Well located in a_def nedpool - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ - - - KUPARUK RIVER,_ KUPARUK RV QIL - 49014Q, governed by Conservation Order No. 4$2C. _ - - - _ - - - _ _ 5 Well located proper distance from drilling unh-boundary- - - - - - - - - - -- - - - - - - - - - - - -Yes _ - - - _ - -Conservation Oder No. 4320 contains no spacing restrictions with respect_to dolling unit boundaries. _ _ _ _ _ - _ 6 Well located proper distance from other wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ - _ Yes _ - - _ _ _ Conservation O[de[ No. 432C has no interwell_spacing_rgstnc#ions, - _ _ - _ _ - _ _ _ _ _ _ - - - - - - _ _ _ _ - - 7 Sufficient arreage_ayailable in drilling unit- - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ _ _ _ _ - -Conservation Order No. 4320 has no inter!cell-spacing_restric#ions, WellboCe will ke-mQre than 540' from _ - - - - - 8 If deviated, is_wellbore plet_included - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ _ _ - _ - - an external property line where ovmership or landownership changes. - - _ - - - - - - - - - _ _ - _ . _ - - - - . 9 Ope[atotonlyaffactedparb'------ ---- ----- --- --- -- - Yes- - --- -- -- - - --- - - ----- - ------- ------ ------ 10 Operatorhas-appropria#e bondlnforoe-- ---- -- - --- --- ----Yes------ - -- -- - --- -- ---------- ------ -- - ----- --~ 11 Petm4.oaDbeissuedwlthoutconserYationorder------------------ ---------Yes------ -----------------------------.---------------------.---------------- Appr Date 12 Pe[mitoanbeissuedwithoutadministtativ_e_approval-------------- ----------Yes------ --------------------------------------------------------------------- 13 CanpermitbeaPRrov_edbefore15•daywait- ---- - ------ ----- -Yes-- ------ ---- - ------ ----- -- - - - -- ------ SFD 6111!2008 14 WeillQCatedwithinarQasndstrataauthorizedby.InjectionOrdet#(put_IO#in- comments)(FOr_ NA__._-- -__--------------------_--_------___--_-----_---_----____-_---_-. 15 Ailwells_within1l4_mileateeofreyiewidentified(Fo[servieewelionly)----- ---------- NA_------ ___--------.----_-------_------_--_--------..----------------------- 16 Pte-producedinjectoe duration of preptoductionlessthan3months-(For service wellonly)---NA------ --------------------------------------------------------------------- 17 .Nonconven, 9as_conforms to A831,05.034Q.1.A),(~2.A-D) - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Engineering 18 Conductorstung-provided- ---- --- -- ---- - ----- Yes---- ------- -- -- --- ----- ------- -- -- -- -- - ---~- - 19 SurfacecasingprQt@ctsallknownUSDWs-------------------- ---------- ~?------- -Allaqurfersexempted,40CFR_147.142(bJ($).-------------------------------------- 20 CMTVOIadequate_tDCirculate-on_conductor&surf-csg-------------- ---------Yes------ ----------_----------------------------------------------------- ! 21 CMT vol adequate-to tie-in long string to ss~rf sig. - - - - - - - - - - - - - NO - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 22 CMTwillcover-ail knownproductivehorizons-------------------- ----------Yes_----- ------------------------------------------------------------------- 23 CasiD9desgnssdequatefotC,LE3&-permatrost-- - ---- -- -- ----Yes -- - - ----- -- -- -------- ---- -- - - -- -------- 24 Adequate iankageor reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ - _ Yes - _ - - _ _ Rig equipped with steel phs, No reserve pi#planned._ All waste_to;~pproved AnnuN or-disposal welljs)._ _ _ _ _ _ _ - 25 If_a_re-drill,has_a1D-403forabandonmentkeen approved----------- ---------- NA------ --------------------------------------------------------------------- 26 Adequate weilbore separetionproposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ - - - _ - _ Proximity anaysis perf_otmed, Traveling cylinder path calcula#ed, Gyros possible insurface-hole, - _ _ - - _ _ - _ _ 27 Ifdiverter_required,do_esitmeetregulations.---- - -- - -- - - --- Yes---- -- -- ------ -- - ---- ------- - ---- - ----- -- Appr Date 28 Dolling flujd-program schematic & equip list adequgte- - - - - - - - - - - - - - - - - - - -Yes - _ - _ _ - -Maximum expected fomration pressure 11.4 EMN/._ Planned MW up t919.5 ppg or as needed._ - - - - - _ - - - _ TEM 6116(2008 29 BOPEs,_do theymeet regulation _ - - - _ - - - _ - - - - - - - - - - - - - - - - - - - - _ _ Yes - - - _ - _ _Casing drilling is planned to"strengthen" deep formation to withstand higher EMW. Topset wl liner_possible - _ - _ 30 BOPE_press rating appropriate; test to_(put psig in comments)- - - - - - - - - - _ - _ _ -Yes _ . _ - _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ BOP tesiplanned_ - MASP calculated at 2054 psi, 3500_psi .- ` ~~ 31 Chpke_manifeldcompiieswlAPl_RP•53(May34)----------------- -----------Yes------ = _ _ _ _ _ -.--------------- 32 Work will9ccurwithoutoperationshutdown-___-___----.__-- ----_---_-Yes_---- ------------------------------------------------------------------ 33 Is Rresence of H2S gas probable - - - - - - - - - - - - - - - - - _ - - - _ - - _ - - - _ - Yes - _ _ - _ _ H2& is reported-at 2A pad. Mud should preclude on rig. - Rig has_sentors and alarms. - - - - - _ - - - _ - - 34 Mechanical_condifton of wells within AQR yer~ed (FOt service wel) only - - - - - - - - - - - - - NA_ _ - - _ - - - - - _ _ . _ - _ - - _ Geology 35 Petmitoan be issued wlo hydrogen_sulfiderneasures - - - - - - - - - - - - - - - - - - - - - - - - No_ _ _ _ - - _ - H2$ occurs in-significan# quantities in the Kupeak reservoir ai 2A-Pad.- - - _ - - - - - - _ - - - _ - - _ . - - _ - _ 36 Data-presented on po#entiai overpressurezores- - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - _ _ _Kup-C sand ergzected to_be n°rmally pressured, brit K~ A sand expected to_ - - - _ - - - _ - - - - - - _ - . _ _ _ - - Appr Date 37 Seismic analysis of shallow gas zones- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ _ _ _ - have EMW of 19,4 ppg; Kup A will_!~e top-set with_casing and drilled with - - _ _ - - - - - - - - - - _ . _ - - _ SFD 611112008 38 Seabed condition serve _ doff-shore) - - - - - - - - - - - - - - - - - - - - _y(~ ---- ---NA- --- -11.5 ppg mud.-- -- -- ------ - ------ - -- -- - ---- 39 Contactnamelphoneforweekty-grog-ressreAOrts[exPloratory only]------ ----------NA------- ------------------------------------------------------------------- Geologic Commissioner: Date: Engineering Date P is Commissioner: Co issi Date ~~,~ ~ e6-~~ 6 /608 • iNelt 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. 2A-26.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Feb 27 15:25:27 2009 Reel Header Service name .............LISTPE Date . ...................09/02/27 Ori qin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................sTS LIS writing Library. Tape Header Service name .............LISTPE Date . ...................09/02/27 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Physical EOF scientific Technical services Library. Scientific Technical Services Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: 2A-26 API NUMBER: 501032057500 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 27-FEB-09 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: Mw-000588405 Mw-000588405 Mw-000588405 LOGGING ENGINEER: S. POLAK 5. POLAK S. POLAK OPERATOR WITNESS: F. HERBERT F. HERBERT M. THORTON MWD RUN 4 JOB NUMBER: Mw-000588405 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: M. THORTON SURFACE LOCATION SECTION: 13 TOWNSHIP: 11N RANGE: 8E FNL: FSL: 776 FEL: FWL: 227 Page 1 2A-26.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: 40.35 DERRICK FLOOR: 132.45 GROUND LEVEL: 92.10 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.500 16.000 110.0 2ND STRING 9.880 10.750 3149.0 3RD STRING 6.750 7.625 7796.0 PRODUCTION STRING 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 RUN 1 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, DRILLSTRING DYNAMICS SENSOR (DDSr) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR). 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR), PRESSURE WHILE DRILLING (PWD), AND DRILLSTRING DYNAMICS SENSOR (DDSr), COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL LITHO DENSITY (ALD) AND BIMODAL ACOUSTIC (BAT). 5. MWD RUN 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND DRILLSTRING DYNAMICS SENSOR (DDSr), COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL LITHO DENSITY (ALD). 6. MWD RUN 4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND DRILLSTRING DYNAMICS SENSOR (DDS), COMPENSATED THERMAL NEUTRON (CTN), STABILIZED LITHO DENSITY (SLD), AND BIMODAL ACOUSTIC (BAT). 7. MWD DATA ARE CONSIDERED PDC AS PER VERBAL INSTRUCTIONS FROM JENNIFER HEAD (CPAI) TO BRYAN BURINDA (SDS) ON 18-FEB-2008. 8. MWD RUNS 1-3 REPRESENT THE WELL 2A-26 WITH API#: Page 2 2A-26.tapx 50-103-20575-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8210 ft MD, 6419 ft TVD. SROP = RATE OF PENETRATION WHILE DRILLING. SGRC = GAMMA RAY COMBINED. SEXP = PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = FORMATION EXPOSURE TIME. TNPS = THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = BULK DENSITY-COMPENSATED (LOW-COUNT RATE BIN). SC02 = STANDOFF CORRECTION (LOW-COUNT RATE BIN). SNP2 = PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT RATE BIN). DTCP = COMPRESSIONAL SLOWNESS DTSP = SHEAR SLOWNESS VPVS = RATIO OF COMPRESSIONAL VERSUS SHEAR VELOCITY LOG MARKERS: SHEARFL = INDICATES SHEAR IS REFRACTED SHEAR WITH NO DISPERSION CORRECTION APPLIED. DENSLIDE = INDICATES INTERVALS OF NON-DRILLSTRING ROTATION REFERENCED TO DENSITY SENSOR DEPTH. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: FIXED (9 7/8" AND 6 3/4" NOMINAL) AVG OFFSET: FIXED (.5" NOMINAL) MUD WEIGHT: 8.6-9.4 (9 7/8") PPG AND 12.8 PPG (6 3/4"~ MUD SALINITY: 350-500 PPM CHLORIDES MUD TYPE: WATER BASED MUD FORMATION WATER SALINITY: 14,545 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT. EXCEPT FOR ROP AND GAMMA RAY, THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. ALSO SONIC DATA IS SMOOTHED WITH A 1.8 FT WINDOW. THE GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/27 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sT5LI6.000 Comment Record Page 3 2A-26.tapx FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 173.0 8153.0 RPD 232.0 8160.0 FET 232.0 8160.0 RPx 232.0 8160.0 RPS 232.0 8160.0 RPM 232.0 8160.0 ROP 242.0 8210.0 NPHI 3139.0 8125.0 DRHO 3139.0 8140.0 NCNT 3139.0 8125.0 RHOB 3139.0 8140.0 FCNT 3139.0 8125.0 PEF 3139.0 8140.0 DTC 3140.0 8086.0 DTSH 3153.5 8086.0 CRA 3153.5 8086.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP 1 173.0 2 3150.0 3 6895.0 4 7490.0 REMARKS: MERGED MAIN PASS. MERGE BASE 3150.0 6895.0 7490.0 8210.0 Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 DTC MWD USPF 4 1 68 12 4 DTSH MWD USPF 4 1 68 16 5 RHOB MWD G/CC 4 1 68 20 6 DRHO MWD G/CC 4 1 68 24 7 Page 4 ~ ~ 2A-26.tapx RPD MWD OHMM 4 1 68 28 8 RPM MWD OHMM 4 1 68 32 9 RPS MWD OHMM 4 1 68 36 10 RPX MWD OHMM 4 1 68 40 11 FET MWD HR 4 1 68 44 12 GR MWD API 4 1 68 48 13 PEF MwD B/E 4 1 68 52 14 ROP MWD FPH 4 1 68 56 15 NPHI MWD PU 4 1 68 60 16 SCRA MWD NONE 4 1 68 64 17 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 173 8210 4191.5 16075 173 8210 FCNT MWD CP30 139.54 2510.31 1172.74 9190 3139 8125 NCNT MWD CP30 14849.9 273106 197435 9190 3139 8125 DTC MWD USPF 52.34 132.89 108.405 7869 3140 8086 DTSH MWD USPF 144.17 333.12 226.89 7842 3153.5 8086 RHOB MWD G/CC 1.459 2.715 2.30398 9237 3139 8140 DRHO MWD G/CC -1.244 0.351 0.0627715 9237 3139 8140 RPD MWD OHMM 1.04 2000 27.224 15048 232 8160 RPM MWD OHMM 0.42 2000 26.0311 15048 232 8160 RPS MWD OHMM 0.16 2000 17.0433 15048 232 8160 RPX MWD OHMM 0.98 346.9 11.9364 15048 232 8160 FET MWD HR 0.05 191.08 2.23995 15048 232 8160 GR MwD API 11.83 423.48 98.2125 15293 173 8153 PEF MwD B/E 1.36 19.78 3.32177 9237 3139 8140 ROP MWD FPH 0.25 2968.26 242.526 15937 242 8210 NPHI MwD PU 14.09 55.6 31.4414 9190 3139 8125 SCRA MWD NONE 1.5841 2.6367 2.08456 7842 3153.5 8086 First Reading For Entire File..........173 Last Reading For Entire File...........8210 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/27 Maximum Physical Record..65535 File Type ................Lo Next File Name...........5T5LIB.002 Physical EOF File Header Service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/27 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: Page 5 ~ ~ 2A-26.tapx RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 173.0 3097.0 SEDP 232.0 3089.5 SEXP 232.0 3089.5 SESP 232.0 3089.5 SEMP 232.0 3089.5 SFXE 232.0 3089.5 ROP 242.0 3150.0 $ LOG HEADER DATA DATE LOGGED: 02-JAN-09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 3150.0 TOP LOG INTERVAL (FT): 242.0 BOTTOM LOG INTERVAL (FT): 3150.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: 42.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 268322 EWR4 ELECTROMAG. RESIS. 4 116184 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 13.500 DRILLER'S CASING DEPTH (FT): 110.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 155.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3): 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 6.000 63.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.970 98.6 MUD FILTRATE AT MT: 7.000 63.0 MUD CAKE AT MT: 3.500 63.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 6 2A-26.tapx Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined ,4bsent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWDO10 OHMM 4 1 68 4 2 RPM MWDO10 OHMM 4 1 68 8 3 RPS MWDO10 OHMM 4 1 68 12 4 RPX MWDO10 OHMM 4 1 68 16 5 FET MWDO10 HR 4 1 68 20 6 GR MWDO10 API 4 1 68 24 7 ROP MWDO10 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 173 3150 1661.5 5955 173 3150 RPD MWDO10 OHMM 3.34 2000 58.1166 5706 232 3089.5 RPM MWDO10 OHMM 3.67 2000 58.5394 5706 232 3089.5 RPS MWDO10 OHMM 3.48 2000 37.7184 5706 232 3089.5 RPX MWDO10 OHMM 3.12 238.9 25.5698 5706 232 3089.5 FET MWDO10 HR 0.05 1.41 0.577375 5706 232 3089.5 GR MWD010 API 11.83 116.57 67.0936 5849 173 3097 ROP MWDO10 FPH 0.25 2968.26 285.179 5817 242 3150 First Reading For Entire File..........173 Last Reading For Entire File...........3150 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/27 Maximum Physical Record..65535 File Type ................L0 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.......09/02/27 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.002 Page 7 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY 2A-26.tapx header data for each bit run in separate files. 2 .5000 VENDOR TOOL CODE SGRC SFXE CT FA SEXP CTNA SNP2 TNPS SBD2 SEMP SC02 SESP SEDP DTCP VPVS DTSP LOG HEADER DATA START DEPTH 3103.0 3139.0 3139.0 3139.0 3139.0 3139.0 3139.0 3139.0 3139.0 3139.0 3139.0 3139.0 3140.0 3153.5 3153.5 STOP DEPTH 6847.5 6839.5 6796.5 6839.5 6796.5 6782.5 6796.5 6782.5 6839.5 6782.5 6839.5 6839.5 6774.0 6774.0 6774.0 DATE LOGGED: 07-JAN-09 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 6895.0 TOP LOG INTERVAL (FT): 3150.0 BOTTOM LOG INTERVAL (FT): 6895.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 38.7 MAXIMUM ANGLE: 52.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 11204306 CTN COMP THERMAL NEUTRON 185457 BAT Bi-modal Accostic 177762 ASLD Azimuthal Litho-Den 11130532 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.880 DRILLER'S CASING DEPTH (FT): 3149.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 41.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 420 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 2.900 75.0 Page 8 2A-26.tapx MUD AT MAX CIRCULATING TERMPERATURE: 1.640 138.2 MUD FILTRATE AT MT: 2.300 75.0 MUD CAKE AT MT: 1.600 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MWD020 CP30 4 1 68 4 2 NCNT MwD020 CP30 4 1 68 8 3 DTC MWD020 USPF 4 1 68 12 4 DTSH MWD020 USPF 4 1 68 16 5 RHOB MWD020 G/CC 4 1 68 20 6 DRHO MWD020 G/CC 4 1 68 24 7 RPD MWD020 OHMM 4 1 68 28 8 RPM MwD020 OHMM 4 1 68 32 9 RPS MWD020 OHMM 4 1 68 36 10 RPx MWD020 OHMM 4 1 68 40 11 FET MWD020 HR 4 1 68 44 12 GR MWD020 API 4 1 68 48 13 PEF MwD020 B/E 4 1 68 52 14 NPHI MWD020 PU 4 1 68 56 15 SCRA MWD020 NONE 4 1 68 60 16 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3103 6847.5 4975.25 7490 3103 6847.5 FCNT MWD020 CP30 807.6 2510.31 1233.65 7316 3139 6796.5 NCNT MWD020 CP30 176361 273106 210649 7316 3139 6796.5 DTC MWD020 USPF 52.34 132.89 109.174 7269 3140 6774 DTSH MWD020 USPF 144.17 333.12 230.375 7242 3153.5 6774 RHOB MWD020 G/cc 1.459 2.715 2.27196 7288 3139 6782.5 DRHO MWD020 G/CC -1.244 0.351 0.0637143 7288 3139 6782.5 RPD MWD020 OHMM 1.04 2000 8.62995 7402 3139 6839.5 RPM MWD020 OHMM 0.42 48.89 3.7441 7402 3139 6839.5 RPS MWD020 OHMM 0.16 22.09 3.63854 7402 3139 6839.5 RPx MWD020 OHMM 0.98 20.79 3.52622 7402 3139 6839.5 FET MwD020 HR 0.16 92.62 0.875927 7402 3139 6839.5 GR MWD020 API 37.52 222.98 115.562 7490 3103 6847.5 PEF MWD020 B/E 1.36 14.01 2.65605 7288 3139 6782.5 Page 9 • 2A-26.tapx NPHI MwD020 Pu 14.09 55.6 31.0888 7316 3139 SCRA MWD020 NONE 1.5841 2.6367 2.10284 7242 3153.5 First Reading For Entire File..........3103 Last Reading For Entire File...........6847.5 File Trailer Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/27 Maximum Physical Record..65535 File TyE~e ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/27 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SNP2 6783.0 7408.5 SCO2 6783.0 7408.5 SBD2 6783.0 7408.5 TNPS 6797.0 7394.5 CTFA 6797.0 7394.5 CTNA 6797.0 7394.5 SESP 6840.0 7435.0 SFXE 6840.0 7435.0 SEMP 6840.0 7435.0 SEXP 6840.0 7435.0 SEDP 6840.0 7435.0 SGRC 6847.5 7442.5 SROP 6895.5 7490.0 LOG HEADER DATA DATE LOGGED: 08-JAN-09 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7490.0 TOP LOG INTERVAL (FT): 6895.0 Page 10 6796.5 6774 ~ i 2A-26.tapx BOTTOM LOG INTERVAL (FT): 7490.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 24.5 MAXIMUM ANGLE: 37.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 11204306 CTN COMP THERMAL NEUTRON 179954 ASLD Azimuthal Litho-Den 151843 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.880 DRILLER'S CASING DEPTH (FT): 3149.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 41.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 420 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.700 71.0 MUD AT MAX CIRCULATING TERMPERATURE: .970 129.2 MUD FILTRATE AT MT: 1.100 71.0 MUD CAKE AT MT: 1.100 71.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ......... .. ... ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FONT MWD030 CP30 4 1 68 4 2 NCNT MWD030 CP30 4 1 68 8 3 RHOB MWD030 G/CC 4 1 68 12 4 DRHO MWD030 G/CC 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 Page 11 • 2A-26.tapx RPx MwD030 oHMM 4 1 68 32 9 FET MWD030 HR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 B/E 4 1 68 44 12 RoP MWD030 FPH 4 1 68 48 13 NPHI MWD030 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6783 7490 7136.5 1415 6783 7490 FCNT MWD030 CP30 915.15 1987.58 1291.08 1196 6797 7394.5 NCNT MWD030 CP30 188873 252365 216315 1196 6797 7394.5 RHOB MwD030 G/CC 1.655 2.654 2.42883 1252 6783 7408.5 DRHO MWD030 G/CC -0.005 0.233 0.0620439 1252 6783 7408.5 RPD MwD030 OHMM 1.04 6.49 2.88466 1191 6840 7435 RPM MwD030 OHMM 0.97 5.96 2.7472 1191 6840 7435 RPS MWD030 OHMM 0.99 5.56 2.73224 1191 6840 7435 RPx MWD030 OHMM 1 5.74 2.68927 1191 6840 7435 FET MwD030 HR 0.22 27.68 3.28551 1191 6840 7435 GR MWD030 API 65 423.48 149.433 1191 6847.5 7442.5 PEF MwD030 B/E 2.03 5.23 3.38263 1252 6783 7408.5 ROP MWD030 FPH 4.32 383 179.842 1190 6895.5 7490 NPHI MWD030 PU 20.17 52.46 32.1847 1196 6797 7394.5 First Reading For Entire File..........6783 Last Reading For Entire File...........7490 File Trailer Service name... .......STSL26.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/27 Maximum Physical Record..65535 File Type ................Lo N2xt File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/02/27 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH Page 12 • • 2A-26.tapx SROP 7490.5 8210.0 SGRC 7746.5 8153.0 SEDP 7786.0 8160.0 SFXE 7786.0 8160.0 SEXP 7786.0 8160.0 SEMP 7786.0 8160.0 SESP 7786.0 8160.0 vPVS 7786.5 8086.0 CTFA 7786.5 8125.0 CTNA 7786.5 8125.0 TNPS 7786.5 8125.0 DTCP 7786.5 8086.0 DTSP 7786.5 8086.0 SBD2 7792.0 8140.0 SNP2 7792.0 8140.0 SC02 7792.0 8140.0 LOG HEADER DATA DATE LOGGED: 19-JAN-09 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8210.0 TOP LOG INTERVAL (FT): 7490.0 BOTTOM LOG INTERVAL (FT): 9210.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 18.7 MAXIMUM ANGLE: 19.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 184054 SLD STABILIZED LITHO DEN 109110 CTN COMP THERMA L NEUTRON 239974 BAT Bi-modal Ac costic 147826 EWR4 Electromag Resis. 4 90518 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7796.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 12.80 MUD VISCOSITY (S): 48.0 MUD PH: 10.2 MUD CHLORIDES (PPM): 290 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.600 71.0 MUD AT MAX CIRCULATING TERMPERATURE: .920 129.2 MUD FILTRATE AT MT: 1.350 71.0 MUD CAKE AT MT: 3.000 71.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): Page 13 • 2A-26.tapx TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... .......... 0 Data specification Block Type..... 0 Logging Direction ................. DOwn Optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999 Depth Units. .. .. ..... Datum specification Block sub-type ...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 FONT MWD040 CP30 4 1 68 4 2 NCNT MWD040 CP30 4 1 68 8 3 DTC MWD040 USPF 4 1 68 12 4 DTSH MWD040 USPF 4 1 68 16 5 RHOS MwD040 G/CC 4 1 68 20 6 DRHO MWD040 G/CC 4 1 68 24 7 RPD MwD040 OHMM 4 1 68 28 8 RPM MwD040 OHMM 4 1 68 32 9 RPS MWD040 OHMM 4 1 68 36 10 RPx MwD040 oHMM 4 1 68 40 11 FET MWD040 HR 4 1 68 44 12 GR MwD040 API 4 1 68 48 13 PEF MwD040 B/E 4 1 68 52 14 ROP MWD040 FPH 4 1 68 56 15 NPHI MWD040 Pu 4 1 68 60 16 SCRA MWD040 NONE 4 1 68 64 17 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7490.5 8210 7850.25 1440 7490.5 8210 FCNT MWD040 CP30 139.54 529.62 306.772 678 7786.5 8125 NCNT MWD040 CP30 14849.9 28232.3 21550.3 678 7786.5 8125 DTC MWD040 USPF 88.73 108.72 99.0867 600 7786.5 8086 DTSH MwD040 USPF 152.19 205.39 184.823 600 7786.5 8086 RHOB MWD040 G/CC 2.057 2.68 2.41456 697 7792 8140 DRHO MWD040 G/CC -0.41 0.191 0.0542195 697 7792 8140 RPD MWD040 OHMM 1.57 1366.38 14.3386 749 7786 8160 RPM MWD040 OHMM 1.45 2000 35.6536 749 7786 8160 RPS MWD040 OHMM 1.47 1475.5 14.766 749 7786 8160 RPX MWD040 OHMM 1.48 346.9 5.89227 749 7786 8160 FET MWD040 HR 0.98 191.08 26.7232 749 7786 8160 GR MWD040 API 32.67 113.03 83.6893 814 7746.5 8153 PEF MwD040 B/E 6.32 19.78 10.1735 697 7792 8140 ROP MWD040 FPH 0.93 113.9 45.5573 1440 7490.5 8210 NPHI MwD040 Pu 22.43 50.25 33.9346 678 7786.5 8125 SCRA MWD040 NONE 1.5898 2.1256 1.86392 600 7786.5 8086 First Reading For Entire File..........7490 Last Reading For Entire File...........8210 Page 14 2,4-26. tapx File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 gate of Generation.......09/02/27 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE gate . ...................09/02/27 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE gate . ...................09/02/27 Ori 9in ...................STs Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End of LIS File :7 scientific Technical services scientific Technical services Page 15 ~ ~ Memory Muni-Finger Galpler Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2A-2S Log Date: Apri15, 2009 Fieki: Kuparuk Log No.: 7307 State: Alaska Run No.: 1 API No.: 50-103-20575-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8rd Mod Top Log Intvl1.: Surtace Pipet Use: Tubing Bot. Log Intvl1.: 588 Ft. (MD) Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8rd Mod Top Log Intvl2.: 7,260 Ft. (MD) Pipet Use: Tubing Bot. Log Intv12.: 7,583 Ft. (MD) Inspection Type : /ntemal Diameter Inspection COMMENTS The upper log Interval is tied Into the 3.5" Camco DS Nlpp/e at 511' (MD), and the lower log interval is tied into the 3.5" Camco D Mipp/e at 7`,515' (MD). This log was run to verify the internal diameters of the Camco DS Nipple (511') and the Camco D Nipple (7,515'). The Camco DS Nipple (511') appears to be 2.875" nominal ID, with a minimum recorded ID of 2.85" (511'). The Camco D Nipple (7,515') appears to be 2.810" nominal ID, with a minimum ID of 2.77" (7,516'). Scale-like, light deposits are recorded throughout the lower half of the D Nipple. 3-D log plots of the caliper recordings across these intervals are included in this report. The caliper recordings indicate the 3.5" tubing logged is in good condition with respect to corrosive and mechanical damage. No significant wall penetrations (>9°~), cross-sectional wall loss (> 6%) and ID restric#ions are recorded throughout the 3.5" tubing logged. Caliper recordings indicate slight buckling from surface to 480' and ftom the top of the lower log interval (7,260') to _7,500', including buckling from 364' to the 384'. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (>9%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (> 6°r6) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: Camco DS Nipple Minimum I.D. = 2.85" Jt. 14.2 @ 511 Ft. (MD) Camco D Nipple Minimum I.D. = 2.77" Jt. 231.2 @ 7,516 Ft. (MD) No other significant ID restrictions are recorded. Field Engineer. Wm. McCrossan Analyst: HY. Yang Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 fax: (281) 565-1369 E-mail: PDS amemorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~~ ~9</ Jam- ~S~/ • PDS Multifinger Caliper 3D Log Plot ~, _- S Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-26 Date : April 5, 2Q09 Description : Detail of Caliper Recordings Across the Camco DS Nipple at 511' • PDS Multifinger Caliper 3D Log Plot ~, _ , Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2A-26 Date : April 5, 2009 Description : Detail of Caliper Recordings Across the Camco D Nipple at 7,515' • . PDS Report Overview ~~ emu. Body Region Analysis Well: 2A-26 Survey Date: April 5, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L$0 EUE•8Rnd•Mod 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body metal loss body 30 0 2 10 0 0 to 1 to 10 to 1% 10% 20% 20 to 40 to over 40% 85% 85% Number of 'oints anal se d total = 23 pene loss . 1 22 0 5 18 0 0 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 0 0 0 0 0 0 Damage Profile (°,6 wall) ~ penetration body r;,~,;;:. metal loss body 0 50 100 0 8' 15 Bottom of Survey = 17 Analysis Overview page 2 PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf L-80 EUE 8rd Mod Body Wall: 0.254 in Upset Wall: 0.254 in Nominal I.D.: 2.992 in Well: 2A-26 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: April 5, 2009 Joint No. Jt. Depth (Et) I'en. Ulxc~t (Irn.) Pen. Body (Ins.) Pen. % Metal I cis "~ Min. LD• (Ins.) Damage Profile Comments (%wall) 0 50 100 .1 37 U 0.02 8 2.95 P P 1 41 U 0.02 i .00 Sli ht bucklin . 1.1 73 U 0.02 7 ~? 2.98 PUP 1.2 81 t? 0.02 7 r 2.96 P P 51i ht b cklin . 2 89 a 0.02 8 .01 Sli ht bucklin . 3 121 O 0.02 8 3.00 Sli t buc li 4 153 (? 0.0 ~) 1 2.98 51i ht bucklin . 5 185 t? 0.01 (i -1 3.02 Sli ht bucklin . 6 217 t? 0.01 G ,' 2.98 Sli ht bucklin . 7 249 t? 0.02 7 2.99 Sli ht bucklin . 8 281 U 0. 2 9 s 3.01 Sli ht bucklin . 31 U 0.0 7 ~ .99 Sli t bucklin . 1 344 t? 0.02 7 3 3.00 Bucklin . 11 76 t? 0.0 7 ? 2.99 Bucklin . 12 40 t? 0.02 8 4 3.00 Sli ht bucklin . 13 440 t? 0.0 7 ~ .99 Sli t bucklin . 14 471 U ,02 > 3.01 Sli ht bu kli 4. 50 U 0. 1 5 5 3.00 PU 14.2 511 U 0 U U 2.85 3.5" Cameo DS Ni 14. 514 t1 0.01 4 t) 3.00 PUP 1 0 t) 0.02 8 (~ 3.0 16 552 t? 0.02 7 6 3.01 7 5 4 U 0.0 7 1 3.00 _ Penetration Body Metal Loss Body Page 1 w~ r ~r rt r~ r r r r r r ~^ir ~r . ^^r r r r ~~ PDS Report Cross Sections ~- Well: 2A-26 Survey Date: April 5, 2009 Field: Kuparuk Tool Type; UW MFC 24 No. 218370 Company; ConocoPhitlips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3~pf L•80_EUE Srd Mod Analyst HY. Yang Cross Section for Joint 14.2 at depth 511.27 ft Tool speed = 43 Nominal ID = 2.992 Upset OD = 3.500 Remaining wall area = 100 In upset region Tool deviation = 8 ° Finger 3 Projection = -0.101 ins Camco DS Nipple Minimum I.D. = 2.85 ins. HIGH SIDE = UP •i Cross Sections page 1 PDS Report Overview ~ ~~. Body Region Analysis Well: 2A-26 Survey Date: April 5, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218370 Cornpany: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: IiY. Yan Tubing: Nom.OD Weight Grade L~ Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 93 f L-80 EUE 8rd Mod 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (%wall) ~ penetration body ~~- metal loss body 20 10 0 0 to 1 to 10 ro 20 ro 40 ro over 1% 10% 20% 40% 85% 85% Number of'oints anal se d total = 14 pene. 1 13 0 0 0 0 loss 5 9 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole /pons pitting corrosion corrosion corrosion ible hde Number of 'oints dama ed total = 0 0 0 0 0 0 Damage Profile (°~ wall) ~ penetration body metal loss body 0 50 100 ooc GLM 5 Bottom of Survey = 232.3 Analysis Overview page 2 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE 8rd Mod Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 2A-26 Kuparuk ConocoPhillips Alaska, Inc. USA April 5, 2009 Joint No. Jt. Depth (Ft.) i'~~n. Ulric~t (Ins.) Pen. Body (Ins.) Penn. % tilc~lal I c~tis °d, Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 22 7260 O 0.02 7 .99 Sli ht b cklin . 226 7292 C) 0.0 7 _' .9 li t b klin . 2 7 7322 U 0.02 i :' 2.97 Sli ht bucklin . 28 7354 t~ 0.02 Z 2.97 Sli ht bucklin . 2 9 7386 I~ 0.02 F3 2.97 Sli ht bucklin . 230 7418 U 0.02 £3 1 3. 0 Sli ht buck in . 2301 7450 U 0.02 i I) .94 PUP 230.2 7456 U 0 0 (1 N A L 5 Latch ~ 5:00 23 .3 7 9 t) 0. 1 5 U .98 PUP 23 7475 U 0.01 6 ~ .97 Sli h c i 231.1 7507 (~ 0.01 ~ ~ .94 P P 231.2 7515 t) 0 0 0 2.77 3.5" Camco D i le 231.3 7518 0 .01 6 U 2.97 PUP 232 7524 O 7 2 3.00 2.1 7556 ~) 0 2 £3 t ~ 2.92 UP 32.2 7564 t~ 0 O U 2.99 Baker 80-40 PBK w eal Assembl 32.3 7583 (~ 0 O u A TOP OF LI E Penetration Body Metal Loss Body Page 1 __ `~, PDS Report Cross Sections ~~ Well; 2A•26 Survey Date: April 5, 2009 Field: Kuparuk Tool Type; UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 EUE 8rd Mod_ Analyst; HY. Yana Cross Section for Joint 231.2 at depth 7515.61 ft Tool speed = 43 Nominal ID = 2.992 Upset OD = 3.500 Remaining wall area = 100 In upset region Tool deviation = 25 ° Finger 24 Projection = -0.122 ins Camco D Nipple Minimum I.D. = 2.77 ins. HIGH SIDE = UP • s Cross Sections page 1 ~. KUP 2A-26 COI'1000P~'11~~1EJ5 WeN Attributes Max A Ie 8 MD TD Al:~tihn. Cn w ° °n° W 501032057500 KUPARUK RIVER UNIT PRODUCING 51.97 4.162 8,210 . ... ~ .. Commctll N46 ipgy Dah Mnota[inn Date 103ii'd tltJ gRgeese 44.07 NA74cER. 38 NIPPLE. S'It GAS LIFT. 2.841 GAS LIFT, 5,637 GAS LIFT, 6 832 GAS UFT, 7458 NIPPLE, 7 575 LOCATOR, 1.564 SEAL ASSY. T.564 1 38 IV1l.1VI[C JI IMV{.IA I IVIY placed 99m1041k 011620 Cer6olite into fartnatlan W/Bpps stage In perf5 LINER, 7 5288206 ro, e2io • ConocoPhillips Alaska,inc. FINAL WELL REPORT MUDLOGGING DATA • Kuparuk River Unit 2A-26 Provided by: ~~ EPOCH Approved by: Jennifer A. Head Compiled by: Larry Resch Tollef Winslow Josh Dubowski Date: 1 /18/2009 Distribution: 2/16/2009 ~`~ - c o~~r 1~~~ a • • Conoco~illips Ak'~Ska. InC. 2A-26 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW .... 1.1 Equipment Summary .......................... 1.2 Crew .................................................... 2 WELL DETAILS ......................................... 2.1 Well Summary ..................................... 2.2 Hole Data ............................................ 3 GEOLOGICAL DATA ................................. 3.1 Mud Log Summary .............................. 3.2 Connection Gas Summary .................. 3.3 Trip/Wiper Gas Summary ................... 3.4 Sampling Program /Sample Dispatch 4 DRILLING DATA ........................................ 4.1 Daily Activity Summary :...................... 4.2 Survey Data :....................................... 4.3 Bit Record ........................................... 4.4 Mud Record ........................................ 5 MORNING REPORTS ............................... Enclosures: 2"/100' Formation Log (MD and TVD) 2"/100' Gas Ratio Log (MD and TVD) 2"/100' LWD / Lithology Log (MD and TVD) 2"/100' Drilling Dynamics Log (MD and TVD) ~~~C~ ................. 3 ................. 3 ................. 3 ................. 4 ................. 4 ................. 4 ................. 5 ................. 5 ................. 7 ................. 7 ................. 8 ................. 9 ................. 9 ...............12 ...............15 ...............16 ...............19 2 Conocci~iilips waste. ~~. 2A-26 • 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary • C Parameter Equipment Type /Position Total Downtime Comments QGM Agitator (Mounted in possum Ditch as g belly) Flame ionization total gas & 0 chromato rah . Effective Circulating Density From Sperry-Sun 2080' to TD 0 ECD Hook Load / Wei ht on bit Totco Sensors 0 Mud Flow In Totco Sensors 0 Mud Flow Out Totco Sensors 0 Mudlogging unit computer HP Compaq Pentium 4 (X2, DML & 0 s stem Ri watch Mudlogging unit DAC box In-unit data collection/distribution 1 day Unit was damaged in center shi in . Pit Volumes, Pit Gain/Loss Totco Sensors 0 Pum Pressure Totco Sensors 0 Pum stroke counters Totco Sensors 0 Totco Well Monitoring Totco Sensors 0 Com onents Rate of enetration Totco Sensors 0 RPM Totco Sensors 0 Tor ue Totco Sensors 0 1.2 Crew Unit Type Arctic Unit Number ~ ML030 Mudloggers Years Days Sample Catchers Years Days Technician Days Lar Resch 5.5 16/23 Steve Franzen .5 20/23 Allen Williams 2/23 Tollef Winslow 1 23/23 James Chapman .5 20/23 Joshua Dubowski 1 7/23 '' Years experience as Mudlogger "2 Days at wellsite between rig up and rig down of logging unit. ~i E~~~H ConocoPhillips ~~~; ~~. 2A-26 r 1 L~ 2 WELL DETAILS 2.1 Well Summary Well: KRU 2A-26 API Index #: 50-103-20575-00 Field: Kuparuk River Unit Surface Co-Ordinates: 776' FSL, 227' FWL Sec. 13 T11 N R9E. Borough: North Slope Borough Primary Targets: A4 Sand: 7828 'MD, 5907' TVDSS A3 Sand: 7856' MD; 5932 TVDSS State: Alaska Primary Target Depth: 8210' MD/6418'TVD Rig Name /Type: Doyon 15/Arctic/Triple TD Depth: 8210' MD/6418'TVD Spud Date: 12/30/2008 Ground Elevation: PAD 92.1' MSL TD Date: 1/18/2009 KB Elevation: RKB 132.5' MSL Days Drilling: 19 TD Formation: Below the A3 sand Completion Status: Days Evaluating: none Classification: Production • 2.2 Hole Data Maximum De th Shoe De th FIT Hole TD Mud Dev. Casing/ (ppg) Section MD TVD Formation Weight o. (inc) Liner MD TVD MD (ft) (ft) (ppg) (ft) (ft) ft Surface 3149' 2805' West Sak 9.2-9.3 43.61 10 3/" 3149' 2805' 16.2 Intermediate 7835' 5743' A4 sand 11.8 20.49 7 5/8" 7796' 6607' 14.4 Production 8210' 6418' siltstone 12.8 18.66 4'/: 8210' 6418' • ~~~~~ Conocci~i{bps ~5~; ems. 2A-26 • 3 GEOLOGICAL DATA 3.1 Mud Loa Summary K1 7609' to 7705' MD (5840' TO 5927' TVD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Avera a Maximum Minimum Avera e 116 7.6 53 978 46 181 This interval is dominated by a sandstone that is light gray to pale yellowish brown to brown to very pale orange; fine grain; generally well rounded to sub rounded in part; very good to moderate sphericity; very well sorted to occasionally fair; generally clean with no visibly apparent matrix; occasionally slightly argillaceous in part; dominate grain support with good to very good visible porosity; no hydrocarbon odor from samples; oil is visible both on cuttings and between grains in pore spaces; up to 80% bright gold to dull yellow fluorescence; immediate bursting white to bluish white cut. Glauconite is common throughout the interval. C Sand. 7705' to 7750' MD (5927' TO 5968' TVD) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 120 8 52 829 32 436 This interval is dominated by sand and sandstone. The sandstone coloration is due to a honey brown and amber oil stain; light grayish white to milky white; generally very fine grain, locally fine grain; well rounded to rarely sub-rounded, often extremely well rounded; good to very good sphericity; very well sorted; generally unconsolidated or disconsolidated in samples, but friable and poorly consolidated cuttings are common; noncalcareous; entirely grain supported; no matrix component indicated; good to excellent visible porosity and permeability; well defined cuttings often exhibit oil in situ and clearly visible in pore spaces; no visible evidence of secondary clay infill; samples dominated by translucent ,transparent and matte quartz; samples through interval exhibit up to 10%glauconite as light green to moderate green, well rounded fine grain clasts, often mottled with medium light gray material; gross samples exhibit oil within pore spaces, on unconsolidated quartz grains, and floating on samples; strong hydrocarbon odor noticed at shaker, in pits and in washed and processed samples; gross samples exhibit almost 100% bright yellow to straw yellow fluorescence with generous bluish white solvent reaction. Kuparuk B. 7750' to 7831' MD (5968' TO 6041 v' TVDI Drill Rate (ft/hr Total Gas units) Maximum Minimum Avera a Maximum Minimum Avera e 68 11 29 590 26 199 This interval is dominated by sand and sandstone. The sandstone coloration is due to a honey brown and amber oil stain; light grayish white to milky white; generally very fine grain, locally fine grain; well rounded to rarely sub-rounded, often extremely well rounded; good to very good sphericity; very well sorted; generally unconsolidated or disconsolidated in samples, but friable and poorly consolidated cuttings are common; noncalcareous; entirely grain supported; no matrix component indicated; good to excellent visible porosity and permeability; well defined cuttings often exhibit oil in situ and clearly visible in pore spaces; no visible evidence of secondary clay infill; samples dominated by translucent ,transparent and matte quartz; samples through interval exhibit up to 10%glauconite as light green to moderate green, well rounded fine grain clasts, often mottled with medium light gray material; gross samples exhibit oil within pore spaces, on unconsolidated quartz grains, E~Q~1Z ConocoPhillips ~5~. ~~. 2A-26 • and floating on samples; strong hydrocarbon odor noticed at shaker, in pits and in washed and processed samples; gross samples exhibit almost 100% bright yellow to straw yellow fluorescence with generous bluish white solvent reaction. A4 Sand. 7831' to 7858' MD 6041' TO 6066v' TVD • • Drill Rate ft/hr) Total Gas (units Maximum Minimum Avera a Maximum Minimum Avera e 51 0.3 40 1281 164 503 This interval is dominated by sand and sandstone. The sandstone coloration is due to a honey brown and amber oil stain; light grayish white to milky white; generally very fine grain, locally fine grain; well rounded to rarely sub-rounded, often extremely well rounded; good to very good sphericity; very well sorted; generally unconsolidated or disconsolidated in samples, but friable and poorly consolidated cuttings are common; noncalcareous; entirely grain supported; no matrix component indicated; good to excellent visible porosity and permeability; well defined cuttings often exhibit oil in situ and clearly visible in pore spaces; no visible evidence of secondary clay infill; samples dominated by translucent ,transparent and matte quartz; samples through interval exhibit up to 10% glauconite as light green to moderate green, well rounded fine grain clasts, often mottled with medium light gray material; gross samples exhibit oil within pore spaces, on unconsolidated quartz grains, and floating on samples; strong hydrocarbon odor noticed at shaker, in pits and in washed and processed samples; gross samples exhibit almost 100% bright yellow to straw yellow fluorescence with generous bluish white solvent reaction. A3 Sand. 7858' to 7900' MD (6066' TO 6418' TVD) Drill Rate ft/hr Total Gas units Maximum Minimum Avera a Maximum Minimum Avera e 64 38 52 1002 238 555 The sand is unconsolidated; uniformly upper fine grained to lower fine grained; grains demonstrate moderate to low sphericity and angular to subrounded rounding; no cement as the grains are unconsolidated; sand is well sorted to very well sorted; texturally, the sand is immature but compositionally the sand is mature as it is 100% quartz; quartz is translucent, however about 70% of the grains across the interval are oil stained a light honey color; no fossils or accessory minerals; porosity and permeability of the sand is visually estimated to be good; at the beginning of the interval an oil sheen was noted on the sample, sample emits an oil odor; fluorescence is a sandy yellow with a blooming bluish white cut when solvent is added. ~^ ~~~CL7 ConocoPftillips AI~SIGa, ~fSC. 2A-26 • 3.2 Connection Gas Summary 1 unit = 0.05% Methane Equivalent Note: No connection gasses were observed Depth (ft) Background Units MD/TVD Un t Above Background ( s) 7700' 110 357 8149' 51 36 3.3 Trip/Wiper Gas Summary 1 Unit = 0.05% Methane Eauivalent Depth (ft) M D/TVD Trip to (ft) MD/TVD Maximum Gas Units Downtime hours 6895' MD surface 440 24.1 8210' MD n/a 241 1.75 LJ IL^^ ~~~C~ Con©coPhiilips Alaska. Inc. 2A-26 • 3.4 Sampling Program /Sample Dispatch Set Sample Type Frequency Interval Dispatched To: ConocoPhillips Alaska, Inc. ABV 100 ' ' ' 619 East Ship Creek Ave. Processed: 50 -7500 3200 Suite 102 1 and 2 Washed and 30' ' 7550' - 7600' ' ' Anchorage, Ak 99502 Dried 10 7600 - 8210 Attn: D. Przywojski 907 263-4859 Sample frequency may be altered according to conditions. • • ~ EPOCH ConocciPhillips Alaska, Inc.. 2A-26 • 4 DRILLING DATA 4.1 Daily Activity Summary: December 31, 2008 Spud well and drill to 226 ft. Pull out of hole; pickup remaining BHA. Run to bottom and drill ahead from 226 ft to 2164 ft. January 1, 2009 Drill ahead from 2164 ft to casing point at 3150 ft with no problems. Circulate bottoms up. Pump weighted sweep. Short trip; run back to bottom. Pump weighted sweep; circulate and condition hole for casing. Pulling out of the hole for casing at report time. January 2, 2009 Complete trip out of hole. Download LWD; lay down BHA. PJSM and rig up to run 10-3/4" casing. Run 10-3/4" casing to base of permafrost. Circulate and condition mud. Continue trip in hole from base of permafrost to 2872 ft. Continue running in hole from 2872 ft. with pumps due to poor displacement. Tag bottom at 3154 ft. Stage pump to 7 bpm without losses. Circulate and condition mud to program specifications. Perform cement job: Pump 5 bbls water, 75 CW-100, 75 bbls 10.5ppg mud push, 492 bbls lead, 94 bbls 12.Oppg tail, 20 bbls water. Bump plug at 2751 strokes. Record 200 bbls of cement at surface. Pick up/clean up and start to nipple down diverter. January 3, 2009 Continue to nipple down diverter. Prep casing for HOT head and let cool down slowly. Clean pits. Bring on 580 • bbls of new LSND mud. Nipple up. January 4, 2009 Continue nippling up; test BOP's. Pick up BHA #2. Test LWD, blow down top drive, load nukes, continue picking up BHA. Run in hole to 2970 ft: Fill pipe and test MWD. Continue trip in hole from 2970 ft to 3045 ft; circulate bottoms up. Rig up test equipment and conduct casing shoe test. Drilling on cement above float collar. January 5, 2009 Drill out float equipment, shoe, 20 foot of formation. Circulate bottoms up. Displace to LSND. Perform FIT test. Obtain pressure while drilling baseline. Drill ahead from 3170 ft to 5160 ft. January 6, 2009 Drill ahead from 5160 ft to 5444 ft5. Pick up weight increases 30k with increasing torque. Circulate bottoms up while working pipe. Pump 40 bbl 10.3ppg 250 vis sweep; observe slight increase in cuttings. Torque drops. Drill ahead from 5444 ft to 6740 ft. Pump 40 bbl 10.3ppg 250 vis sweep. Pump pressure drops 300 psi as soon as sweep left bit. ECD's dropped from 10.55 to 10.32 ppg; observe slight increase in cuttings at shaker. Pull out of hole from 6895 ft for MWD. Back ream from 4095 ft to shoe. January 7, 2009 Continue to back ream out of hole to 2782 ft. Finish trip on elevators. Pick up/Make up BKA #3. Run in hole to 3136 ft. Circulate bottoms up at shoe. Continue trip in hole, washing two stands to bottom. Epoch records 440 units of trip gas at 24.1 hours down time. Drill ahead from 6895 ft to 7090 ft. January 8, 2009 Drill ahead from 7090 to 7495'MD. Circulate 2+ bottoms up. ECD decreased from 10.1 to 8.94ppg. Short trip and return to bottom. Epoch records 982 units of wipertrip gas. Pump 50 bbl 10.3ppg 250 vis sweep; observe significant increase of cuttings at shaker. Weight up to 9.5ppg as a result of wiper trip gas amount. Pump dry • job and pull out of hole. Lay down BHA. Change rams to 7-5/8". Currently testing BOP's. ~^ ~~~~~ 9 Conoc~hillips Alaska,lnc. 2A-26 Januarv 9, 2009 Complete BOP tests. Rig up and run in hole with 7-5/8" casing while drilling tools to 3011'MD. Circulate bottoms up at 250 gpm. Continue trip in hole, stopping to circulate bottoms up at 5409 ft, 5830 ft and 7488 ft. Epoch records 407 units of trip gas maximum at 26.5 hours down time. Perform LOT at 7488'MD to 12.2 ppg EMW. Drill ahead with 7-5/8" casing to 7635 ft. Januarv 10, 2009 Drill ahead with 7-5/8" casing from 7635 ft to 7656 ft. Circulate bottoms up; circulate and condition. Perform second LOT at 7656 ft: EMW = 14.4ppg. Drill ahead with casing from 7656 ft to 7695 ft. Record 963 units of gas: Circulate bottoms up; circulate out gas. Drill ahead with 7-5/8" casing from 7695 ft to 7780 ft: Circulate bottoms up. Drill ahead with 7-5/8" casing from 7780 ft to 7835 ft and displace to 11.5 ppg WBM. Gas increases to over 3000 units; weight up to 11.8ppg while reciprocating pipe at report time. Januarv 11, 2009 Continue weighting up to 11.8 ppg while reciprocating casing string. Flow check well with 11.8 ppg in/out: Well flowing. Circulate bottoms up. Casing parts while circulating. Lay down 1 joint of 7-5/8" casing; shut in well. Build kill weigh mud; pump 15.8 ppg mud. Monitor well. Pump 15.7 ppg kill weight mud. Monitor well: Still flowing. Pull out of hole with only 13 joints 7-5/8" casing. Monitor well: Flowing. Close blind rams. Change out pipe rams and test hydril and pipe rams. Run in hole with fishing BHA. Circulate until mud 12.0 in and out. Pull fish free. Epoch records 2487 units of gas maximum at 12.1+ in/out. Circulate out gas. Januarv 12, 2009 Continue to circulate out gas while reciprocating casing from 7825 ft to 7815 ft. Monitor well: Well flowing slightly. Circulate bottoms up and weight up to 12.3 ppg. Epoch records maximum 2769 units at 1.8 hours down time. Monitor well: Well is static. Short trip out of hole with fish; lay down damaged casing. Drop carbide and dye twice with no indication of getting either back to surface. Monitor well: Well flowing slightly. Run in hole with replaced 7-5/8" casing. Circulate and condition hole. Epoch records maximum gas of 2291 units at 4.0 hours down time. Continue to circulate with 12.3 ppg mud in/out while rigging up cementers. Gas steadies to 125 to 150 units. Pump 40 bbls mud push, 84 bbls of cement; bump plug with 343 of 12.3 ppg LSND. Maximum gas recorded during cement operations was 171 units. Januarv 13, 2009 Cement lines were blown down, and cement head rigged down. ND riser and raise the stack. Cut casing, NU stack, and c/o rams. Perform a LOT and freeze protect 10 3/4" X 7 5/8" annulus. Test BOPE and prepare to LD 5" DP. Januarv 14.2009 Had safety meeting for LD 5" drill pipe out of derrick. The rig was down for repairing pipe skate. Made up BHA #5. Picked up 4" DP and running in the hole @ report time. Januarv 15. 2009 Continued to RIH with 4" DP. Circulated bottom's up @ 7645' MD then rigged up and tested 7 5/8" Casing. Washed down and drilled out shoe & cement to 7,802' MD. CBU & weight-up to 12.5 ppg. CBU again with 1670 units of gas, increased fluid density to 12.8 ppg. CBU, pumped dry job and POOH @ report time. Januarv 16. 2009 Continued to pump out of hole. Cleaned out junk basket & monitored well (static). Held safety meeting for rigging up wireline unit and tools. Ran in hole with GYRO and logging @ report time. Januarv 17, 2009 Continued to log the well on wireline. Monitored well periodically (static). Finished wireline operation with assembly #5. POOH with wireline, rigged down, and picking up BHA @ report time. Januarv 18, 2009 • Picked up BHA and loaded Nuclear Scoures as per Sperry Sun. TIH and CBU @ 2500' MD and 5000' MD. ~^ E~7~~`H 10 Gonoc~hillips 2A-26 • RIH to bottom, drilled to 7855' MD and circulated out 1,638 units of gas. Performed Fit test @ 7796' MD with a 15.9 EMW. Drilled ahead to TD @ 8,210' MD and circulated 40 bbl 180 vis sweep. Return of 15% increase in cuttings at surface. January 19 2009 Prepare for Cement Job: Black Water Pill (40 bbls) and Retarder Pill (80 bbls). Products used included CF Desco II, SAPP, Vis, Sodium Bicarbonate, and Citric Acid. Treated active system to lower pH to neutral range. • E~~~H 11 Conoc Phillips Alaska,lnc. 2A-26 4.2 Survey Data: 4.2.1 Surface Hole: 13-1/2" Drilled Section • Measured Depth ft Incl. (deg) Azim. (deg) True Vertical Depth (ft) Northings (ft){+N/-S} Eastings (ft){+E/-W} Vertical Section ft Dogleg Rate /100ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 40.35 0.00 0.00 40.35 0.00 0.00 0.00 0.00 100.00 0.54 354.52 100.00 0.28 -0.03 -0.21 0.91 168.00 0.64 358.28 168.00 0.98 -0.07 -0.71 0.16 263.00 1.61 150.53 262.99 0.35 0.57 0.19 2.31 355.00 4.06 151.40 354.87 -3.64 2.77 4.50 2.66 445.00 5.17 144.98 444.57 -9.76 6.62 11.48 1.36 500.00 7.00 140.84 499.26 -14.39 10.16 17.22 3.42 600.00 10.46 137.12 598.09 -25.77 20.19 32.30 3.50 665.00 12.24 137.82 661.81 -35.20 28.83 45.05 2.75 730.00 12.58 141.90 725.30 -45.87 37.82 58.89 1.45 781.80 13.65 141.44 775.75 -55.09 45.11 70.50 2.08 877.15 15.67 143.43 867.99 -74.23 59.80 94.27 2.18 972.17 15.61 144.50 959.49 -94.95 74.87 119.39 0.31 1067.60 15.59 145.86 1051.40 -116.01 89.52 144.43 0.38 1163.12 18.10 144.78 1142.82 -138.76 105.29 171.44 2.65 1257.95 19.25 144.84 1232.65 -163.58 122.78 201.12 1.21 1353.32 20.98 142.88 1322.20 -190.05 142.14 233.28 1.95 1447.78 24.16 141.92 1409.42 -218.75 164.28 269.01 3.39 1543.17 26.04 140.60 1495.80 -250.30 189.61 309.01 2.06 1640.00 28.93 137.53 1581.69 -284.01 218.92 353.41 3.32 1734.78 30.18 137.11 1664.14 -318.38 250.61 400.00 1.34 1829.59 31.39 138.75 1745.59 -354.40 283.12 448.31 1.55 1924.51 34.49 139.26 1825.24 -393.36 316.96 499.60 3.28 2019.12 33.96 138.35 1903.47 -433.40 352.01 552.50 0.78 2114.51 35.14 138.12 1982.03 -473.75 388.04 606.34 1.24 2210.11 34.92 138.30 2060.32 -514.67 424.61 660.95 0.25 2305.64 34.98 138.68 2138.62 -555.65 460.88 715.39 0.24 2400.65 34.74 138.35 2216.58 -596.33 496.85 769.41 0.32 2496.32 35.19 137.81 2294.98 -637.12 533.48 823.98 0.57 2591.05 34.95 135.47 2372.52 -676.69 570.84 878.27 1.44 2686.56 35.68 134.73 2450.45 -715.80 609.82 933.43 0.89 2781.07 37.71 136.82 2526.23 -756.28 649.18 989.81 2.52 2877.08 39.82 136.57 2601.09 -800.02 690.41 1049.77 2.20 2970.97 41.41 135.73 2672.36 -844.09 732.76 1110.77 1.79 3066.45 42.42 135.46 2743.41 -889.65 777.39 1174.46 1.07 3103.62 42.59 134.60 2770.81 -907.42 795.14 1199.55 1.63 3133.79 43.61 134.36 2792.84 -921.86 809.85 1220.16 3.42 3214.64 46.12 133.77 2850.14 -961.52 850.83 1277.17 3.15 3310.27 48.54 133.00 2914.95 -1009.81 901.93 1347.47 2.60 3404.58 48.66 132.78 2977.32 -1057.96 953.76 1418.21 0.22 3499.42 48.73 134.30 3039.92 -1107.03 1005.40 1489.44 1.21 Li E~~~H 12 Conoc~illips ~s~. i~~. 2A-26 • 4.2.2 Intermediate Hole: 9-7/8" Drilled Section • ~, Measured Depth ft Incl. (deg) Azim. (deg) True Vertical Depth (ft) Northings (ft){+N/-S} Eastings (ft){+E/-W} Vertical Section ft Dogleg Rate °/100ft 3595.25 49.70 130.01 3102.53 -1155.69 1059.18 1561.97 3.54 3690.17 48.21 129.43 3164.86 -1201.44 1114.24 1633.46 1.64 3785.38 48.31 128.91 3228.25 -1246.31 1169.32 1704.38 0.42 3880.71 47.94 130.18 3291.88 -1291.50 1224.06 1775.26 1.07 3976.08 49.43 127.48 3354.85 -1336.39 1279.86 1846.71 2.64 4066.32 50.83 126.54 3412.70 -1378.08 1335.17 1915.64 1.75 4162.40 51.97 127.46 3472.64 -1423.27 1395.13 1990.36 1.40 4261.03 51.87 125.26 3533.48 -1469.29 1457.64 2067.53 1.76 4357.35 51.59 127.58 3593.14 -1514.18 1518.49 2142.70 1.91 4452.29 51.54 131.42 3652.17 -1561.47 1575.85 2216.93 3.17 4547.48 51.34 131.68 3711.50 -1610.84 1631.56 2291.35 0.30 4642.15 51.02 132.06 3770.85 -1660.07 1686.48 2365.10 0.46 4737.71 50.83 131.30 3831.09 -1709.40 1741.89 2439.28 0.65 4834.31 51.79 131.74 3891.47 -1759.38 1798.34 2514.66 1.06 4929.79 51.65 133.09 3950.62 -1809.93 1853.67 2589.61 1.12 5023.16 51.51 133.41 4008.65 -1860.06 1906.96 2662.76 0.31 5118.18 51.63 129.93 4067.72 -1909.53 1962.55 2737.17 2.87 5212.97 51.27 130.30 4126.79 -1957.29 2019.24 2811.23 0.49 5307.48 51.54 129.74 4185.75 -2004.79 2075.81 2885.02 0.54 5403.19 51.24 130.41 4245.47 -2052.94 2133.04 2959.73 0.63 5496.39 50.78 131.36 4304.11 -2100.35 2187.80 3032.14 0.93 5593.58 51.90 130.29 4364.83 -2149.96 2245.23 3107.99 1.44 5689.22 51.57 130.18 4424.06 -2198.47 2302.56 3183.01 0.36 5783.79 51.40 130.04 4482.95 -2246.14 2359.15 3256.94 0.21 5879.31 51.44 130.07 4542.51 -2294.19 2416.31 3331.54 0.05 5973.56 51.40 130.22 4601.29 -2341.69 2472.63 3405.15 0.13 6068.59 51.18 130.56 4660.72 -2389.74 2529.11 3479.24 0.36 6164.24 50.81 130.69 4720.92 -2438.14 2585.52 3553.53 0.40 6259.67 50.91 131.07 4781.16 -2486.58 2641.48 3627.51 0.33 6354.88 50.90 132.01 4841.20 -2535.58 2696.79 3701.39 0.77 6449.09 49.18 130.18 4901.70 -2583.05 2751.19 3773.57 2.36 6544.98 47.61 128.94 4965.37 -2628.72 2806.46 3845.16 1.90 6640.46 45.16 128.72 5031.23 -2672.06 2860.31 3914.13 2.57 6735.52 41.43 129.09 5100.41 -2712.99 2911.03 3979.17 3.93 6830.64 38.66 130.42 5173.22 -2752.11 2958.09 4040.28 3.05 6901.71 37.13 129.52 5229.30 -2780.15 2991.53 4083.89 2.29 6996.47 34.09 130.37 5306.33 -2815.56 3033.84 4138.99 3.25 7091.56 30.88 130.50 5386.53 -2848.68 3072.71 4190.02 3.38 7186.90 27.97 133.71 5469.57 -2880.03 3107.48 4236.83 3.47 7282.13 25.41 132.46 5554.65 -2909.26 3138.70 4279.60 2.75 7328.86 25.17 132.80 5596.90 -2922.78 3153.39 4299.56 0.60 7377.27 24.92 132.14 5640.76 -2936.61 3168.51 4320.06 0.77 7448.95 24.50 133.23 5705.88 -2956.93 3190.53 4350.02 0.86 7490.00 24.50 133.23 5743.23 -2968.58 3202.94 4367.04 0.00 7590.00 22.27 133.85 5834.99 -2996.12 3231.58 4406.77 2.27 ~i E~a~H 13 Conacci~tillips Alaska,lnc. 2A-26 .7 7690. 00 20 .78 133. 00 5928 .01 -3021. 35 3258. 22 4443 .45 1.52 7770. 00 20 .49 134. 15 6002 .88 -3040. 78 3278. 65 4471 .64 0.62 7828. 61 19 .31 135. 67 6057 .99 -3054. 86 3292. 78 4491 .57 2.2 4.2.3 Production Hole: 6-3/4" Drilled Section • • Measured Depth ft Incl. de Azim. de True Vertical De th ft Northings ft +N/-S Eastings ft +E/- Vertical Section ft Dogleg Rate o/100ft 7924.43 19.21 135.69 6148.45 -3077.47 3314.86 4523.13 0.1 8019.42 19.00 136.05 6238.21 -3099.79 3336.51 4554.17 0.25 8111.41 18.72 136.03 6325.26 -3121.19 3357.15 4583.86 0.3 8172.2.0 18.66 137.17 6382.84 -3135.34 3370.54 4603.29 0.61 8210.00 18.66 137.17 6418.65 -3144.21 3378.76 4615.35 0 E~~~H 14 Con©coP~Ftillips Alaska inc. 2A-26 • 4.3 Bit Record Bit Size Type Ser. No. Jets/TFA In Out Ftg. Hrs. Wear Reason 1 13 1/2" HC MX-1 5154408 3X15, 1X13/ 147' 3150' 3003' 15.3 xxxxx Csg. Pt. 0.6474 2 9 7/8" DTX619M610 123722 6x14 3150' 7495' 4345' XX N/A Csg. Pt. 2rr1 9 7/8" DTX619MB10 123722 6x14 7495' 7835' 340' XX N/A Csg. Pt. 1-1-CT- 5 6-3/4" HCD 4052 7014648 5x14/0.752 7835' 8210' 375' 9.5 A11-X-EI- TD N D-TD E~~~l~ 15 r CQt'rK~~I~t~15 aUaska, ~~. 2A-26 4.4 Mud Record Contractor: MiSwaco-Spud Mud Surface Holey 13-1 /2" Drilled Section Date Depth MW lPP9) FLT ~ oF) VIS (s/qt) PV YP Gels FL FC Sols ("~o) O/VU Ratio Sd (%) MBT pH CI- (ml/I) Ca+ (ml/I) 12/31/2008 850 9.3 60 350 54 56 65/85/127 9.0 3/- 6.25 2/92 0.25 28 9.0 1100 160 1970 9.2 64 155 32 44 44/75/100 8.6 3/- 7.00 1/92 0.30 25 8.9 600 96 1 /1 /2009 3150 9.6 80 181 47 54 20/71 /92 5.8 3/- 10.00 1 /89 0.30 30 8.5 450 40 3150 9.2 72 54 21 17 6/22/35 6.8 3/- 8.00 1 /91 0.30 20 8.4 500 40 1/2/2009 3150 9.3 72 101 41 38 5/62/75 6.8 3/- 8.00 1/91 0.30 20 8.4 500 40 3150 9.3 70 45 20 12 2/4/6 6.8 3/- 8.00 1/91 0.30 20 8.5 500 40 1 /3/2009 3150 9.2 60 51 16 14 7/8/ 7.8 1 /- 4.00 1 /95 - 3 10.2 120 80 1/4/2009 3150 9.3 70 43 20 10 2/4/6 6.8 3/- 8.00 1/91 0.30 20 8.5 500 40 3060 9.2 60 51 11 18 7/8/10 7.2 1 /- 4.00 1 /91 - 3 10.1 200 120 ~^ El" ~~1Z 16 • Contractor: MiSwaco--LSND Intermediate Holey 9-7/8" Drilled Section ~OI'1OCO1'hi~~l Alaska,lnc, 2A-26 Date Depth MW (Pp9) FLT ~ oF) VIS (s/qt) PV YP Gels FL FC Sols (%) O/W Ratio Sd (%) MBT pH CI- (ml/I) Ca+ (ml/I) 1 /5/2009 4022 9.2 76 45 12 20 6/10/13 6.1 1 /- 5.00 1 /95 - 7.50 9.7 350 70 5159 9.2 70 41 12 18 8/12/14 6.0 1 /- 6.50 1 /93 Tr 16.25 9.4 420 120 1/6/2009 6404 9.2 95 45 15 17 6/12/20 4.1 1/- 7.0 1/93 Tr 20.00 9.6 350 92 6895 9.2 92 44 14 17 6/14/23 4.4 1 /- 7.5 1 /92 Tr 22.50 9.6 380 120 1 /7/2009 6895 9.2 82 44 10 16 5/12/21 4.3 1 /- 7.0 1 /92 Tr 18.75 9.5 450 100 7051 9.2 90 45 9 16 5/7/11 4.5 1/- 6.5 1/93 Tr 18.75 9.3 350 120 1/8/2009 7501 9.5 98 42 9 17 5/8/16 3.5 1/- 7.0 2/91 Tr 19.50 9.0 350 60 7501 9.5 96 43 9 16 5/8/14 3.6 1 /- 7.0 2/91 Tr 18.00 9.9 350 80 1 /9/2008 7502 9.6 70 46 11 18 6/11 /14 3.6 1 /- 7.0 2/91 Tr 18.00 9.9 350 80 7780 9.6 67 46 10 18 6/10/12 2.4 1 /- 7.0 2/91 Tr 20.00 9.6 320 72 1/10/2009 7800 9.5 41 41 11 15 4/7/12 2.4 1/- 7.0 2/91 Tr 20.00 9.6 320 72 Truck 7781 11.5 48 48 28 19 4/6/8 6.1 1/- 13.0 /87 NA 8.75 10.0 250 24 7835 11.8 55 55 27 19 4/5/7 5.4 1 /- 13.0 1 /87 Tr 10.00 9.5 300 20 1 /11 /2009 7835 11.8 62 60 23 16 5/7/7 3.1 1 /- 14.0 1 /85 Tr 11.25 9.2 250 24 7835 12.1 86 50 18 16 5/6/7 4.0 1/- 14.0 1/85 Tr 10.00 9.1 220 20 1/12/2009 7835 12.3 80 54 17 16 4/6/7 4.0 1/- 16.0 1/83 Tr 10.00 9.1 220 20 7835 12.3 78 54 16 17 4/5/7 3.8 1 /- 14.0 1 /85 Tr 10.00 9.2 240 20 1 /13/2009 7835 12.3 78 50 16 17 4/5/7 3.8 1 /- 14.0 1 /85 Tr 10.00 9.2 240 20 7835 12.3 73 49 16 16 4// 4.0 1 /- 14.0 1 /85 Tr 10.00 9.1 240 20 1 /14/2009 7835 12.0 75 53 17 16 5/6/7 3.8 1 /- 13 1 /86 Tr 7.5 9.1 240 20 7835 12.3 74 54 16 ~ 18 6/8/9 4.1 1/- 13 1/86 Tr 7.5 9.1 240 20 1/15/2009 7835 12.3 72 49 19 17 6/8/10 3.8 1/- 17 1/82 Tr 10 10.2 300 80 7835 12.8 72 52 18 20 7/9/11 4 1/- 17 1/82 Tr 9 10.2 290 80 1/16/2009 7835 12.8 68 52 18 20 7/9/11 4 1/- 17 1/82 tr 9 10.2 290 80 7835 12.8 70 52 19 19 7/9/11 4 1 /- 17 1 /82 tr 8.5 10.2 290 80 1 /17/2009 7835 12.8 76 50 19 19 7/9/10 4 1 /- 17 1 /82 tr 8.5 10.0 290 80 7835 12.8 74 48 21 17 5/6/7 4.8 1 /- 17 1 /82 tr 8 10.2 290 80 EPQCH 17 • Contractor: MiSwaco-Weighted WBM Production Hole: 6-3/4" Drilled Section Conoco fillips m~~~ ~~. 2A-26 Date Depth MW lPp9) FLT ~ oF) VIS (s/qt) PV YP Gels FL FC Sols ("~o) O/VU Ratio Sd ("~o) MBT pH CI- (ml/I) Ca+ (ml/l) 1/18/2009 7855 12.8 68 54 18 21 6/9/11 5.4 1/- 19 1/80 tr 10 9.3 300 80 8210 12.8 80 52 26 22 6/8/10 4.8 1/- 19 1/80 tr 9.5 9.8 300 80 1 /19/2009 8210 12.8 65 58 18 21 7/9/11 4.5 1 /- 19 1 /80 Tr 10 9.3 280 80 8210 12.8 70 55 19 20 6/8/10 4.5 1 /- 19 1 /80 Tr 9.5 7.8 280 80 Abbreviations MW =Mud Weight Gels =Gel Strength Sand =Sand content ECD =Effective Circulating Density FL =Water or Filtrate Loss CI =Chlorides VIS =Funnel Viscosity FC =Filter Cake Ca =Hardness Calcium PV =Plastic Viscosity Sols =Solids O/W =Oil to Water ratio YP =Yield Point FLT =Flow Line Temp EPOCH 18 • • • MORNING REPORTS E~oc~ 19 • r1 • ~ E~~c~ 20 • Daily Report Page 1 of 1 ConocoPhillips Kuparuk DAILY WELLSITE REPORT EPOCH 2A - 26 REPORT FOR Granny, Greener, Head DATE Dec 31, 2008 DEPTH 2164' PRESENT OPERATION Drilling Ahead TIME 2359 hrs YESTERDAY 147 24 HOUR FOOTAGE 2017 CASING INFORMATION 16" @ 147 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 877 15.67 143.43 867.99' 1068' 15.59 145.86 1051.40' SURVEY DATA 1543' 26.04 140.60 1495.80' 2019' 33:96 138.35 1903.47 2496' 35.19 137.81 2294.98' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 13-1/2" HC MX-1 5154408 3X15, 1X13 147 2017 7.4 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 886.5 @ 1364 11.9 @ 2069 199.3 .296.5 FT/HR SURFACE TORQUE 9291 @ 2111 0 @ 1889 4171.8 6763.5 AMPS WEIGHT ON BIT 50 @ 2045 0 @ 1943 12.4 32.3 KLBS ROTARY RPM 0 @ 2164 0 @ 2164 0.0 0.0 RPM PUMP PRESSURE 2594 @ 2143 521 @ 2068 1866.6 2430.9 PSI DRILLING MUD REPORT DEPTH 1970/1855 MW 9.2 VIS 155 PV 32 YP 44 FL 8.6 Gels 44/75/100 CL- 600 FC 3 SOL 7.0 SD 0.3 OIL 1/92 MBL 25 pH 8.9 Ca+ 96 CCI MWD SUMMARY INTERVAL 147 TO Current TOOLS Tri-Cone bit with MWD and LWD. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 160 @ 1433 0 @ 11.7. TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) . 10822. @ 2080 2 @ 1910 1150.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ @ AVG PROPANE (C-3) 0 @ @ CURRENT BUTANE (C-4) 0 @ @ CURRENT BACKGROUND/AVG 50 u PENTANE (C-5) 0 @ @ HYDROCARBON SHOWS Please Reffer to mud log INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 24 hrs: 80% sand and conglomeratic sand, 10% tuffaceous sand, 10% tuffaceous claystone, occasional coal PRESENT LITHOLOGY 2150 ft: 100% sand, slightly conglomeratic DAILY ACTIVITY Spud well and drill to 226 ft. Pull out of hole; pick up remaining BHA. Run to bottom and drill ahead from SUMMARY 226 ft to 2164 ft at report time. EPOCH PERSONNEL ON BOARD Resch, Winslow + 2 SC_ DAILY COST REPORT BY Larry Resch file://C:\Documents%20and%20Settings\EpochAdmin\My%20Documents\My%20 Wells\C... 1 /1 /2009 • Daily Report Page 1 of 2 ConocoPhillips Kuparuk DAILY WELLSITE REPORT EPQ~H 2A-26 REPORT FOR Granny, Greeneer, Head DATE Jan 01, 2009 DEPTH 3150' PRESENT OPERATION POOH for Casing TIME 2359 hrs YESTERDAY 2164' 24 HOUR FOOTAGE 986' CASING INFORMATION 16" @ 147' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2591' 34.95 135.47 2372.52' SURVEY DATA 2781 37.71 136.82 2526.23' 2971' 41.41 135.73 2672.36' 3104' 42.59 134.60 2770.81' 3150p 42.59 134.60 p2804.95' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 13-1/2" HC MX-1 5154408 3X15,1X13 14T 3150' 3003' 15.3 Csg Pt DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 357.7 @ 2208 9.1 @ 2975 235.1 47.1 FT/HR SURFACE TORQUE 13190 @ 2834 1 @ 2847 6026.3 6138.8 AMPS WEIGHT ON BIT 33 @ 2761 1 @ 3113 5.8 0.0 KLBS ROTARY RPM 0 @ 3150.00000 0 @ 3150.00000 0.0 0.00000 RPM PUMP PRESSURE 3129 @ 3146 272 @ 2927 2730.7 2814 PSI DRILLING MUD REPORT DEPTH 3150/2805 MW 9.2 VIS 54 PV 21 YP 17 FL 6.8 Gels 6/22/35 CL- 500 FC 3 SOL 8 SD 0.3 OIL 1/91 MBL 20 pH 8.4 Ca+ 40 CCI MWD SUMMARY INTERVAL 14T TO 3150' TOOLS Tri-cone bit with MWD and LWD. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 709 @ 2669 13 @ 2175 144.7 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 90663 @ 2669 2339 @ 2175 21868.3 CONNECTION GAS HIGH 0 ETHANE (C-2) 1266 @ 3135 2 @ 2638 237.2 AVG PROPANE (C-3) 305 @ 3135 0 @ 35.0 CURRENT BUTANE (C-4) 717 @ 2787 2 @ 2731 97.7 CURRENT BACKGROUND/AVG 20-25U while circulating PENTANE (C-5) 294 @ 2664 3 @ 2640 2.9 HYDROCARBON 100% sample fluorescence, strong odor, oil in SHOWS sample INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 2650-2700MD/2416- 100% unconsolidated well rounded 709 u C-1:90664, C-2: 823, C-3: 200, C-4i: 491, C-4n: --,C- 2452TVD sandstone max 5i: 491, C-5n: 202 LITHOLOGY 90% sandstone, 10% claystone PRESENT LITHOLOGY No new footage drilled past TD. DAILY ACTIVITY Drill ahead from 2164 ft to casing point at 3150 ft with no problems. Circulate bottoms up. Pump weighted sweep. SUMMARY Short trip; run back to bottom. Pump weighted sweep ; circulate and condition hole for casiong. Pulling out of hole for casing at report time. file://C:\Documents%20and%20 Settings\EpochAdmin\My%20Documents\My%20 Wells\C... .172/2009 Daily Report Page 2 of 2 EPOCH PERSONNEL ON BOARD Resch, Winslow + 2 SC DAILY COST REPORT BY Larry Resch file://C:\Documents%20and%20 Settings\EpochAdmin\My%20Documents\My%20 W ells\C... 1 /2/2009 • • Daily Report Page 1 of 1 ConocoPhillips Kuparuk DAILY WELLSITE REPORT ~. EPOCH 2A - 26 REPORT FOR Granny, Greener, Head DATE Jan 02, 2009 DEPTH 3150' PRESENT OPERATION Wait on cement TIME 2359 hrs YESTERDAY 3150' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 14T 10-3/4" @ ? SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE• @ @ PSI DRILLING MUD REPORT DEPTH 3150/2805 MW 9.3 VIS 45 PV 20 YP 12 FL 6.8 Gels 2/4/6 CL- 500 FC 3 SOL 8.0 SD 0.3 OIL 1/91 MBL 20 pH 8.5 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS No tools in hole this period. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY(ppm) SURVEY. METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG n!a PENTANE (C-5) @ @ HYDROCARBON SHOWS No new footage drilled this period. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new footage drilled this period. Complete trip out of hole. Download LWD; lay down BHA. PJSM and rig up to run 10-3/4" casing. Run 10-3/4" casing DAILY to base of permafrost. Circulate and condition mud. Continue trip in hole from base of permafrost to 2872 ft. Continue ACTIVITY running in hole from 2872 ft. with pumps due to poor displacement. Tag bottom at 3154 ft. Stage pump to 7 bpm SUMMARY without losses. Circulate and condition mud to program specifications. Perform cement job: Pump 5 bbls water, 75 CW-100, 75 bbls 10.5ppg mud push, 492 bbls lead, 94 bbls 12.Oppg tail, 20 bbls water. Bump plug at 2751 strokes. Record 200 bbls of cement at surface. Pick up/clean up and start to nipple down diverter at report time. EPOCH PERSONNEL ON BOARD Resch, Winslow + 2 SC_ DAILY COST $3310 REPORT BY Larry Resch file://C:\Documents%20and%20 Settings\EpochAdmin\My%20Documents\My%20 Wells\C... 1 /3/2009 • Daily Report Page 1 of 1 ConocoPhillips Kuparuk DAILY WELLSITE REPORT n EPOCH 2A - 26 REPORT FOR Granny, Greener, Head DATE Jan 03, 2009 DEPTH 3150' PRESENT OPERATION Nipple Up TIME 2359 hrs YESTERDAY 3150' 24 HOUR FOOTAGE 0' CASING INFORMATION 10-3/4" @ 3150' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3150/2805 MW 9.2 VIS 51 PV 16 YP 14 FL 7.8 - Gels 7/8/ CL- 120 FC 1 SOL 4.0 SD OIL 1/95 MBL 3 pH 10.2 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS No tools in hole this period. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a C HROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG --- PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new footage dri lled this period.. DAILY ACTIVITY Continue to nipple down diverter. Prep casing for HOT head and let cool down slowly. Clean pits. Bring on SUMMARY b80 bbls of new LSND mud. Nippling up at report time. EPOCH PERSONNEL ON BOARD Resch, Winslow + 2 SC_ DAILY COST $3410 REPORT BY Larry Resch file://C:\Documents%20and%20Settings\EpochAdmin\My%20Documents\My%20Wells\C... 1 /4/2009 Daily Report Page 1 of 1 ConocoPhillips Kuparuk DAILY WELLSITE REPORT EPOCH 2A-26 REPORT FOR Herbert, Rizek, Greener, Head DATE Jan 04, 2009 DEPTH 3150' PRESENT OPERATION Drilling cement above float collar. TIME 2359 hrs YESTERDAY 3150' 24 HOUR FOOTAGE 0' CASING INFORMATION 10-1/2" @ 3150' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9.875" HYC DTX619MB10 123722 6 X 14/0.902 3150' 0 0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT. DEPTH N/A at report time MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL 3150' TO TOOLS PDC bit with Sperry Drill and LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS n/a CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG n/a PENTANE (C-5) @ @ HYDROCARBON SHOWS No new footage drilled this period. INTERVAL LITHOLOGY/REMARKS GAS .DESCRIPTION LITHOLOGY PRESENT LITHOLOGY No new footage drilled this period DAILY ACTIVITY Continue nippling up; test BOP's. Pick up BHA #2. Test LWD, blow down top drive, load nukes, continue picking up SUMMARY BHA. Run in hole to 2970 ft: Fill pipe and test MWD. Continue trip in hole from 2970 ft to 3045 ft; circulate bottoms up. Rig up test equipment and conduct casing shoe test. Drilling on cement above float collar at report time. EPOCH PERSONNEL ON BOARD Resch, Winslow + 2 SC_ DAILY COST $3310 REPORT BY Larry Resch • file://C:\Documents%20and%20Settings\EpochAdmin\My%20Documents\My%20Wells\C... 1 /5/2009 Daily Report • • Page 1 of I ConocoPhillips Kuparuk DAILY WELLSITE REPORT EPOCH 2A - 26 REPORT FOR Herbert, Rizek, Greener, Head DATE Jan 05, 2009 DEPTH 5160' PRESENT OPERATION Drilling Ahead TIME 2359 hrs YESTERDAY 3150' 24 HOUR FOOTAGE 2010' CASING INFORMATION 10-1/2" @ 3149' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3785' 48.31 . 128.91 3228.25' 4261' 51.87 125.26 3533 48' SURVEY DATA . 4738' 50.83 131.30 3831.09' 5213' 51.27 130.30 4126.79' 5496' 50.78 131.36 4304.11' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9-7/8" HYC DTX619MB10 123722 6 X 14/0.902 3150' 2010' 8.4 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 432.9 @ 3357 9.2 @ 4214 275.9 311.7 FT/HR SURFACE TORQUE 13038 @ 5139 3 @ 4402 8250.4 9664.8 AMPS WEIGHT ON BIT 35 @ 4969 1 @ 3741 8.6 10.3 KLBS ROTARY RPM 127 @ 3288 1 @ 5076 .107.1 121 RPM PUMP PRESSURE 3358 @ 5157 1622 @ 3424 2568.5 3257.5 PSI DRILLING MUD REPORT DEPTH 5159/4126 MW 9.2 VIS '41 PV 12 YP 18 FL 6 Gels 8/12/14 CL- 420 FC 1 SOL 6.5 SD tr OIL 1/93 MBL 16.25 pH 9.4 Ca+ 120 CCI MWD SUMMARY INTERVAL 3150' TO Current TOOLS PDC bit with Spery Drill and LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 474 @ 3274 0 @ 5037.00000 56.3 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 62636 @ 3274 26 @ 4023 7223.5 CONNECTION GAS HIGH 0 ETHANE (C-2) 2462 @ 3274 0 @ 164.8 AVG PROPANE (C-3) 784 @ 3274 0 @ 31.9 CURRENT BUTANE (C-4) 587 @ 3274.0 @ 10.1. CUR RENT BACKGROUND/AVG 15-25 while circulating PENTANE. (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS None. Please refer to mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 24 hour: 60% siltstone, 30% sandstone, 10% claystone PRESENT LITHOLOGY 5150 ft: 90% sandstone, 10%siltstone DAILY ACTIVITY Drill out float equipment, shoe, 20 foot of formation. Circulate bottoms up. Displace to LSND. Perform FIT test. SUMMARY Obtain pressure wjile drilling baseline. Drill ahead from 3170 ft to 5160 ft at report time. EPOCH PERSONNEL ON BOARD Resch, Winslow + 2 SC_ DAILY COST $3435 REPORT BY Larry Resch file://C:\DOCUMENTS%°20AND%20 SETTINGS\EPOCHADMIN\MY%20DOCUMENTS... 1 /6/2009 • • • Daily Report Page 1 of 2 ConocoPhillips Kuparuk DAILY WELLSITE REPORT EPOCH 2A - 26 REPORT FOR Herbert, Rizek, Greener, Head DATE Jan 06, 2009 DEPTH 6895' PRESENT OPERATION POOH for MWD TIME 2359 hrs YESTERDAY 5160' 24 HOUR FOOTAGE-1735' CASING INFORMATION 10-1 /2" @ 3149' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5594' 51.90 130.29 4364.83' 5879' 51.44 130.07 4542.51' SURVEY DATA 6069' 51.18 130.56 4660.72' 6449' 49.18 130.18 4901.70' 6831' 38.66 130.42 5173.22' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 9-7/8" HYC DTX619MB10 123722 6X14/0.902 3150 3745' 17.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 547.0 @ 5444 5.2 @ 5924 237.5 138.4 FT/HR SURFACE TORQUE 15577 @ 6680 0 @ 6701 11134.5 1324. AMPS WEIGHT ON BIT 28 @ 6703 2 @ 5846 7.6 30.3 KLBS ROTARY RPM 126 @ 5162 1 @ 6886 103.8 0.00000 RPM PUMP PRESSURE 4094 @ 6191 2965 @ 5218 3641.5 3358.8 PSI DRILLING MUD REPORT DEPTH 6895/5224 MW 9.2 VIS 44 PV 14 YP 17 FL 4.4 Gels 6/14/23 CL- 380 FC 1 SOL 7.5 SD tr OIL 1/92 MBL 22.5 pH 9.6 Ca+ 120 CCI MWD SUMMARY INTERVAL 3150 TO Current TOOLS PDC bit with Spery Drill and LWD GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 643 @ 6574 0 @ 61.9 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS. n/a CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 7049467 @ 6495.00000 @ 57420.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 1155538 @ 6495.00000 @ 8354.3 AVG PROPANE (C-3) 638483 @ 6495.00000 @ 4770.0 CURRENT BUTANE (C-4) 241606 @ 6495.00000 @ 1914.8 CURRENT BACKGROUND/AVG -- PENTANE (C-5) 0 @ @ -0.1 HYDROCARBON SHOWS none. Please refer to mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 70% sand, 20% siltstone, 10% claystone PRESENT LITHOLOGY 6850 ft: 100% sand, trace claystone Drill ahead from 5160 ft to 5444 ft5. Pick up weight increases 30k with increasing torque. Circulate bottoms up while DAILY working pipe. Pump 40 bbl 10.3ppg 250 vis sweep; observe slight inrease in cuttings. Torque drops. Drill ahead from ACTIVITY 5444 ft to 6740 ft. Pump 40 bbl 10.3ppg 250 vis sweep. Pump pressure drops 300 psi as soon as sweep left bit. SUMMARY ECD's dropped from 10.55 to 10.32 ppg; observe slight increase in cuttings at shaker. Pull out of hole from 6895 ft for MWD. Back ream from 4095 ft to shoe at report time. file://C:\DOCUMENTS%20AND%20 SETTINGS\EPOCHADMIN\MY%20DOCUMENTS... 1 /7/2009 Daily Report EPOCH PERSONNEL ON BOARD Resch, Winslow + 2 SC_ DAILY COST $3435 REPORT BY Larry Resch Page 2 of 2 • file://C:\DOCUMENTS%20AND%20SETTINGS\EPOCHADMIN\MY%20DOCUMENTS... 1 /7/2009 Daily Report Page 1 of 1 ConocoPhillips Kuparuk DAILY WELLSITE REPORT E'PQC,H 2A - 26 REPORT FOR Herbert, Rizek, Greener, Head DATE Jan 08; 2009 DEPTH 7495' PRESENT OPERATION Test BOP's TIME 2359 hrs YESTERDAY 7090' 24 HOUR FOOTAGE 405' CASING INFORMATION 10-1/2" @ 3149' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. .SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 442.8 @ 7413' 36.2 @ 7140' 201:6 200.6' FT/HR SURFACE TORQUE 17548 @ 7482' 619 @ .7158' 13373.9 16144.0' AMPS WEIGHT ON BIT 30 @ 7167 2 @ 7433' 6.0 2:8 KLBS ROTARY RPM 126 @ 7340' 2 @ 7234' 104.2 123' RPM PUMP PRESSURE 3870 @ 7428' 3164 @ 7234' 3548.8 3607' PSI DRILLING MUD REPORT DEPTH 7502/5374 MW 9.5 VIS 43 PV 9 YP 16 FL 3.6 Gels 5/8/14 CL- 350 FC 1 SOL 7 SD tr OIL 2/91 MBL 18 pH 9.9 Ca+ 80, CCI MWD SUMMARY INTERVAL TO TOOLS BHA not available at report time. Plan to rig up with casing while drilling. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 476 @ 7411 18 @ 7141 195.4 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS 982 U CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 56170 @ 7411 2746 @ 7141 25132.8 CONNECTION GAS HIGH 0 ETHANE (C-2) 4308 @ 7411 133 @ 7259 1626.9 AVG PROPANE (C-3) 1404 @ 7411 3 @ 7149 525.7 CURRENT BUTANE (C-4) 504 @ 7411 2 @ 7241 104.8 CURRENT BACKGROUND/AVG -- PENTANE (C-5) 0 @ 0 @ HYDROCARBON SHOWS please refer to mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY No new footage drilled since last report PRESENT LITHOLOGY DAILY Drill ahead from 7090 to 7495'MD.. Circulate 2+ bottums up. ECD decreased from 10.1 to 8.94ppg. Short trip and ACTIVITY return to bottom. Epoich records 982 units of wiper trip gas. Pump 50 bbl 10.3ppg 250 vis sweep; observe significant SUMMARY increase of cuttings at shaker. Weight up to 9.5ppg as a result of wiper trip gas amount. Pump dry job and pull out of hole. Lay down BHA. Change rams to 7-5/8". Currently testing BOP's at report time. EPOCH PERSONNEL ON BOARD Resch, Winslow + 2 SC_ DAILY COST $3435 REPORT BY Larry Resch :7 file://C:\DOCUMENTS%20AND%20 SETTINGS\EPOCHADMIN\MY%20DOCUMENTS... 1 /9/2009 ~, • Daily Report Page 1 of 1 ConocoPhillips Kuparuk DAILY WELLSITE REPORT EPOCH 2A - 26 REPORT FOR Herbert, Rizek, Greener, Head DATE Jan 9, 2009 DEPTH 7635' PRESENT OPERATION Casing While Drilling TIME 2359 hrs YESTERDAY 7495' 24 HOUR FOOTAGE 140' CASING INFORMATION 10-1/2" @ 3149' 7-5/8" @ ? DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA No surveys in this drilled interval BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 200.6 @ 7495 12.2 @ 7496 46.8 37.4 FT/HR SURFACE TORQUE 21220 @ 7624 16144 @ 7495 19196.2 17659 AMPS WEIGHT ON BIT 25 @ 7496 2 @ 7495 6.7 6.5 KLBS ROTARY RPM 123 @ 7495 39 @ 7496 79.9 78 RPM PUMP PRESSURE 3607 @ 7495 1275 @ 7501 .1450.4 1531 PSI DRILLING MUD REPORT DEPTH 7780/5374 MW 9.6 VIS 46 PV 10 YP 18 FL 2.4 Gels 6/10/12 CL- 320 FC 1 SOL 7 SD TR OIL 2/91 MBL 20 pH 9.6 Ca+ 72 CCI MWD SUMMARY INTERVAL 7495' TO Current. TOOLS Currently casing while drilling. No MWD/LWD tools in hole. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 263 @ 7615 44 @ 7500 205.0 TRIP GAS 407 u CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) 32572 @ 7615 5762 @ 7500 4617.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 2524 @ 7495 458 @ 7500 374.7 AVG PROPANE (C-3) 858 @ 7495 164 @ 7500 137.1 CURRENT BUTANE (C-4) 221 @ 7495 6 @ 7512 5.7 CURRENT BACKGROUND/AVG 185 u PENTANE (C-5) 0 @ @ HYDROCARBON SHOWS Please refer to mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 24 hours: 50% sandstone, 50% carbonaceous shale PRESENT LITHOLOGY 7630 ft: 80% sandstone, 20% carbonaceous shale DAILY Complete BOP tests. Rig up and run in hole with 7-5/8" casing while drilling tools to 3011'MD. Circulate bottoms up ACTIVITY at 250 gpm. Continue trip in hole, stopping to circulate bottoms up at 5409 ft, 5830 ft and 7488 ft. Epoch records 407 SUMMARY units of trip gas maximum at 26.5 hours down time. Perform LOT at 7488'MD to 12.2 ppg EMW. Drill ahead with 7- 5/8" casing to 7635 ft at report time. EPOCH PERSONNEL ON BOARD Resch, Winslow + 2 SC_ DAILY COST $3535 REPORT BY Larry Resch file://C:\Documents%20and%20Settings\EpochAdmin\My%20Documents\My%20Wells\... 1 /11 /2009 Daily Report • Page 1 of 1 ConocoPhillips Kuparuk DAILY WELLSITE REPORT EPOCH 2A - 26 REPORT FOR Thornton, Rizek, Greener, Head DATE Jan 10, 2009 DEPTH 7835' PRESENT OPERATION Weight Up; Circulate and Condition TIME 2359 hrs YESTERDAY 7635' 24 HOUR FOOTAGE 200' CASING INFORMATION 10-1/2" @ 3149' 7-5/8" @ ? SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 120.1 @ 7743. 7.6 @ 7638 42.9 19.1 FT/HR SURFACE TORQUE 22291 @ 7710 16138 @ .7658 19433.0 20015 AMPS WEIGHT ON BIT 11 @ 7676 1 @ 7802 5.1 -0.0 KLBS ROTARY RPM 84 @ 7657 47 @ 7817 8.1.1 79 RPM PUMP PRESSURE 1531 @ 7635 1256 @ 7699 1382.0 1367 PSI DRILLING MUD REPORT DEPTH 7835/5374 MW 11.8 VIS 55 PV 27 YP 19 FL 5.4 Gels 4/5/7 CL- 300 FC 1 SOL 13 SD TR OIL 1/87 MBL 10 pH 9.5 Ca+ 20 CCI MWD SUMMARY INTERVAL 7495' TO TOOLS Currently casing while drilling. No MWD/LWD tools in hole. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 978 @ 7678 26 @ 7819 249.3 TRIP GAS n/a CUTTING GAS @ @ WIPER GAS n/a CHROMATOGRAPHY (ppm) SURVEY n/a METHANE (C-1) 131665 @ 7678 3057 @ 7819 27858.4 CONNECTION GAS HIGH 357u @ 7699'MD ETHANE (C-2) 11793 @ 7728 349 @ 7818 3105.7 AVG 0 PROPANE (C-3) 7055 @ 7835 159 @ 7818 1407.4 CURRENT 0 BUTANE (C-4) 3141 @ 7835 3 @ 7653 527.5 CURRENT BACKGROUND/AVG 1500 u PENTANE (C-5) 1175 @ 7835 5 @ 7704 66.5 HYDROCARBON SHOWS Please refer to mud log. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 24 hours: 100% sandstone, trace carbonaceous shale PRESENT LITHOLOGY 7835 ft: 100% sandstone; trace shale. Drill ahead with 7-5/8" casing from 7635 ft to 7656 ft. Circulate bottoms up; circulate and condition. Perform second DAILY LOT at 7656 ft: EMW = 14.4ppg. Drill ahead with casing from 7656 ft to 7695 ft. Record 963 units of gas: Circulate ACTIVITY bottoms up; circulate out gas. Drill ahead with 7-5/8" casing from 7695 ft to 7780 ft: Criculate bottoms up. Drill ahead SUMMARY with 7-5/8" casing from 7780 ft to 7835 ft and displace to 11.5 ppg WBM. Gas increases to over 3000 units; weight up to 11.8ppg while reciprocating pipe at report time. EPOCH PERSONNEL ON BOARD Resch, Winslow + 2 SC_ DAILY COST $3535 REPORT BY Larry Resch file://C:\DOCUMENTS%20AND%20SETTINGS\EPOCHADMIN\MY%20DOCUMENT... 1 / 1.1 /2009 • Daily Report Page 1 of 1 ConocoPhillips Kuparuk DAILY WELLSITE REPORT EPOCH 2A - 26 REPORT FOR Thornton, Rizek, Greener, Head DATE Jan 11, 2009 DEPTH 7835' PRESENT OPERATION Circulate out gas TIME 2359 hrs YESTERDAY 7835' 24 HOUR FOOTAGE 0' CASING INFORMATION 10-1/2" @ 3149'_ 7-5/8" @ ? SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KCBs ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7835/6057 MW 12.1 VIS 50 PV 18 YP 16 FL 4.0 Gels 5/6/7 CL- 220 FC 1 SOL 14 SD tr OIL 1/85 MBL 10 pH 9.1 Ca+ 20 CCI MWD SUMMARY INTERVAL 7495' TO TOOLS Casing while drilling. No MWD/LWD tools in hole. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS No new footage drilled this period. INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY No new footage drilled this period. PRESENT LITHOLOGY Continue weighting up to 11.8 ppg while reciprocating casing string. Flow check well with 11.8 ppg in/out: Well flowing. DAILY Circulate bottoms up. Casing parts while circulating. Lay down 1 joint of 7-5/8" casing; shut in well. Build kill weigh ACTIVITY mud; pump 15.8 ppg mud. Monitor well. Pump 15.7 ppg kill weight mud. Monitor well: Still flowing. Pull out of hole with SUMMARY only 13 joints 7-5/8" casing. Monitor well: Flowing. Close blind rams. Change out pipe rams and test hydril and pipe rams. Run in hole with fishing BHA. Circulate until mud 12.0 in and out. Pull fish free. Epoch records 2487 units of gas maximum at 12.1+ in/out. Circulating out gas at report time. EPOCH PERSONNEL ON BOARD Resch, Winslow + 2 SC_ DAILY COST $3535 REPORT BY Larry Resch • file://C:\DOCUMENTS%20AND%20 SETTINGS\EPOCHADMIN\MY%20DOCUMENT... 1 / 12/2009 ConocoPhillips Alaska Inc. 2A - 26 Daily Report Jennifer Head Report for: M. Thornton G. Rizek M. Greener. Date: 1/12/09 Time: 2359hrs Current Depth (MD): 7835' Current Pumping Cement Current Depth (TVD): 6057 Operations: 24 hr Foota a MD : 0 rlrillinn D~r~mcterc ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: ECD: Current: Max: La Strokes: Time: Surf-Surf: Strokes: Time:. Mari Prnnartiac (n~ 7RRF/Rnr,7 MW: 12.3 FV: 54 PV: 16 YP: 17 fL: 3.8 Gels: 4/5/7 Sol: 14 H: 9.2 CI-~ 240 Ca+ ~ 20 MW Change: Mud Loss event Gas Bata Ditch Gas:. Avc Varies while kill (sae Fvontc Depth: None From: _ Depth: None Volume: _ Bk rd Current: Max: q well units units To: Reason: MDITVD Units C1 C2 C3 C41 C4N C51 C5N Tri Gas n/a Conn. Gases none Other Gas Sam les: No. De th MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: No new footage drilled this period. Last 24 hrs: Continue to circulate out gas while reciprocating casing from 7825 ft to 7815 ft. Monitor well: Well flowing slightly. Circulate bottoms up and weight up to 12.3 ppg. Epoch records maximum 2769 units at 1.8 hours down time. Monitor well: Well is static. Short trip out of hole with fish; lay down damaged casing. Drop carbide and dye twice with no indication of getting either back to surface. OperatlOnal Summary: Monitor well: Well flowing slightly. Run in hole with replaced 7-5/8" casing. Circulate and condition hole. Epoch records maximum gas of 2291 units at 4.0 hours down time. Continue to circulate with 12.3 ppg mud in/out while rigging up cementers. Gas steadies to 125 to 150 units. Pump 40 bbls mud push, 84 bbls of cement; bump plug with 343 of 12.3ppg LSND. Maximum gas recorded during cement operations was 171 units. Calibrations: THA., Chro matograph At x10 and x100 attenuation Failures: None Daily Cost: X3535 ~^ ~~~~~ ConocoPhillips Alaska Inc. 2A - 26 Daily Report Jennifer Head Report for: M. Thornton G. Rizek M. Greener Date: 1/13/09 Time: 2359hrs Current Depth (MD): 7835' Current L/D Drill Pipe Current Depth (TVD): 605T Operations: 24 hr Foota a MD : 0 Drilling Parameters ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: ECD: Current: Max: La Strokes: Time: Surf-Surf: Strokes:. Time: Mud Properties la7 7835/6057 MW: 12.3 FV: 49 PV: 16 YP: 16 FL: 4 Gels: 4// Sol: 14 H: 9.1 CI-~ 240 Ca++~ 20 MW Change: Depth: None From: Mud Loss event: Depth: None _ Volume: Gas Data Ditch Gas: Av . Bk rd Current: Max: Varies while killin well units units Gas Events To: Reason: ,~. MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Tri Gas n/a Conn. Gases none Other Gas Sam les: No. De th MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: No new footage drilled this period. Last 24 hrs: Cement lines were blown down, and cement head rigged down. ND riser and raise the stack. Operational Summary: Cut casing, NU stack, and Go rams. Perform a LOT and freeze protect 10 3/4" X 7 5/8" annulus. Test BOPE and prepare to LD 5" DP. Calibrations: None Failures: None Daily Cost: X3535 i• E~V~~ • • ConocoPhillips Alaska Inc. 2A-26 Daily Report Jennifer Head Report for: M. Thornton S. Lapine M. Greener Date: 1/14/09 .Time: 2359hrs Current Depth (MD): 7835' Current .Current Depth (TVD): 6057' Operations: Stand into hole. 24 hr Foota a MD : 0 f)rillinn Paramotcrc ROP: Current: Max: Tor ue: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: ECD: Current: Max: La Strokes: Time: Surf-Surf: Strokes: Time: Mud Prooerties (a~ 7R~.ni/Rnr,7 MW: 12.3 FV: 54 PV: 16 YP: 18 FL: 4.1 Gels: 6/8/9 Sol: 13 H: 9.1 CI-~ 240 Ca+ ~ 20 MW Change:. Mud Loss event: Gas .Data Depth: None From: Depth: None Volume: To: Reason: Ditch Gas: Av . none Gas Events Current: I Max: MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Tri Gas n/a Conn. Gases none Other Gas Samoles• No. De th MD/TVD Units C1 C2 C3 C41 C4N C51 C5N Lithologies: Current: No new footage drilled this period. Last 24 hrs: Operational Summary: Had safety meeting for LD 5"drill pipe out of derrick. The rig was down for repairing pipe skate. Made up BHA #5. Picked up 4" DP and running in the hole @ report time. Calibrations: Carbide tested gas trap. Tested fine. Failures: None Daily Cost: X3535 ~i E~~C.C7
