The URL can be used to link to this page

Home My WebLink About210-035CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD3-302A PTD (210-035) Date:Thursday, June 1, 2023 1:13:29 PM From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Thursday, June 1, 2023 11:36 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD3-302A PTD (210-035) Chris, CD3-302A PTD (210-035) extended 30 day monitor ends today. The well has stabilized and shows integrity. CPAI will submit necessary documents to cancel AA AIO 18E.003. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Well Integrity Specialist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com From: WNS Integrity Sent: Thursday, April 27, 2023 2:48 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; ALP Prod Engr <alp2087@conocophillips.com> Subject: RE: CRU CD3-302A PTD (210-035) Chris, CRU CD3-302A PTD (210-035) is showing high IA while on gas. CPAI plans to bleed the well and extend the 30 day monitor to prove well integrity. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Well Integrity Specialist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com From: WNS Integrity Sent: Thursday, March 2, 2023 2:45 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; ALP Prod Engr <alp2087@conocophillips.com> Subject: CRU CD3-302A PTD (210-035) Chris, CRU CD3-302A PTD (210-035) has completed a workover. The well currently operates under AIO 18E.003 for known TxIA on gas injection. CPAI plans to bring the well online for gas injection. A 30 day monitor will commence and if the well proves integrity to gas injection, CPAI will cancel AA AIO 18E.003. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Well Integrity Specalist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD3-302A PTD (210-035) Date:Thursday, April 27, 2023 2:50:44 PM From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Thursday, April 27, 2023 2:48 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; ALP Prod Engr <alp2087@conocophillips.com> Subject: RE: CRU CD3-302A PTD (210-035) Chris, CRU CD3-302A PTD (210-035) is showing high IA while on gas. CPAI plans to bleed the well and extend the 30 day monitor to prove well integrity. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Well Integrity Specialist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com From: WNS Integrity Sent: Thursday, March 2, 2023 2:45 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; ALP Prod Engr <alp2087@conocophillips.com> Subject: CRU CD3-302A PTD (210-035) Chris, CRU CD3-302A PTD (210-035) has completed a workover. The well currently operates under AIO 18E.003 for known TxIA on gas injection. CPAI plans to bring the well online for gas injection. A 30 day monitor will commence and if the well proves integrity to gas injection, CPAI will cancel AA AIO 18E.003. Let me know if you have any questions or disagree with this plan. Thanks, P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 13, 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitors, 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 attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Brennen Green or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Brennen Green ConocoPhillips Well Integrity Field Supervisor Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2023.04.13 11:34:18-08'00' Foxit PDF Editor Version: 12.0.1 Brennen Green ConocoPhillips Alaska Inc.Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-offReport of Sundry Operations (10-404)Alpine FieldWell Name API # PTD #Initial top of cementVol. of cement pumpedFinal top of cementCement top off date Corrosion inhibitorCorrosion inhibitor/ sealant dateft bbls in galCD3-106 5010320611-0000 210-001 N/APost Conductor Ext10.75" 4/5/2022 2 4/12/2023CD3-117 5010320596-0000 209-026 N/APost Conductor Ext13" 4/5/2022 3 4/12/2023CD3-127 5010320634-0000 211-005 18' 1.0 8" 4/9/2022 1 4/12/2023CD3-302A 5010320522-0100 210-035 N/APost Conductor Ext9" 4/5/2022 2 4/12/2023CD4-214 5010320537-0000 206-145 22' 8" 1.6 7" 4/9/2022 1.5 4/12/2023CD4-319 5010320516-0000 205-148 22' 3" 1.5 7" 4/9/2022 1.5 4/12/2023Date 04/13/2023CD3 & CD4 PadsCD3-302A5010320522-0100210-035N/A9"4/5/202224/12/2023Post Conductor Ext MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, May 19, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD3-302A COLVILLE RIV UNIT CD3-302A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/19/2023 CD3-302A 50-103-20522-01-00 210-035-0 G SPT 6701 2100350 1675 3850 3850 3860 3860 695 765 765 765 OTHER P Guy Cook 4/5/2023 MIT-IA post RWO. Well is currently under AIO 18E.003. Submittal for AA cancellation to follow passing MIT-IA and 30 day monitor on gas injection. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD3-302A Inspection Date: Tubing OA Packer Depth 1540 2495 2490 2490IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230404193803 BBL Pumped:1.2 BBL Returned:1 Friday, May 19, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 99 9 9 9 Well is currently under AIO 18E.003.Submittal for AA cancellation James B. Regg Digitally signed by James B. Regg Date: 2023.05.19 14:45:46 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD3-302A PTD (210-035) Date:Thursday, March 2, 2023 2:59:14 PM From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Thursday, March 2, 2023 2:45 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; ALP Prod Engr <alp2087@conocophillips.com> Subject: CRU CD3-302A PTD (210-035) Chris, CRU CD3-302A PTD (210-035) has completed a workover. The well currently operates under AIO 18E.003 for known TxIA on gas injection. CPAI plans to bring the well online for gas injection. A 30 day monitor will commence and if the well proves integrity to gas injection, CPAI will cancel AA AIO 18E.003. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Well Integrity Specalist ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | WNSIntegrity@conocophillips.com STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________COLVILLE RIV UNIT CD3-302A JBR 03/31/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Several leaks during the shell test, HCR choke-replaced, Oteko flanges on both kill and choked-replaced. Flanges on stack in a few spots needed tightened. Test Results TEST DATA Rig Rep:Frank Carlo/Matt SamOperator:ConocoPhillips Alaska, Inc.Operator Rep:Byran Marmon/ Wes Jeardo Rig Owner/Rig No.:Doyon 142 PTD#:2100350 DATE:2/13/2023 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopAGE230219102401 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5 MASP: 4130 Sundry No: 323-027 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 14 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8 P #1 Rams 1 3 1/2 x 6 P #2 Rams 1 Blind/Shear P #3 Rams 1 3 1/2 x 6 P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8 P HCR Valves 2 3 1/8 P Kill Line Valves 1 3 1/8 P Check Valve 0 NA BOP Misc 0 NA System Pressure P2900 Pressure After Closure P1750 200 PSI Attained P7 Full Pressure Attained P55 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P6@ 2000 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P13 #1 Rams P7 #2 Rams P7 #3 Rams P7 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P2 HCR Kill P2 9 9 9 9 9 9999 9 Several leaks during the shell test, %23(7HVW'R\RQ &58&'$37' $2*&&,QVSERS$*( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS By Kayla Junke at 1:09 pm, Mar 17, 2023 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 E Coiled Tubing Ops ❑ Other: Replace Tubing ❑� 2. Operator Name 4. Well Class Before Work: 5. Permit to Drill Number: ConoeoPhillips Alaska, Inc. Development ❑ Exploratory ❑ Stratigraphic ❑ Service El 210.035 3. Address: P.O. Box 100360 6. API Number: Anchorage, AK 99510 50-103-20622-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0364471, ADL0372104, ADL0372105 CRU CD3-302A 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): NIA Colville River Field/ Fiord Ku aruk Oil Pool 11. Present Well Condition Summary: Total Depth measured 12603' feet Plugs measured 12161' feet true vertical 6941' feet Junk measured None feet Effective Depth measured 12161' feet Packer measured 119881,120981 feet true vertical 6727' feet true vertical 6656', 6701' feet Casing Length Size MD TVD Buret Collapse Conductor 77' 16" 115' 115' Surface 2642' 9-5/8" 2669' 2495' Intermediate 12568' 7" 12593' 6935' Production Liner Perforation depth Measured depth 12361-12371' True Vertical depth 6814-6819' Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 12212' MD 6749' TVD Packers and SSSV (type, measured and true vertical depth) Packer. D&L Perm Packer 11988' MD 6656' TVD Packer: Baker Premier Packer 12098' MD 6701' TVD SSSV: None N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13a. Representative Daily Average Production or Injection Data Oil-BbI Gas-Mcf Water-BbI Casing Pressure Tubing Pressure Prior to well operation: INJECTOR - - - - Subsequent to operation: - - - - - 131b. Pools active after work: 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory ❑ Development ❑ Service ❑' Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑' GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby cerfify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: W� Digitally signed by Adam Hem 323-027 Authorized Name and Adam 1 Kle ll Date: 2023-03.1609:58:36 Digital Signature with Dale: -wool Contact Name: Adam IOem Contact Email: adam.klemCrDconocomhillios.com Authorized Title: Staff RWO /CTD Engineer Contact Phone: (907) 263-4529 Sr Pet Eng: Isr Pet Geo: I JSr Res Eng: RBDMS JSB 032323 Form 10404 Revised 1012022 Due Within 30 days of Operations Submit in PDF format to aogcc.permifting@alaska.gov Operations Summary (with Timelog Depths) CD3-302 9.6 RIG RELEASE DATE 2/16/2023 CmwcoPhiOips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Time ErM Time Dur (hr) Phase Activity Code Time P-T-X Operation Stan Depth (ftKB) End Depth (ftKB) 2/9/2023 2/9/2023 9.00 MIRU, MOVE MOB P RAISE STOMPERS ON SUB, INSTALL 0.0 0.0 00:00 09:00 AUGER BACK INTO PITS. JACK UP SUB AND LATCH TO TRUCK. HOOK UP CATS. START TO MOVE SUB AND DISCOVER AIR LEAKING FROM TWO ODS REAR TIRE SEAL RINGS. CHANGE OUT ORINGS ON TIRES AND AIR UP SAME PER NES TECH. 2/9/2023 2/9/2023 1.50 MIRU, MOVE MOB P WAIT ON AVIAITION ON DECISION TO 0.0 0.0 09:00 10:30 DIVERT FLIGHT FROM ALPINE TO KUPARUK. DECISION MADE TO LAND IN ALPINE. 2/9/2023 2/9/2023 1.25 MIRU, MOVE MOB P TRANSPORT ROCKWASHER, PIT 0.0 0.0 10:30 11:45 COMPLEX, AND SUB FROM CD4 TO ALPINE RUNWAYACTIVE SIGN. 2/9/2023 2/9/2023 1.00 MIRU, MOVE MOB T STANDBYAT RUNWAYACTIVE SIGN 0.0 0.0 11:45 12:45 FOR CASA TO ROUNDTRIP TO KUPARUK FOR GROCERIES. 2/9/2023 2/9/2023 1.25 MIRU, MOVE MOB P CONTINUE TO TRANSPORT 0.0 0.0 12:45 14:00 ROCKWASHER, PIT COMPLEX, AND SUB FROM ACTIVE RUNWAY SIGN TO CD3-302A. 2/9/2023 2/9/2023 1.25 MIRU, MOVE MOB T ONCE ONTO ICE ROADAT CD2, NES 0.0 0.0 14:00 15:15 FOUND ISSUE WITH SOW PULLING PITCOMPLEX. REPAIRTRUCK. 2/9/2023 2/9/2023 2.75 MIRU, MOVE MOB P CONTINUE TO TRANSPORT 0.0 0.0 15:15 18:00 ROCKWASHER, PIT COMPLEX, AND SUB FROM ICE ROAD AT CD2 TO CD3-302A. 2/9/2023 2/9/2023 3.00 MIRU, MOVE MOB P LAY HERCULITE AND RIG MATS. 0.0 0.0 18:00 21:00 SPOT SUB OVER CD3-302A. - SIMOPS - WAIT ON CD4 LAKE PUMP TO BE REMOVED. TRANSPORT PUMP, POWER, AND PIPESHED MODULES FROM CD4 TO CD3. LEAVE LOCATION AT 19:45. 2/9/2023 2/9/2023 1.50 MIRU, MOVE MOB P SET SUB STOMPERSAND CONTINUE 0.0 0.0 21:00 22:30 TO PLACE MATS. SIMOPS- CONTINUE TO TRANSPORT PUMP, POWER, AND PIPESHED MODULES FROM CD4 TO CD3. 2/9/2023 2/9/2023 0.50 MIRU, MOVE MOB P SKID RIG FLOOR INTO POSITION 0.0 0.0 22:30 23:00 AND REMOVE TOW TONGUE. 2/9/2023 2/10/2023 1.00 MIRU, MOVE MOB P SPOT PITS MODULE. SIMOPS - 0.0 0.0 23:00 00:00 PUMP, POWER, AND PIPESHED MODULES ARRIVE AT CD3. 2/10/2023 2/10/2023 0.50 MIRU, MOVE MOB P SPOT PUMP MODULE 0.0 0.0 00:00 00:30 2/10/2023 2/10/2023 1.50 MIRU, MOVE MOB P SPOT PIPE SHED. 0.0 0.0 00:30 02:00 2/10/2023 2/10/2023 0.50 MIRU, MOVE MOB P SPOT MOTOR COMPLEX 0.0 0.0 02:00 02:30 2/10/2023 2/10/2023 0.50 MIRU, MOVE MOB P SPOT ROCK WASHER. 0.0 0.0 02:30 03:00 2/10/2023 2/10/2023 3.00 MIRU, MOVE MOB P WORK ON COMPLETING RIG 0.0 0.0 03:00 06:00 ACCEPTANCE CHECK LIST. IE. LOWER AND SECURE ALL STAIRS AND WALKWAYS AROUND THE RIG. WORK ON HOOKING UP STEAM, AIR, AND WATER. WRAP HERCULITE AROUND CELLAR. WRAP BACK CELLAR DOOR WITH RE-INFORCED PLASTIC WRAP. ELECTRICIAN BEGIN TO PLUG IN ELECTICAL COMPONENTS. Page 117 Report Printed: 3/13/2023 Operations Summary (with Timelog Depths) CD3-302 9.6 RIG RELEASE DATE 2/16/2023 Co..31,1111 s Rig: DOYON 142 Job: RECOMPLETION Time Log Shm Time ErM Time Dur (hr) Phase Activity Code Time P-T-X Operation Stan Depth (ftK8) End Depth (ftKB) 2/10/2023 2/10/2023 6.00 MIRU, MOVE MOB P CONTINUE TO M/U STEAM, AIR, 0.0 0.0 06:00 12:00 WATER, AND MUD LINE CONNECTIONS. SPOTAND BERM TIGER TANKAND CHOKE SKID, M/U HP HOSE TO SAME. HERCULITEAND SEAL UP CELLAR BACK DOOR. R/U HEATER FOR CELLAR. COMPLETE M/U OF ELECTRICAL CONNECTIONS. RIG STILL ON CAT POWER. MAKE 48 HR NOTIFICATION TO AOGCC FOR BOP TEST @10:30 AM 2/10/2023 2/10/2023 6.00 MIRU, MOVE MOB P INSTALL BEAVERSLIDE. M/U CHOKE, 0.0 0.0 12:00 18:00 KILLAND CEMENT LINES ON SUB. TAKE ON FRESH WATER AND FUEL TO RIG. WORK ON RIG ACCEPTANCE CHECKLIST. R/U RIG TO HIGHLINE POWER. RIG ON HIGHLINE POWER @16:30 HRS 2/10/2023 2/11/2023 6.00 MIRU, MOVE MOB P CONT M/U CHOKE, KILL, CEMENT 0.0 0.0 18:00 00:00 AND INJECTION LINES ON SUB. TAKE ON SEAWATER TO PITS. CONNECT BOP HYD LINES. BUILD MANIFOLD FOR CIRCULATING WELL. INSTALL PIPE SKATE RAIL ASSEMBLY AND TEST SAME. WORK ON RIG ACCEPTANCE CHECKLIST 2/11/2023 2/11/2023 4.00 MIRU, WELCTL NUND P PERFORM RIG ACCEPTANCE WALK 0.0 0.0 00:00 04:00 THRU WITH TOOL PUSHER. ACCEPT RIG ON 2111/23 @ 00:00 HRS TAKE ON 2ND LOAD OF SEAWATER TO PITS. C/O TREE FLANGES. M/U CIRC LINES FOR DISPLACEMENT. LOAD PIPE SHED WITH 4.5" HYD 563 TUBING. R/U HP HOSES FROM INJECTION LINE TO TREE AT TUBING AND IATHRU CIRC MANIFOLD TO CHOKE HOUSE AND TIGER TANK. WARM UP LINE WITH STEAM AND BLOW DOWN SAME. BRING FMC LUBRICATOR TO RIG FLOOR 2/11/2023 2/11/2023 0.50 MIRU, WELCTL SEQP P PRESSURE TESTALL LINES TO 0.0 0.0 04:00 04:30 TIGER TANK TO 1000 PSI. BLOW DOWN LINES. 2/11/2023 2/11/2023 1.00 MIRU, WELCTL OWFF P R/U FMC AND PULL BPV. OBSERVE 0.0 0.0 04:30 05:30 20 PSI ON TUBING AND IA. 70 PSI ON CA. 2/11/2023 2/11/2023 0.50 MIRU, WELCTL SFTY P HOLD PRE -SPUD MEETING WITH 0.0 0.0 05:30 06:00 BOTH CREWS. REVIEW HSE PRIORITIES AND JOB SCOPE PLAN FORWARD. 2/11/2023 2/11/2023 3.25 MIRU, WELCTL SEOP P BLOW AIR THRU TIGER TANK LINE. 0.0 06:00 09:15 CHECKALL LINE UPS AT PITS, PUMP ROOM AND CELLAR MANIFOLD. COMPLETE PREP TO CIRC OUT DIESELAND SEAWATER DISPLACEMENT. PRESSURE TEST MUD LINE TO RIG FLOORAND INJECTION LINE TO CELLAR TO 3500 PSI. W/MPlF2 Page 217 Report Printed: 3/13/2023 Operations Summary (with Timelog Depths) CD3-302 9.6 RIG RELEASE DATE 2/16/2023 CorrocoPhlnipe Rig: DOYON 142 Job: RECOMPLETION Time Log Stim Time ErM Time Dur (hr) Phase Activity Code Time P-T-X Operation Stan Depth (ftK8) End Depth (ftKB) 2/11/2023 2/11/2023 2.50 MIRU, WELCTL DISP P DISPLACE WELL TO CLEAN 09:15 11:45 SEAWATER. PUMP 40 BBLS 8.5 PPG SEAWATER DOWN IA, TAKING DIESEL FP RETURNS OUT TUBING TO TIGER TANK. 3 BPM = 440 PSI LINE UP TO PUMP DOWN TUBING. PUMP 427 BBLS 8.5 PPG SEAWATER DOWN TUBING, TAKING RETURNS OUT IA TO TIGER TANK. 5 BPM = 880 PSI SHUT WELL IN AND B/D ALL CIRC LINES. 2/11/2023 2/11/2023 0.50 MIRU, WELCTL OWFF P OBSERVE WELL FOR FLOW. WELL IS 0.0 0.0 11:45 12:15 STATIC 2/11/2023 2/11/2023 2.25 MIRU, WELCTL NUND P FMC REP INSTALL BPV. 0.0 0.0 12:15 14:30 R/U AND PUMP DOWN IATO TEST BPV FROM BELOW. 1000 PSI, 10 MIN = GOOD TEST. 2 BBLS TO PRESSURE UP / 2 BBLS BLED BACK TO PITS. N/D TREE PER FMC REPS. SEND TREE OUT FOR INSPECTION AND RE -DRESS. 2/11/2023 2/11/2023 5.50 MIRU, WHDBOP NUND P FMC REPS ATTEMPT TO REMOVE 0.0 0.0 14:30 20:00 STRAIGHT BORE METAL SEAL FROM TUBING HANGER = UNSUCCESSFUL. STEAM HANGER AND R/U PULLER, WORK METAL SEAL FREE. 2/11/2023 2/11/2023 1.00 MIRU, WHDBOP NUND P INSPECT HANGER THREADS = 0.0 0.0 20:00 21:00 GOOD. DRESS TOP OF HANGER NECK. INSTALL BLANKING PLUG AND SPEED HEAD AS PER FMC REPS 2/11/2023 2/12/2023 3.00 MIRU, WHDBOP NUND P R/U AND N/U ADAPTER FLANGE AND 0.0 0.0 21:00 00:00 BOP STACK 2/12/2023 2/12/2023 6.00 MIRU, WHDBOP NUND P CONTINUE TO N/U BOP. INSTALL 0.0 0.0 00:00 06:00 DUTCH RISER. REMOVE CHOKE HARDLINE EXTENSION DUE TO PRODUCTION TIE IN MANIFOLD BEING IN THE WAY OF NORMAL LINE UP. M/U CHOKE AND KILL LINES TO BOP STACK. TORQUE UP ALL CONNECTIONS ON BOP STACK. M/U FLOOR VALVES FOR TESTING. R/U TEST PUMP AND EQUIPMENT. FABRICATE RISER FOR CORRECT FITMENT. CONTINUE TO LOAD AND PROCESS 41/2" TUBING IN PIPE SHED. 2/12/2023 2/12/2023 3.50 MIRU, WHDBOP NUND P ENERGIZE KOOMEY FILL STACK 0.0 0.0 06:00 09:30 AND ATTEMPT BODY/SHELL TEST. FOUND LEAK ON CHOKE HCR. REPLACE CHOKE HCR. 2/12/2023 2/12/2023 1.50 MIRU, WHDBOP NUND P FINISH N/U BOPE AND TEST 0.0 0.0 09:30 11:00 EQUIPMENT 2/12/2023 2/12/2023 2.00 MIRU, WHDBOP NUND P PERFORM SHELL TEST. FIND LEAKS 0.0 0.0 11:00 13:00 ON CHOKE AND KILL LINES IN HALLWAYS, CHOKE LINE IN CELLAR, AND FLANGE ABOVE MUD CROSS. TIGHTEN ALL CONNECTIONS = UNSUCCESSFULL. Page 317 Report Printed: 3/13/2023 Operations Summary (with Timelog Depths) CD3-302 9.6 RIG RELEASE DATE 2/16/2023 ConoWPh➢tips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Stan Depth hi End Depth (ftKB) 2/12/2023 2/12/2023 9.00 MIRU, WHDBOP NUND T DRAIN AND BLOW DOWN BOP 0.0 0.0 13:00 22:00 STACK.REPLACE SEAL RINGS ON ALL LEAKING CONNECTIONS. AND RE -TORQUE. PERFORM SHELL TEST. CHOKE AND KILL LINE CONNECTIONS ARE STILL LEAKING.TIGHTEN CONNECTIONS AGAIN. INSTALL NEW CLAMPSAND SEAL RINGS IN TOP AND BOTTOM OF KILL LINE IN HALLWAY. RE - TORQUE FLANGE CONNECTION BELOW LOWER PIPE RAMS. 2/12/2023 2/13/2023 2.00 MIRU, WHDBOP BOPE P PERFORM INITIAL BOPE TEST. 0.0 0.0 22:00 00:00 TEST ANNULAR TO 250 PSI LOW, 3500 PSI HIGH, 5 MIN EA. TEST ALL RAMS, HCR'S, CHOKE VALVES, IBOP'S,AND FLOOR VALVES TO 250 PSI LOW, 5000 PSI HIGH, 5 MIN EA. USE 4 1/2" TEST JOINT. ALL TESTS WITNESS BY AOGCC INSPECTOR ADAM EARL 2/13/2023 2/13/2023 2.50 MIRU, WHDBOP BOPE P PERFORM INITIAL BOPE TEST. TEST 0.0 0.0 00:00 02:30 ANNULAR TO 250 PSI LOW, 3500 PSI HIGH, 5 MIN EA. TESTALL RAMS, HCR'S, CHOKE VALVES, IBOP'S, AND FLOOR VALVES TO 250 PSI LOW, 5000 PSI HIGH, 5 MIN EA. USE 4 1/2" TEST JOINT. PERFORM KOOMEY TEST ALL TESTS WITNESS BY AOGCC INSPECTOR ADAM EARL 2/13/2023 2/13/2023 1.00 COMPZN, RPCOMP RURD P DRAIN STACKAND BLOW DOWN ALL 0.0 0.0 02:30 03:30 LINES. RID TEST EQUIPMENT. 2/13/2023 2/13/2023 2.00 COMPZN, RPCOMP RURD P R/U DOYON CASING EQUIPMENT. 0.0 0.0 03:30 05:30 2/13/2023 2/13/2023 2.50 COMPZN, RPCOMP THGR P CHECK FOR PRESSURE = WELL IS 0.0 0.0 05:30 08:00 STATIC. PULL BPV WITH T-BAR. MAKE UP LANDING JOINT TO HANGER, ENSURE NO PRESSURE ON IA. BACK OUT LDS PER FMC REP. PULL HANGER TO RIG FLOOR. PUWT = 135K OFF SEAT. LID HANGER AND REMOVE FROM RIG FLOOR. LOAD COMPLETION PACKER AND JEWELRY INTO PIPE SHED. 2/13/2023 2/13/2023 3.50 COMPZN, RPCOMP PULD P PULLAND LID 4.5" IBTM 12.6# 12,060.0 10,062.0 08:00 11:30 TUBING. F/12060' T/10062' MD. PUWT = 130K 2/13/2023 2/13/2023 1.00 COMPZN, RPCOMP PULD P PROCESS PIPE IN PIPE SHED. 10,062.0 10,062.0 11:30 12:30 WRITE NUMBER, STRAPAND WRITE WELL NAME ON EACH JOINT. REMOVE PIPE FROM PIPE SHED TO CONTAINMENT AREA. 2/13/2023 2/13/2023 2.50 COMPZN, RPCOMP PULD P CONTINUE TO LID 4.5" IBTM 12.6# 10,062.0 8,360.0 12:30 15:00 TUBING F/10062' T/8360' MD. PUWT = 130K 2/13/2023 2/13/2023 1.00 COMPZN, RPCOMP PULD P PROCESS PIPE IN PIPE SHED. 8,360.0 8,360.0 15:00 16:00 WRITE NUMBER, STRAPAND WRITE WELL NAME ON EACH JOINT. REMOVE PIPE FROM PIPE SHED TO CONTAINMENT AREA. 2/13/2023 2/13/2023 4.75 COMPZN, RPCOMP PULD P CONTINUE TO LID 4.5" IBTM 12.6# 8,360.0 4,490.0 16:00 20:45 TUBING F/8360' T/4490' MD. PUWT = 115K Page 417 Report Printed: 3/13/2023 Operations Summary (with Timelog Depths) CD3-302 9.6 RIG RELEASE DATE 2/16/2023 ConoWPh➢tips Rig: DOYON 142 Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Stan Depth (ftKB) End Depth (ftKB) 2/13/2023 2/13/2023 2.25 COMPZN, RPCOMP PULD P PROCESS PIPE IN PIPE SHED. 4,490.0 4,490.0 20:45 23:00 WRITE NUMBER, STRAP AND WRITE WELL NAME ON EACH JOINT. REMOVE PIPE FROM PIPE SHED. STICKERAND STACKAT CONTAINMENT AREA. 2/13/2023 2/14/2023 1.00 COMPZN, RPCOMP PULD P CONTINUE TO L/D 4.5" IBTM 12.6# 4,490.0 3,716.0 23:00 00:00 TUBING F/4490' T/3716' MD. PUWT = 78K, SOWT = 80K 2/14/2023 2/14/2023 4.00 COMPZN, RPCOMP PULD P CONTINUE TO LAY DOWN 4.51BTM 3,716.0 0.0 00:00 04:00 TUBING F/3716'T/SURFACE.LAID DOWN 280 JTS TOTAL PLUS 19.59' CUT JOINT. 2/14/2023 2/14/2023 4.00 COMPZN, RPCOMP PULD P PROCESS PIPE IN PIPE SHED. 0.0 0.0 04:00 08:00 NUMBER, STRAP AND WRITE WELL NAME ON EACH JOINT. REMOVE PIPE FROM PIPE SHED. STICKER AND STACKAT CONTAINMENT AREA. NORM INSPECT PIPE. C/O POWER TONGS. CLEAN/CLEAR RIG FLOOR. M/U HYDRIL 563 CROSSOVER TO FOSV. PREP RIG FLOOR TO RUN TUBING 2/14/2023 2/14/2023 0.50 COMPZN, RPCOMP PULD P PJSM FOR RUNNING 4.5" HYDRIL 563 0.0 0.0 08:00 08:30 12.6# L80 TUBING 2/14/2023 2/14/2023 0.50 COMPZN, RPCOMP PULD P CONFIRM FINAL RUNNING TALLY 0.0 0.0 08:30 09:00 AND UPPER COMPLETION COMPONENTS 2/14/2023 2/14/2023 3.00 COMPZN, RPCOMP PULD P M/U COMPLETION COMPONENTS. 0.0 1,717.0 09:00 12:00 OVERSHOT, LANDING NIPPLE, PACKER, GLM W/DCK-2, 4.5" 12.6# HYD 563 TUBING, AND, UPPER LANDING NIPPLE F/SURFACE TO 1717' MD, (JT 40) PUWT/SOWT = 67K 2/14/2023 2/14/2023 6.00 COMPZN, RPCOMP PULD P CONTINUE TO RUN 4.5" HYD 563 1,717.0 7,903.0 12:00 18:00 TUBING PER TALLY F/1717' T/7903' MD. (JT41 - 190) TAKE ON BRINE TO PITS. SEND OUT OLD TUBING 2/14/2023 2/14/2023 4.50 COMPZN, RPCOMP PULD P CONTINUE TO RUN 4.5" HYD 563 7,903.0 12,020.0 18:00 22:30 TUBING PER TALLY, F/7903' T/'12020' MD. (JT190 - 290) PUWT = 142K, SOWT = 98K. M/U JOINTS 291 AND 292. 2/14/2023 2/14/2023 0.50 COMPZN, RPCOMP PULD P R/U CROSSOVER, HEAD PIN AND 12,020.0 12,020.0 22:30 23:00 CEMENT HOSE 2/14/2023 2/15/2023 1.00 COMPZN, RPCOMP HOSO P ESTABLISH CIRCULATION.2 BPM = 12,020.0 12,083.0 23:00 00:00 92 PSI. PUWT = 142K, SOWT= 98K. RIH SLOW AND OBSERVE PRESSURE INCREASE TO 210 PSI = TOP OF STUMPAT 12076' MD. SHUT DOWN PUMP AND OPEN BLEEDER. CONTINUE TO SLACK OFF. OBSERVE OVERSHOT PINS SHEAR-OUTAT 85K, THEN SOWT RETURN TO 98K. CONT SLACK OFF TO NO-GO @J 12083' MD. PULL UP TO PUWT OF 142K AND MARK PIPE AND DETERMINE SPACE -OUT MEASUREMENT. 2/15/2023 2/15/2023 1.00 COMPZN, RPCOMP HOSO P LID 3 JOINTS -292, 291, AND 290. 12,083.0 11,980.0 00:00 01:00 F/12083' T/11980'. BRING NEEDED PUP JOINTS TO RIG FLOOR. Page 517 Report Printed: 3/13/2023 Operations Summary (with Timelog Depths) CD3-302 9.6 RIG RELEASE DATE 2/16/2023 Cori.a>hil ips Rig: DOYON 142 Job: RECOMPLETION Time Log Stim Time ErM Time Dur(hr) Phase Activity Code Time P-T.X Operation Start Depth(WB) End Deptth(MB) 2/15/2023 2/15/2023 1.00 COMPZN, RPCOMP THGR P M/U 3 SPACE -OUT PUPS, 9.77, 9.78. 11,980.0 12,047.0 01:00 02:00 AND 3.91 = 23.46. M/U JOINT 290. M/U XO, TIW, HEAD PIN AND CEMENT HOSE TO LANDING JOINT. M/U LANDING JOINT TO HANGER, M/U HANGER TO TUBING STRING AND ORIENT PER FMC REP 2/15/2023 2/15/2023 2.50 COMPZN, RPCOMP CRIH P CIRCULATE 408 BBLS OF 12,047.0 12,047.0 02:00 04:30 CORROSION INHIBITED SEAWATER SURFACE TO SURFACE. 3 BPM = 200 PSI. DRAIN BOP STACK. 2/15/2023 2/15/2023 0.50 COMPZN, RPCOMP THGR P LAND HANGER IN WELL HEAD. 12,047.0 12,080.0 04:30 05:00 BOTTOM OF OVERSHOT AT 12080' MD. 2/15/2023 2/15/2023 2.50 COMPZN, RPCOMP PRTS P MAKE MULTIPLE ATTEMPTS TO TEST 12,080.0 12,080.0 05:00 07:30 HANGER SEALS TO 5000 PSI ON CHART. UNSUCCESSFUL. 2/15/2023 2/15/2023 0.50 COMPZN, RPCOMP PRTS P RIG UP FMC HYDRAULIC FOOT 12,080.0 12,080.0 07:30 08:00 PUMP DIRECTLY TO TREE VALVE WITH MECHANICAL GAUGE. TEST HANGER SEALS TO 5000 PSI, 15 MIN. WITNESSED BY FMC AND CPAI REP. TEST SUCCESSFUL 2/15/2023 2/15/2023 0.50 COMPZN, RPCOMP PRTS P DISCUSS OPTIONS WITH TOWN. 12,080.0 12,080.0 08:00 08:30 RIG UP AND SEAT VALVE SEATS ON #1 MUD PUMP. 2/15/2023 2/15/2023 3.50 COMPZN, RPCOMP PRTS P R/U CHART RECORDER DIRECTLY 12,080.0 12,080.0 08:30 12:00 TO TREE VALVE. TEST TO 5000 PSI 15 MIN. CHARTED = UNSUCCESSFUL. RID CHART. RIG UP FMC HYDRAULIC FOOT PUMP DIRECTLYTO TREE VALVE WITH MECHANICAL GAUGE. TEST HANGER SEALS TO 5000 PSI, 15 MIN. WITNESSED BY FMC AND CPAI REP. TEST SUCCESSFUL 2/15/2023 2/15/2023 0.50 COMPZN, RPCOMP PACK P DROP 1.75" BALL AND ROD PER 12,080.0 12,080.0 12:00 12:30 BAKER REP 2/15/2023 2/15/2023 2.50 COMPZN, RPCOMP PRTS P BALL ON SEAT, PRESSURE UP ON 12,080.0 12,080.0 12:30 15:00 TUBING TO SET PACKER. WITH PACKER SET, PRESSURE TEST TUBING T/4000 PSI, 30 MIN, CHARTED. 2/15/2023 2/15/2023 1.00 COMPZN, RPCOMP PRTS P BLEED TUBING DOWN TO 2000 PSI. 12,080.0 12,080.0 15:00 16:00 PRESSURE UP ON IA TO 3000 PSI, 30 MIN, CHARTED. QUICKLY BLEED OFF PRESSURE ON TUBING TO SHEAR SOV 2/15/2023 2/15/2023 0.50 COMPZN, WHDBOP MPSP P RID TEST EQUIPMENTAND BLOW 12,080.0 12,080.0 16:00 16:30 DOWN LINES. BACK OUT LANDING JOINT PER FMC REP. SET BPV. TEST TO 1000 PSI, 10 MIN, CHARTED, RID TEST EQUIP. 2/15/2023 2/15/2023 1.00 COMPZN, WHDBOP PRTS P TEST BPV TO 1000 PSI, 10 MIN, 12,080.0 12,080.0 16:30 17:30 CHARTED, RID TEST EQUIP. 2/15/2023 2/15/2023 3.00 COMPZN, WHDBOP NUND P N/D KILL LINE, CHOKE LINE, RISER, 12,080.0 12,080.0 17:30 20:30 DUTCH RISER, N/D BOP STACK, RACK BACK ON STUMP AND SECURE Page 617 Report Printed: 3/13/2023 Operations Summary (with Timelog Depths) CD3-302 RIG RELEASE DATE 2/16/2023 con«oannrps Rig: DOYON 142 Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Corte Time P-T-X Operation Stan Depth (flKB) End Depth (flKB) 2/15/2023 2/15/2023 2.00 COMPZN, WHDBOP NUND P N/D SPEED HEAD AND ADAPTER 12,080.0 12,080.0 20:30 22:30 AND LIFT TO BOP DECK. LIFT TREE TO BOP DECK TO WARM AREA. NIPPLE UP TREE TO WELL HEAD PER FMC. SIMOPS - EMPTY MUD PITS OF SEA WATER. BLOW DOWN RIG WATER. ORGANIZE PAD FOR RIG MOVE 2/15/2023 2/15/2023 1.00 COMPZN, WHDBOP SEQP P R/U TEST EQUIP AND TEST HANGER 12,080.0 12,080.0 22:30 23:30 VOID T/5000 PSI, 10 MIN. WITNESS BY FMC AND CPAI REP. FILL TREE AND PURGE ALL TEST LINES WITH DIESEL. 2/15/2023 2/16/2023 0.50 COMPZN, WHDBOP SEQP P R/U TEST EQUIP TO TREE. ATTEMPT 12,080.0 12,080.0 23:30 00:00 TO TEST TREE, 250 PSI LOW, 5000 PSI HIGH ON CHART. 2/16/2023 2/16/2023 1.00 COMPZN, WHDBOP SEQP P CONT. TEST TREE. 5000 PSI, 5 MIN, 12,080.0 12,080.0 00:00 01:00 CHARTED. RIG DOWN TEST EQUIP. 2/16/2023 2/16/2023 1.00 COMPZN,WHDBOP MPSP P PULL BPV. 12,080.0 12,080.0 01:00 02:00 R/U CIRCULATING MANIFOLD TO IA, TUBING AND TIGER TANK. IN PREP FOR FREEZE PROTECT AND U- TUBE. 2/16/2023 2/16/2023 0.75 COMPZN, WHDBOP FRZP P R/U LRS HOT OIL TRUCK. PT LINES 12,080.0 12,080.0 02:00 02:45 TO 2000 PSI. PUMP 72 BBLS FREEZE PROTECT DIESEL DOWN IA. 2 BPM = 500 PSI. TAKE TUBING RETURNS TO TIGER TANK. RID LRS. BLOW DOWN ALL LINES. 2/16/2023 2/16/2023 0.75 COMPZN, WHDBOP FRZP P LINE UP CIRC MANIFOLD TO IAAND 12,080.0 12,080.0 02:45 03:30 TUBING. ALLOW DIESEL TO U-TUBE. SIMOPS / REMOVE CABLES FROM SKATE RAILS IN PREP FOR RIG MOVE. 2/16/2023 2/16/2023 0.50 COMPZN, WHDBOP MPSP P INSTALL BPV. SECURE WELL. 12,080.0 12,080.0 03:30 04:00 TUBING = 0 PSI. IA = 0 PSI, OA= 280 PSI RELEASE RIG 2/16/2023 @ 04:00 Page 717 Report Printed: 3/13/2023 CD2-302A RWO Summary of Operations DTTMSTART JOBTYP SUMMARYOPS 1/14/2023 ACQUIRE DATA JUMP OFF ALL EQUIPMENT, SPOT EQUIPMENT. TROUBLE SHOOT TRI PLEX. JOB IN PROGRESS. 1/15/2023 ACQUIRE DATA DRIFTED 3.84" TO Al INJ VLV @ 2062' RKB. PULLED Al INJ VLV (HSS-157 ). DRIFTED 3.79" TO XN NIPPLE @ 12,160' RKB; OBTAIN SBHPS @ 12,100' RKB & 11,851' RKB (MAX PSI: 4800, MAX TEMP: 122'); SET 3.81" PXN PLUG BODY @ 12,160' RKB; SET BAITED P PRONG @ SAME; OBTAIN PASSING CMIT. AND DRAW DOWN TEST TO 1000 PSI, PLUG HOLDING. PULLED DMY VLV @ 12,029' RKB, POCKET LEFT OPEN, READY FOR ELINE TBG CUT. JOB IN PROGRESS. 1/19/2023 ACQUIRE DATA (PRE RWO) FUNCTION TEST ALL T & IC LDS/GNS (COMPLETE), SBMS (PASSED), T POT (PASSED), T PPPOT (PASSED), LOWER M2M (PASSED), IC POT (PASSED), IC PPPOT (PASSED) 1/20/2023 ACQUIRE DATA (PRE RWO) SCLD/ GAS MIT-OA PASSED TO 1200 PSI 1/29/2023 ACQUIRE DATA (PRE RWO) BLEED OA (COMPLETE) 2/2/2023 PUMPING TRACKING OA FILL UP. PUMP 28 BBLS DIESEL DOWN OA. ONLY JOB COMPLETE 2/5/2023 ACQUIRE DATA PERFORM PRE-RWO TUBING CUT WITH WELLTECH MECHANICAL CUTTER AT 12,066' RKB, MIDDLE OF THE FIRST FULL JOINT ABOVE THE PACKER. READY FOR BPV. 2/6/2023 ACQUIRE DATA (Pre RWO) T X IA DDT PASSED, SET BPV 2/9/2023 RECOMPLETION SPLIT RIG MODULES AND STAGE FOR TRANSPORT TO CD3-302A. TRANSPORT ALL MODULES IN 2 CONVOYS TO CD3-302A. SPOT SUB OVER WELL AND SKID RIG FLOOR 2/10/2023 RECOMPLETION SPOT ALL RIG MODULES IN PLACE AND CONNECT SERVICE LINES. COMPLETE RIG ACCEPTANCE CHECK LIST FOR RIG ACCEPTANCE. 2/11/2023 RECOMPLETION ACCEPT RIG 2/11/23 @ 00:01 HRS. BEGIN WELL WORK. LOAD PIPE SHED. DISPLACE WELL TO SEAWATER. NIPPLE DOWN TREE. NIPPLE UP BOP. 2/1212023 RECOMPLETION NIPPLE UP BOPE. RIG UP TEST EQUIPMENT. TEST BOPE WITH AOGCC STATE REP. 2/13/2023 RECOMPLETION COMPLETE BOPE TEST WITH AOGCC STATE REP. PULL AND LAY DOWN HANGER. PULL AND LAY DOWN 4.5" IBTM TUBING 2/14/2023 RECOMPLETION COMPLETE LAY DOWN OF 4.5" IBTM TUBING. PREP 4.5" HYDRIL 563 TUBING AND PACKER RUN 4.5" COMPLETION 2/15/2023 RECOMPLETION LAND HANGER, SET PACKER, TEST TUBING AND IA, N/D BOP, N/U TREE, 2/16/2023 RECOMPLETION TEST TREE, PUMP FREEZE PROTECT, SET BPV. RELEASE RIG AT 04:00 WNS INJ WELLNAME CD3-302A WELLBORE CD3-302A C XX=:)PII11lps Alaska, Inc. Minaret -GAs PenrareM CUT PACKER, TUBING PERF: INTERMEDIATE', Well Attributes I Max Angle&MD TO FIeM Name WNII-m APWWI Welln°re Sam", Iis" FI RDK PAR K ,020221 IN 8.48 MB(nKBI 11,63423 Aci.1. B7KB) 12,603D Comment Xis 1ppm) Gate Anent n Last WO: Entl UsesKBGN 2 MoI023 V-) 35T9 RR DaR 4I18I2010 UnerIN— Elevation Ammtalicn Depth NtKBI 1 WNlbore End Dole Last M°E By Last Tag: SLM 12,449.0 CO3-302A IN '2011Funern Last Rev Reason Annotation WeIINrt 1 End Dole 1 Last Mod By Rev Reason: Cut Tubing CU3302A "b"U23 I mount, Notes: General & Safety MnoMian End Doh 1 Land, Mod By NOTE: Welded 9"x0.50d Conductor maturing ooD,U22 jammer NOTE Well SIDETRACKED, OLD PROD CSG CUT @26]3' 1 41I Pule I eaden Casing Strings CaB Do' oD lint ID (in) sd Depth set Top (nKe) (nKB) 1DI(nKB) Bepm Parson (to.)Grade Top Trood INTERMEDIATE T 6.28 24.8 12592.9 6,9362 26A0 L-90 BTCM Tubing Strings: string max indicates LONGEST segment of string Top take) set oeptn...setDepth-SYdng Ma... Tuntoe Descripron W[PtdRl Graae Top connection ID (in) 20.5 120]25 6,fi90.6 4112 Tubing- Completion Upper 12.60 L-B0 HVd563 3.96 Completion Details: excludes tubing, pup, space out, thread, IRKS... TOPIM(B) Top ITVDI IINBI Top In PI Ile. Dec oD Pleaded (in) Com Maka MOM, Nominal ID (in) 2,160.4 2,070.2 33.82 Nipple- Landing 4.500 HES 3.813" Landing Nipple X' HES XNipple 3.833 11,925.3 6,631.3 66.58 Mandrel - GAS LIFT 4.500 Camco DCK-2 GLM (3.883"ID) Conics DCK-2 GLM 3.860 11,988.2 6,656.4 66.29 Permanent Packer 5.720 Tx 4%D B L Packer D&L Packer 4.000 12,049.E 6,681.2 66.01 NiDDIe- Lending 4.500 HES 3.813" Landing NiDDle"X" HES XNipple 3.813 12,066.4 6,698.1 65.93 Overshot 5.960 Baker PoorBoy Over Shot 5' of Baker swallow Spared T off NoGo Oversho t 4.670 Top lnKBl Stl OeptM1...se[DegM1... 12,Ofi8.6 12211.9 S[ring Ma... Tuning Deacrlption NY(Ib'XI Grade Tap Conneadon lD (n) 6,748.E 4112 Tubing -Completion Lower 12.60 L-BO IBTM 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Toppili Top Mot MKBI Top lnal PI Nem Dec oD Nomind (in) Com Make MOMI Nominal ID (in) 12,098.5 6,701.2 65.78 PACKER 5.970 BAKER PREMIER PACKER Baker Premier 3.875 12,160.6 6,726.9 65.28 NIPPLE 5.9B4 HES'XN' NIPPLE (3.B13-ID HES W13J25" NO 60) XN 3.725 12,210.5 6,748.0 64.86 WLEG 5.312 WIRELINE ENTRY GUIDE 4.000 Other In Hole (Wlreline retrievable plugs, valves, pumps, fish, etc.) Top (1KB) Top RVD) (nKB) Top Intl C) Dea an. Make Model sN Run been ID Urd 12,068.8 6,689.1 65.92 CUT WELLTECH MECHANICAL CUTTER CUT 2UV2023 3.960 12,160.6 6,726.9 65.28 TUBING PLUG SET AND TESTED 3.813" PXN PLUG, 4.5"BAIT SUB& P PRONG (DAL = 86") 1I15R023 0.000 Mandrel Inserts : excludes pulled inserts Top NM6) To pI in st B Top on I66.53 Nf Sery Vaps Type LNCM1 Ty% OD IIn) TRORun I%I) Run Dole Cmn Meke Modtl PM Slie lln) 11,925.3 6631 6fi31.3 6658 1 SOV 1 2I14I2023 Camco DCK-2 GLM Perforations & Slots Top InKB) Btm IflKB) eIXB) BftnRV d1KB) finked Zone Data Shot Dena is Dens Type Core 12,3fi1.0 12,311.0 IsInit0 6,818.E KUPO,CDI 302A 4124WIU I 6.0 I IPERF Y1I8"MUTILNIUM wI60 GUN deg phase 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Plugs (MD): Junk (MD): 12603'None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 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 and Digital Signature with Date: AOGCC USE ONLY Adam Klem adam.klem@conocophillips.com (907) 263-4529 Senior RWO/CTD Engineer Tubing Grade: Tubing MD (ft): 12098' MD and 6701' TVD 2062' MD and 1988' TVD Perforation Depth TVD (ft): Tubing Size: L-80 12212' 2/12/2023 Packer: Baker Premier Packer SSSV: Camco DB Landing Nipple STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0364471, ADL0372104, ADL0372105 210-035 P.O. Box 100360, Anchorage, AK 99510 50-103-20522-01-00 ConocoPhillips Alaska, Inc. CRU CD3-302A Fiord Kuparuk Oil PoolFiord Kuparuk Oil PoolColville River Field, N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 6941' 12449' 6856' None MD 115' 2495' 6935' 115' 2669' 12593' 16" 9-5/8" 77' 2642' Perforation Depth MD (ft): 7"12568' 12361-12371' MD 6814-6819' TVD 4-1/2" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov MPSP (psi): 4130 By Samantha Carlisle at 2:10 pm, Jan 17, 2023 323-027 Adam Klem Digitally signed by Adam Klem Date: 2023.01.17 10:37:08 -09'00' DLB 01/18/2022 X DSR-1/17/23 X BOP test to 4500 psig Annular test to 2500 psig 10-404 X X VTL 1/23/2023GCW 01/23/23 JLC 1/23/2023 1/23/23Brett W. Huber. Sr.Digitally signed by Brett W. Huber. Sr. Date: 2023.01.23 14:56:15 -09'00' RBDMS JSB 012523 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 17, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Adam Klem Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over WNS Injector CD3-302A (PTD# 210-035). Well CD3-302A was drilled in 2010 as a MI injector of the Fiord Kuparuk. It appears to have tubing connections that leak on gas and it has become a RWO candidate. If you have any questions or require any further information, please contact me at 907-263-4529 The tubing will be cut and pulled above the current production packer and a new 4.5" completion with a non sealing overshot and new packer will be ran. Adam Klem Digitally signed by Adam Klem Date: 2023.01.17 10:37:23 -09'00' CD3-302A RWO Procedure Fiord Kuparuk Injector Pull and Replace Tubing PTD #210-035 Page 1 of 2 Remaining Pre-Rig Work 1. T&IC-PPPOT and T&IC-POT tests. 2. Set plug in nipple at 12,160’ MD 3. MIT-T, MIT-IA 4. Pull GLV for circulation 5. Cut tubing at ~12,080’ MD 6. Prepare well for rig arrival within 48-72 hours of rig arrival. Rig Work MIRU 1. MIRU Doyon 142 on CD3-302A. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/4,500 psi. Test annular 250/2,500 psi. Retrieve Tubing 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2” tubing down to pre rig cut (~12,080’). Install new 4-½” Tubing 6. MU 4 ½” completion with overshot, nipples, packer, GLM. 7. RIH with completion. Overshot tubing stub. 8. Space out as needed. Land tubing and RILDS. Test packoffs. 9. Drop ball and rod. 10. Pressure up tubing to set packer 11. Pressure test tubing to 4000 psi for 30 minutes and chart. 12. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 13. Confirm pressure tests, then shear out SOV with pressure differential. 14. Install BPV. Test BPV as needed. 15. ND BOPE. NU tree. 16. Pull BPV, freeze protect well if necessary. 17. RDMO. Post-Rig Work 18. Pull ball and rod 19. Pull RHC plug 20. Pull SOV. Install DV 21. MITT 22. Pull plug set in nipple 23. Install A1 injection valve in shallow nipple 24. Turn over to operations. General Well info: Wellhead type/pressure rating: FMC Horizontal, 5M psi top flange State witnessed MIT-IA required after stabilized injection. VTL 1/23/23 CD3-302A RWO Procedure Fiord Kuparuk Injector Pull and Replace Tubing PTD #210-035 Page 2 of 2 Production Engineer: Mark Shulman Reservoir Development Engineer: Adam Childs Estimated Start Date: 02/12/2023 Workover Engineer: Adam Klem (263-4529/ adam.klem@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Injector Scope of Work: Pull the existing 4-1/2” completion from planned pre rig cut. Run new 4-1/2” completion and stack new packer. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T planned pre rig MIT-IA: passed 6/7/22 IC POT &PPPOT PASSED – 4/1/22 TBG POT &PPPOT PASSED – 4/1/22 MPSP: 4130 psi using 0.1 psi/ft gradient Static BHP: 4800 psi / 6702 TVD measured on 1/15/2023 CD3-302A Proposed RWO Completion PROPOSED TUBING COMPLETION •4-½" 12.6# L-80 HYD 563 •4-½" DB landing nipple @ ~2,100' MD' (3.813" min ID) •4-½"Camco KBG-2 gas lift mandrel @ ~11,078' MD •D&L Permanent Packer @ ~12,000' MD (4" ID) •4-½" X landing nipple@ ~12,040' MD (3.813" min ID) •4-½"Non-sealing Overshot @ ~12,069' MD REMAINING COMPLETION LEFT IN HOLE •Baker Premier Packer @ 12,099' MD •HES XN Nipple @ 12.160' RKB •WLEG @ 12,210' MD 9-5/8" 40# L-80 shoe @ 2,669' MD 7" 26# L-80 shoe @ 12,593' MD 16" 54.5# H-40 shoe @ 114' MD C-sand perfs 12391' - 12371' RKB Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: SLM 12,449.0 9/23/2011 CD3-302A ninam Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pull XXN plug, Set Injection Valve 6/9/2022 CD3-302Aoberr Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 37.7 Set Depth (ftKB) 114.8 Set Depth (TVD)… 114.7 Wt/Len (lb… 54.50 Grade H-40 Top Connection WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 27.4 Set Depth (ftKB) 2,669.1 Set Depth (TVD)… 2,495.1 Wt/Len (lb… 40.00 Grade L-80 Top Connection BTC Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 24.8 Set Depth (ftKB) 12,592.9 Set Depth (TVD)… 6,935.2 Wt/Len (lb… 26.40 Grade L-80 Top Connection BTCM Tubing Strings: string max indicates LONGEST segment of string Tubing Description TUBING String … 4 1/2 ID (in) 3.96 Top (ftKB) 21.7 Set Depth (ft… 12,211.9 Set Depth (TVD… 6,748.6 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Item Des Nominal ID (in) OD Nominal (in)Make Model 21.7 21.7 0.00 HANGER 3.958 11.000 2,062.1 1,988.1 32.63 NIPPLE 3.813 5.570 CAMCO DB 12,029.7 6,673.2 66.10 GAS LIFT 3.860 5.984 CAMCO KBG-2 12,098.5 6,701.2 65.78 PACKER 3.875 5.970 Baker Premier 12,160.6 6,726.9 65.28 NIPPLE 3.725 5.984 HES XN 12,210.5 6,748.0 64.86 WLEG 4.000 5.312 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 2,062.1 1,988.1 32.63 VALVE 3.81" Injection Valve on DB Lock Set in DB nipple, Closure test Good 6/9/2022 1.250 HSS-157 Mandrel Inserts : excludes pulled inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 12,029.7 6,673.2 66.10 1 GAS LIFT DMY INT 0.000 0.06/7/2022 Fruit. Ext. Pkg. Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 12,361.0 12,371.0 6,814.0 6,818.6 KUPC, CD3- 302A 4/23/20106.0 IPERF 3-1/8" MILLENIUM GUN w/60 deg phase Notes: General & Safety End Date Annotation 4/5/2022 NOTE: Welded 9"x0.500" Conductor extension 4/19/2010 NOTE: View Schematic w/ Alaska Schematic9.0 4/18/2010 NOTE: Well SIDETRACKED, OLD PROD CSG CUT @ 2673' CD3-302A, 6/9/2022 5:13:01 PM Vertical schematic (actual) INTERMEDIATE; 24.8-12,592.9 Float Shoe (Silver Bullet); 12,590.7-12,592.9 Float Collar (Weatherford); 12,505.9-12,506.8 IPERF; 12,361.0-12,371.0 WLEG; 12,210.5 NIPPLE; 12,160.6 PACKER; 12,098.5 GAS LIFT; 12,029.7 SURFACE; 27.4-2,669.1 SHOE; 2,667.7-2,669.1 FLOAT COLLAR; 2,588.9- 2,590.3 VALVE; 2,062.1 NIPPLE; 2,062.1 CONDUCTOR; 37.7-114.7 HANGER; 27.4-29.6 Hanger; 24.8-27.4 HANGER; 21.7 WNS INJ KB-Grd (ft) 43.18 RR Date 4/18/2010 Other Elev… CD3-302A ... TD Act Btm (ftKB) 12,603.0 Well Attributes Field Name FIORD KUPARUK Wellbore API/UWI 501032052201 Wellbore Status INJ Max Angle & MD Incl (°) 68.48 MD (ftKB) 11,634.23 WELLNAME WELLBORE Annotation Last WO: End Date 4/16/2010 H2S (ppm)DateComment SSSV: WRDP CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL]FW: CPAI application CD3-302A AA received072122.pdf Date:Tuesday, August 30, 2022 2:07:52 PM Attachments:image001.png CD3-302A Diagnostic MIT-IA 1 April 22.xlsx CD3-302A Diagnostic MIT-T 31 March 22.xlsx From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, August 24, 2022 10:37 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL]FW: CPAI application CD3-302A AA received072122.pdf Chris- Attached are the 10-426 forms for the diagnostic MIT-T and MIT-IA Kate referenced in her AA request. Please let me know if you have any questions or concerns. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Friday, August 5, 2022 11:57 AM To: Freeborn, Dusty <Dusty.Freeborn@conocophillips.com> Cc: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: [EXTERNAL]FW: CPAI application CD3-302A AA received072122.pdf CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Dusty – Kate says you are in charge while she is out of the office… Thanks Chris From: Wallace, Chris D (OGC) Sent: Friday, August 5, 2022 11:53 AM To: kate.dodson@conocophillips.com Subject: FW: CPAI application CD3-302A AA received072122.pdf Kate, I am processing this CD3-302A AA request and I do not have a record of the mentioned MIT-IA and MIT-T of April 2022. Please provide so we may continue our review. I have an email from Travis dated 2/16/2022 for the first notification of potential TxIA, and I have the record of the passing witnessed MITIA of 2/14/2022. So I would need a valid MITIA after the communication was discovered to proceed with this application. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Carlisle, Samantha J (OGC) <samantha.carlisle@alaska.gov> Sent: Thursday, July 21, 2022 12:32 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: CPAI application CD3-302A AA received072122.pdf Docket number AIO-22-021 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 210-035 Type Inj W Tubing 1050 1300 1300 1300 Type Test P Packer TVD 6701 BBL Pump 3.7 IA 300 3000 2990 2985 Interval O Test psi 1675 BBL Return OA 180 200 200 200 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Alpine/ CRU / CD3 Pad Hills 04/01/22 Notes:Non-witnessed diagnostic MIT-IA Notes: CD3-302 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)CD3-302A Diagnostic MIT-IA 1 April 22 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 210-035 Type Inj W Tubing 1825 3000 2910 2875 Type Test P Packer TVD 6701 BBL Pump 1.2 IA 385 487 483 480 Interval O Test psi 1675 BBL Return OA 193 194 194 194 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Alpine/ CRU / CD3 Pad Hembra 03/31/22 Notes:Non-witnessed diagnostic MIT-T Notes: CD3-302 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)CD3-302A Diagnostic MIT-T 31 March 22 Submit to: OPERATOR: FIEL D /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2100350 Type Inj N Tubing 1950 1950 1950 1950 Type Test P Packer TVD 6701 BBL Pump 1.9 IA 1469 2968 2968 2962 Interval O Test psi 1675 BBL Return OA 212 200 200 200 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechan ic al Integ rity Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:Diagnostic Test performed on CD3-302A during the course of slickline work. Notes: CD3-302A Notes: Notes: Notes: ConocoPhillips Alaska Inc, Alpine / CRU / CD3 PAD N/A Ober 06/07/22 Form 10-426 (Revised 01/2017)2022-0607_MIT_CRU_CD3-302A Diagnostic Test performed on CD3-302A during the course of slickline work. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Alpine CRU injector CD3-302A (PTD# 210-035) was reported with high IA pressure Date:Thursday, July 21, 2022 8:56:23 AM Attachments:image001.png From: Dodson, Kate <Kate.Dodson@conocophillips.com> Sent: Wednesday, July 20, 2022 11:31 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Well Integrity Specialist CPF2 <n2549@conocophillips.com>; Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: Alpine CRU injector CD3-302A (PTD# 210-035) was reported with high IA pressure Hi Chris, CRU CD3-302A (PTD# 210-035) has completed the 30 day monitor period on water-only injection. The IA has stabilized. CPAI plans to submit the paperwork for a waiver to operate on water-only injection. Our plan is to keep the well on water-injection while the paperwork is processed. Please let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Intervention Engineer ConocoPhillips Alaska | Wells Engineering O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com From: Smith, Travis T Sent: Tuesday, June 28, 2022 5:04 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: Alpine CRU injector CD3-302A (PTD# 210-035) was reported with high IA pressure Chris— A status update on CRU injector CD3-302A (PTD# 210-035). After we performed the wellwork described below (swapping the dummy valve and pulling the tubing tail plug), we decided internally it would be more cautious to begin with a water injection trial on this well given the operational and logistics constraints of the CD3 drillsite. We have put the well back on water injection for a 30-day monitoring period at which point we will evaluate putting it on gas injection for a 30-day monitoring period per the original plan. We will inform you of the results of this injection monitoring. Please let me know if you have any questions or disagree with the plan. Thanks, Travis From: Smith, Travis T Sent: Wednesday, April 20, 2022 4:27 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: Alpine CRU injector CD3-302A (PTD# 210-035) was reported with high IA pressure Chris— I wanted to give you an update on CRU injector CD3-302A (PTD# 210-035). DHD performed several diagnostics on the well after the plug was set, including an MIT-T, MIT-IA, and packoff testing. All of these passed. These tests, and the circumstances of the original issue, indicate the well has a gas-only leak. Our path forward is to swap the dummy valve with a high-sealibility dummy valve. Then, pull the tubing tail plug and determine if the issue has been resolved with a 30-day monitoring period on gas injection. We will notify you of the results of this work and any further actions at the point. Please let me know if you have any questions or disagree with the plan. Thanks, Travis From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Tuesday, March 22, 2022 5:04 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Smith, Travis T <Travis.T.Smith@conocophillips.com>; Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: Alpine CRU injector CD3-302A (PTD# 210-035) was reported with high IA pressure Chris- Alpine CRU injector CD3-302A (PTD# 210-035) was reported with high IA pressure requiring multiple IA bleeds. Slickline and LRS were immediately deployed and a tubing plug is in the process of being set. With the tubing loaded, the IA pressure is now stable under the DNE of 2400 psi. The well recently was under observation for suspected TxIA on gas injection and passed an MIT-IA to 4200 psi and an IA DDT was currently “in progress”. When the well is secured with a down hole plug, additional diagnostics to investigate the source of the high IA pressure will be conducted. Once the diagnostics have been completed, the proper paperwork for continued injection or repair will be submitted as required. Attached is the current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Alpine CRU injector CD3-302A (PTD# 210-035) was reported with high IA pressure Date:Thursday, June 30, 2022 11:28:21 AM Attachments:image001.png From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Tuesday, June 28, 2022 5:04 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: Alpine CRU injector CD3-302A (PTD# 210-035) was reported with high IA pressure Chris— A status update on CRU injector CD3-302A (PTD# 210-035). After we performed the wellwork described below (swapping the dummy valve and pulling the tubing tail plug), we decided internally it would be more cautious to begin with a water injection trial on this well given the operational and logistics constraints of the CD3 drillsite. We have put the well back on water injection for a 30-day monitoring period at which point we will evaluate putting it on gas injection for a 30-day monitoring period per the original plan. We will inform you of the results of this injection monitoring. Please let me know if you have any questions or disagree with the plan. Thanks, Travis From: Smith, Travis T Sent: Wednesday, April 20, 2022 4:27 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: Alpine CRU injector CD3-302A (PTD# 210-035) was reported with high IA pressure Chris— I wanted to give you an update on CRU injector CD3-302A (PTD# 210-035). DHD performed several diagnostics on the well after the plug was set, including an MIT-T, MIT-IA, and packoff testing. All of these passed. These tests, and the circumstances of the original issue, indicate the well has a gas-only leak. Our path forward is to swap the dummy valve with a high-sealibility dummy valve. Then, pull the tubing tail plug and determine if the issue has been resolved with a 30-day monitoring period on gas injection. We will notify you of the results of this work and any further actions at the point. Please let me know if you have any questions or disagree with the plan. Thanks, Travis From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Tuesday, March 22, 2022 5:04 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Smith, Travis T <Travis.T.Smith@conocophillips.com>; Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: Alpine CRU injector CD3-302A (PTD# 210-035) was reported with high IA pressure Chris- Alpine CRU injector CD3-302A (PTD# 210-035) was reported with high IA pressure requiring multiple IA bleeds. Slickline and LRS were immediately deployed and a tubing plug is in the process of being set. With the tubing loaded, the IA pressure is now stable under the DNE of 2400 psi. The well recently was under observation for suspected TxIA on gas injection and passed an MIT-IA to 4200 psi and an IA DDT was currently “in progress”. When the well is secured with a down hole plug, additional diagnostics to investigate the source of the high IA pressure will be conducted. Once the diagnostics have been completed, the proper paperwork for continued injection or repair will be submitted as required. Attached is the current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Alpine CRU injector CD3-302A (PTD# 210-035) was reported with high IA pressure Date:Wednesday, May 25, 2022 9:51:33 AM Attachments:image001.png From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Wednesday, April 20, 2022 4:27 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: Alpine CRU injector CD3-302A (PTD# 210-035) was reported with high IA pressure Chris— I wanted to give you an update on CRU injector CD3-302A (PTD# 210-035). DHD performed several diagnostics on the well after the plug was set, including an MIT-T, MIT-IA, and packoff testing. All of these passed. These tests, and the circumstances of the original issue, indicate the well has a gas-only leak. Our path forward is to swap the dummy valve with a high-sealibility dummy valve. Then, pull the tubing tail plug and determine if the issue has been resolved with a 30-day monitoring period on gas injection. We will notify you of the results of this work and any further actions at the point. Please let me know if you have any questions or disagree with the plan. Thanks, Travis From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Tuesday, March 22, 2022 5:04 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Smith, Travis T <Travis.T.Smith@conocophillips.com>; Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: Alpine CRU injector CD3-302A (PTD# 210-035) was reported with high IA pressure Chris- Alpine CRU injector CD3-302A (PTD# 210-035) was reported with high IA pressure requiring multiple IA bleeds. Slickline and LRS were immediately deployed and a tubing plug is in the process of being set. With the tubing loaded, the IA pressure is now stable under the DNE of 2400 psi. The well recently was under observation for suspected TxIA on gas injection and passed an MIT-IA to 4200 psi and an IA DDT was currently “in progress”. When the well is secured with a down hole plug, additional diagnostics to investigate the source of the high IA pressure will be conducted. Once the diagnostics have been completed, the proper paperwork for continued injection or repair will be submitted as required. Attached is the current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone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y Samantha Carlisle at 8:21 am, Apr 07, 2022 'LJLWDOO\VLJQHGE\%UHQQHQ*UHHQ '1& 862 &RQRFR3KLOOLSV&1 %UHQQHQ *UHHQ( Q#FRQRFRSKLOOLSVFRP 5HDVRQ,DPWKHDXWKRURIWKLVGRFXPHQW /RFDWLRQ\RXUVLJQLQJORFDWLRQKHUH 'DWH )R[LW3')(GLWRU9HUVLRQ %UHQQHQ *UHHQ RBDMS SJC 041222 DSR-4/11/22 32%2; $1&+25$*($/$6.$ $SULO &RPPLVVLRQHU-HVVLH&KPLHORZVNL $ODVND2LODQG*DV&RQVHUYDWLRQ&RPPLVVLRQ :HVWWK$YHQXH6XLWH $QFKRUDJH$. &RPPLVVLRQHU&KPLHORZVNL 3OHDVHILQGWKHHQFORVHGIURP&RQRFR3KLOOLSV$ODVND,QFIRUZHOO&ROYLOOH5LY8QLW &'37'´&RQGXFWRUH[WHQVLRQ 3OHDVHFRQWDFW%UHQQHQ*UHHQRU5RJHU0RXVHUDWLI\RXKDYHDQ\TXHVWLRQV 6LQFHUHO\ :HOO,QWHJULW\)LHOG6XSHUYLVRU &RQRFR3KLOOLSV$ODVND,QF 'LJLWDOO\VLJQHGE\%UHQQHQ*UHHQ '1& 862 &RQRFR3KLOOLSV&1 %UHQQHQ *UHHQ( Q#FRQRFRSKLOOLSVFRP 5HDVRQ,DPWKHDXWKRURIWKLVGRFXPHQW /RFDWLRQ\RXUVLJQLQJORFDWLRQKHUH 'DWH )R[LW3')(GLWRU9HUVLRQ %UHQQHQ*UHHQ 'DWH (YHQW6XPPDU\ ([HFXWLYH 6XPPDU\([WHQGHGWKH&RQGXFWRU ϬϰͬϬϱͬϮϮ tĞůĚĞĚĂϭϲΗǆϵΗǆ͘ϱϬϬΗĐŽŶĚƵĐƚŽƌĞǆƚĞŶƐŝŽŶǁŝƚŚϮΗǆϵΗĨůĂƚďĂƌƚŽƚŚĞĞǆŝƐƚŝŶŐĐŽŶĚƵĐƚŽƌ /DVW7DJ $QQRWDWLRQ 'HSWKIW.% (QG'DWH :HOOERUH /DVW0RG%\ /DVW7DJ6/0 &'$ QLQDP /DVW5HY5HDVRQ $QQRWDWLRQ (QG'DWH :HOOERUH /DVW0RG%\ 5HY5HDVRQ:HOGHGDFRQGXFWRUH[WHQVLRQ &'$ EVJUHHQ &DVLQJ6WULQJV &DVLQJ'HVFULSWLRQ &21'8&725 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQOE« *UDGH + 7RS&RQQHFWLRQ :(/'(' &DVLQJ'HVFULSWLRQ 685)$&( 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQOE« *UDGH / 7RS&RQQHFWLRQ %7& &DVLQJ'HVFULSWLRQ ,17(50(',$7( 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQOE« *UDGH / 7RS&RQQHFWLRQ %7&0 7XELQJ6WULQJVVWULQJPD[LQGLFDWHV/21*(67VHJPHQWRIVWULQJ 7XELQJ'HVFULSWLRQ 78%,1* 6WULQJ« ,'LQ 7RSIW.% 6HW'HSWKIW« 6HW'HSWK79'«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« &'$ 7' $FW%WPIW.% :HOO$WWULEXWHV )LHOG1DPH ),25'.83$58. :HOOERUH$3,8:, :HOOERUH6WDWXV ,1- 0D[$QJOH 0' ,QFO 0'IW.% :(//1$0( :(//%25(&'$ $QQRWDWLRQ /DVW:2 (QG'DWH +6SSP 'DWH&RPPHQW 6669:5'3 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Alpine CRU injector CD3-302A (PTD# 210-035) was reported with high IA pressure Date:Thursday, March 24, 2022 4:43:25 PM Attachments:image001.png AnnComm Surveillance TIO for CD3-302A.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Tuesday, March 22, 2022 5:04 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Smith, Travis T <Travis.T.Smith@conocophillips.com>; Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: Alpine CRU injector CD3-302A (PTD# 210-035) was reported with high IA pressure Chris- Alpine CRU injector CD3-302A (PTD# 210-035) was reported with high IA pressure requiring multiple IA bleeds. Slickline and LRS were immediately deployed and a tubing plug is in the process of being set. With the tubing loaded, the IA pressure is now stable under the DNE of 2400 psi. The well recently was under observation for suspected TxIA on gas injection and passed an MIT-IA to 4200 psi and an IA DDT was currently “in progress”. When the well is secured with a down hole plug, additional diagnostics to investigate the source of the high IA pressure will be conducted. Once the diagnostics have been completed, the proper paperwork for continued injection or repair will be submitted as required. Attached is the current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 12,449.0 9/23/2011 CD3-302A ninam Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: PULL INJ VALVE, GLV C/O, SET A1-INJ VLV 8/30/2016 CD3-302A pproven Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 37.0 Set Depth (ftKB) 114.0 Set Depth (TVD) … 114.0 Wt/Len (l… 54.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 27.4 Set Depth (ftKB) 2,669.1 Set Depth (TVD) … 2,495.1 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 24.8 Set Depth (ftKB) 12,592.9 Set Depth (TVD) … 6,935.2 Wt/Len (l… 26.40 Grade L-80 Top Thread BTCM Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 21.7 Set Depth (ft… 12,211.9 Set Depth (TVD) (… 6,748.5 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 21.7 21.7 0.00 HANGER FMC TUBING HANGER 3.958 2,062.1 1,988.1 32.63 NIPPLE CAMCO 'DB' LANDING NIPPLE 3.813 12,098.5 6,701.2 65.78 PACKER BAKER PREMIER PACKER 3.875 12,160.6 6,726.9 65.28 NIPPLE HES 'XN' NIPPLE (3.813" ID w/3.725" NO GO) 3.725 12,210.5 6,748.0 64.86 WLEG WIRELINE ENTRY GUIDE 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 2,062.0 1,988.0 32.62 VALVE 3.81" INJ VLV ON DB LOCK IN SSSV 8/27/2016 1.250 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 12,361.0 12,371.0 6,814.0 6,818.6 KUPC, CD3- 302A 4/23/2010 6.0 IPERF 3-1/8" MILLENIUM GUN w/60 deg phase Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 12,029.7 6,673.2 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 8/26/2016 Notes: General & Safety End Date Annotation 4/19/2010 NOTE: View Schematic w/ Alaska Schematic9.0 4/18/2010 NOTE: Well SIDETRACKED, OLD PROD CSG CUT @ 2673' CD3-302A, 5/28/2020 4:22:19 PM Vertical schematic (actual) INTERMEDIATE; 24.8-12,592.9 IPERF; 12,361.0-12,371.0 WLEG; 12,210.5 NIPPLE; 12,160.6 PACKER; 12,098.5 GAS LIFT; 12,029.7 SURFACE; 27.4-2,669.1 NIPPLE; 2,062.1 VALVE; 2,062.0 CONDUCTOR; 37.0-114.0 HANGER; 21.7 WNS INJ KB-Grd (ft) 43.18 Rig Release Date 4/18/2010 CD3-302A ... TD Act Btm (ftKB) 12,603.0 Well Attributes Field Name FIORD KUPARUK Wellbore API/UWI 501032052201 Wellbore Status INJ Max Angle & MD Incl (°) 68.48 MD (ftKB) 11,634.23 WELLNAME WELLBORECD3-302A Annotation Last WO: End Date 4/16/2010 H2S (ppm) DateComment SSSV: WRDP CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD3-302 (PTD#210-035-10) IA Pressurization Date:Tuesday, February 22, 2022 9:31:01 AM From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Friday, February 18, 2022 4:27 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: CRU CD3-302 (PTD#210-035-10) IA Pressurization Chris— Per our conversation this afternoon, we have revised our plan on CRU well CD3-302 (PTD#210-035- 0). We would like to put this well on a 30-day monitoring period on gas injection and perform the DHD diagnostics while on gas injection. We will update you at the conclusion of this monitoring period, or if the conditions of the well change during the monitoring period. Please let me know if you have any questions or disagree with the plan. Travis From: Smith, Travis T Sent: Tuesday, February 15, 2022 5:08 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD3-302 (PTD#210-035-10) IA Pressurization Chris— CRU well CD3-302 (PTD#210-035-0) has exhibited TxIA communication while on MI injection. Our intent is to WAG the well back to water injection for a 30-day monitoring period as soon as practical. While on water injection service we will conduct standard DHD diagnostics. Based on these results we will propose a path forward to either waiver the well for water-only injection service or attempt a repair to return the well to WAG injection service. A 90-day TIO and well schematic are attached. Please let me know if you have any questions or disagree with the plan. Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com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y Samantha Carlisle at 7:13 am, Feb 10, 2022 'LJLWDOO\VLJQHGE\%UHQQHQ*UHHQ '1& 862 &RQRFR3KLOOLSV&1 %UHQQHQ*UHHQ ( 1#FRQRFRSKLOOLSVFRP 5HDVRQ,DPWKHDXWKRURIWKLVGRFXPHQW /RFDWLRQ\RXUVLJQLQJORFDWLRQKHUH 'DWH )R[LW3')(GLWRU9HUVLRQ %UHQQHQ*UHHQ ; '/% ; 3KRWR GRFXPHQWDWLRQ RI UHSDLU UHTXLUHG '6597/ GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.02.15 15:02:22 -09'00' RBDMS SJC 021722 32%2; $1&+25$*($/$6.$ )HEUXDU\ &RPPLVVLRQHU-HVVLH&KPLHORZVNL $ODVND2LO *DV&RPPLVVLRQ :HVWWK$YHQXH6XLWH $QFKRUDJH$. 'HDU&RPPLVVLRQHU&KPLHORZVNL (QFORVHGSOHDVHILQGWKH$SSOLFDWLRQIRU6XQGU\$SSURYDOIRU&RQRFR3KLOOLSV $ODVND,QFZHOO$/3&'$37'WRH[WHQGFRQGXFWRU 6XPPDU\&RQGXFWRUKDVVXEVLGHGRUZHOOKDVJURZQ´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´ :LWKDSSURYDOWKHFRQGXFWRUH[WHQVLRQZLOOUHTXLUHWKHIROORZLQJJHQHUDOVWHSV 5HPRYHODQGLQJULQJIURPFRQGXFWRULIQHFHVVDU\ ([WHQGWKHFRQGXFWRUWRVWDUWHUKHDG )LOHZLWKWKH$2*&&SRVWUHSDLU /DVW7DJ $QQRWDWLRQ 'HSWKIW.%(QG'DWH :HOOERUH /DVW0RG%\ /DVW7DJ6/0 &'$ QLQDP /DVW5HY5HDVRQ $QQRWDWLRQ (QG'DWH :HOOERUH /DVW0RG%\ 5HY5HDVRQ38//,1-9$/9(*/9&26(7$,1-9/9 &'$SSURYHQ &DVLQJ6WULQJV &DVLQJ'HVFULSWLRQ &21'8&725 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQO« *UDGH + 7RS7KUHDG :(/'(' &DVLQJ'HVFULSWLRQ 685)$&( 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQO« *UDGH / 7RS7KUHDG %7& &DVLQJ'HVFULSWLRQ ,17(50(',$7( 2'LQ ,'LQ 7RSIW.% 6HW'HSWKIW.% 6HW'HSWK79'« :W/HQO« *UDGH / 7RS7KUHDG %7&0 7XELQJ6WULQJV 7XELQJ'HVFULSWLRQ 78%,1* 6WULQJ0D« ,'LQ 7RSIW.% 6HW'HSWKIW« 6HW'HSWK79'«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his email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD3-302 (PTD#210-035) IA Pressurization Date:Wednesday, February 16, 2022 9:39:43 AM Attachments:CD3-302A.pdf CD3-302 90-day TIO.pdf From: Smith, Travis T <Travis.T.Smith@conocophillips.com> Sent: Tuesday, February 15, 2022 5:08 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: CRU CD3-302 (PTD#210-035-10) IA Pressurization Chris— CRU well CD3-302 (PTD#210-035) has exhibited TxIA communication while on MI injection. Our intent is to WAG the well back to water injection for a 30-day monitoring period as soon as practical. While on water injection service we will conduct standard DHD diagnostics. Based on these results we will propose a path forward to either waiver the well for water-only injection service or attempt a repair to return the well to WAG injection service. A 90-day TIO and well schematic are attached. Please let me know if you have any questions or disagree with the plan. Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com Annular Communication Surveillance 17-Nov-2021Well Name:CD3-302 Start Date:17-Nov-2021 15-Feb-2022Days:90 End Date:15-Feb-2022 50 60 70 80 90 100 110 120 130 140 150 0 500 1000 1500 2000 2500 3000 3500 4000 4500 17-Nov-2120-Nov-2123-Nov-2126-Nov-2129-Nov-212-Dec-215-Dec-218-Dec-2111-Dec-2114-Dec-2117-Dec-2120-Dec-2123-Dec-2126-Dec-2129-Dec-211-Jan-224-Jan-227-Jan-2210-Jan-2213-Jan-2216-Jan-2219-Jan-2222-Jan-2225-Jan-2228-Jan-2231-Jan-223-Feb-226-Feb-229-Feb-2212-Feb-2215-Feb-22Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 17-Nov-2120-Nov-2123-Nov-2126-Nov-2129-Nov-212-Dec-215-Dec-218-Dec-2111-Dec-2114-Dec-2117-Dec-2120-Dec-2123-Dec-2126-Dec-2129-Dec-211-Jan-224-Jan-227-Jan-2210-Jan-2213-Jan-2216-Jan-2219-Jan-2222-Jan-2225-Jan-2228-Jan-2231-Jan-223-Feb-226-Feb-229-Feb-2212-Feb-22Injection Rate (BPD or MSCFD)Injection Rate Summary DGI MGI PWI SWI BLPD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 12,449.0 9/23/2011 CD3-302A ninam Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: PULL INJ VALVE, GLV C/O, SET A1-INJ VLV 8/30/2016 CD3-302A pproven Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 37.0 Set Depth (ftKB) 114.0 Set Depth (TVD) … 114.0 Wt/Len (l… 54.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 27.4 Set Depth (ftKB) 2,669.1 Set Depth (TVD) … 2,495.1 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 24.8 Set Depth (ftKB) 12,592.9 Set Depth (TVD) … 6,935.2 Wt/Len (l… 26.40 Grade L-80 Top Thread BTCM Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 21.7 Set Depth (ft… 12,211.9 Set Depth (TVD) (… 6,748.5 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 21.7 21.7 0.00 HANGER FMC TUBING HANGER 3.958 2,062.1 1,988.1 32.63 NIPPLE CAMCO 'DB' LANDING NIPPLE 3.813 12,098.5 6,701.2 65.78 PACKER BAKER PREMIER PACKER 3.875 12,160.6 6,726.9 65.28 NIPPLE HES 'XN' NIPPLE (3.813" ID w/3.725" NO GO) 3.725 12,210.5 6,748.0 64.86 WLEG WIRELINE ENTRY GUIDE 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 2,062.0 1,988.0 32.62 VALVE 3.81" INJ VLV ON DB LOCK IN SSSV 8/27/2016 1.250 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 12,361.0 12,371.0 6,814.0 6,818.6 KUPC, CD3- 302A 4/23/2010 6.0 IPERF 3-1/8" MILLENIUM GUN w/60 deg phase Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 12,029.7 6,673.2 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 8/26/2016 Notes: General & Safety End Date Annotation 4/19/2010 NOTE: View Schematic w/ Alaska Schematic9.0 4/18/2010 NOTE: Well SIDETRACKED, OLD PROD CSG CUT @ 2673' CD3-302A, 5/28/2020 4:22:19 PM Vertical schematic (actual) INTERMEDIATE; 24.8-12,592.9 IPERF; 12,361.0-12,371.0 WLEG; 12,210.5 NIPPLE; 12,160.6 PACKER; 12,098.5 GAS LIFT; 12,029.7 SURFACE; 27.4-2,669.1 NIPPLE; 2,062.1 VALVE; 2,062.0 CONDUCTOR; 37.0-114.0 HANGER; 21.7 WNS INJ KB-Grd (ft) 43.18 Rig Release Date 4/18/2010 CD3-302A ... TD Act Btm (ftKB) 12,603.0 Well Attributes Field Name FIORD KUPARUK Wellbore API/UWI 501032052201 Wellbore Status INJ Max Angle & MD Incl (°) 68.48 MD (ftKB) 11,634.23 WELLNAME WELLBORECD3-302A Annotation Last WO: End Date 4/16/2010 H2S (ppm) DateComment SSSV: WRDP MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,February 20,2018 TO: Jim Regg P.I.Supervisor le fc Z-1 Z7/18 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. CD3-302A FROM: Lou Laubenstein COLVILLE RIV FIORD CD3-302A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry -��— NON-CONFIDENTIAL Comm Well Name COLVILLE RIV FIORD CD3-302A API Well Number 50-103-20522-01-00 Inspector Name: Lou Laubenstein Permit Number: 210-035-0 Inspection Date: 2/10/2018 Insp Num: mitLOL180212123654 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ----- ------- ------ ----- --- Well CD3-302A Type Inj G- TVD 6701 ',Tubing 3512 • 3512 _ 3512 .71 3512 • gyp PTD 2100350 iT e est SPT Test psi 1675 IA 460 2100 2080 2080 ' BBL Pumped: 2 IBBL Returned: 2 - OA 253 . 292 - 294 • 294 Interval ) 4YRTST P/F P Notes: SCANNED • Tuesday,February 20,2018 Page 1 of 1 i p. :`:N c[ i, / , ,I / yf ----1.---.1- -A,:-.7::-. 333 West SeventF A'e e ` r"� (;ovI;FZi�'(1ii 2?.�N 1 vR1�'f.[ i. Anchorage, Alaska 99501 3572 e � 1,,Arne 9117.77 43? OM 1 6 calk MJ Loveland `O4'' Well Integrity Project 3ConocoPhillips Alaska, Inc. a LO P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-302A Sundry Number: 314-034 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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, l'')) -0 — Cathy P Foerster Chair DATED this /7�of January, 2014. Encl. tle STATE OF ALASKA x , AL,__KA OIL AND GAS CONSERVATION COMMISSION 1, . APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 0775 fir r`!it.-, 1.Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well r Chan Cpj ov(,+ r Suspend E Plug Perforations E Perforate E Pull Tubing r Time Extension E Operational r Re-enter Susp. ) Stimulate fv Alter casing r Other:Conductor Extension f . 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory , Developmen r ,y, 210-035 3.Address: -/ I 6.API Number: Stratigraphi r Service fV P.O.Box 100360,Anchorage,Alaska 99510 50-103-20522-01 - 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r . CD3-302A ,, 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 0372105,0364471,0372104• Colville River Field/Fiord Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12603 ' 6941 • Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 2642 9.625 2669' 2495' INTERMEDIATE 12568 7 12593' 6935' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12361'-12371' 6814'-6818' 4.5 L-80 12211 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER PREMIER PACKER . MD=12099 TVD=6701 SSSV-WRDP . MD=2062 TVD=1988 12.Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service F• 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2014 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG F. Abandoned r Commission Representative: GSTOR r SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Martin Walters Email: n1878Ca�cop.com - Printed Name MJ Loveland y Title: Well Integrity Project Signature Phone:659-7043 Date 1/11/14 Commission Use Only Sundry Number:31q-03-ti Conditions of approval: Notify Commission so that a representative may witness I!I Plug Integrity r BOP Test r Mechanical Integrity Test E Location Clearance r Other: RBDMS' ° MAY 0 9 2014 Spacing Exception Required? Yes 0 No 0/ Subsequent Form Required: /e ,_,, 4 a 7 COM SS1 APPROVEDPMBY C// Approved by: C 'p.ro •'.pplication is valid torr nt12mEs from thhc date otlapp oval. Date: 1— 7—/ T Form 10-403(Revised 1 /2012) �► I'is!I Submit Form and Attachments in Duplicate VL-!- ///‘ /11 ORIGIN '//01 1 WNS CD3-302A ConocoPhillips 02 Well Attributes Max Angle&MD TD ' . A!»tik3,Illi;. Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) CltrncoRylllps 501032052201 FIORD KUPARUK INJ 68.48 11,634.23 12,603.0 • Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date • Well Contig -CD3-302A,1/320131257.15 PM SSSV:WRDP _ _ Last WO: 4/16/2010 43.18 4/18/2010_ 6chemaac-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 12,449.0 9/23/2011 Rev Reason:WELL REVIEW osborl 1/3/2013 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WE..String...String Top Thrd CONDUCTOR 16 15.250 37.0 114.0 114.0 54.50 I-I-40 WELDED ., Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd HANGER,22 I SURFACE 95/8 8.835 27.4 2,669.1 2,495.1 40.00 L-80 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd INTERMEDIATE 7 6.276 24.8 12,592.9 6,935.2 26.40 L-80 BTCM E p Tubing Strings Tubing Description String 0... String ID...'Top(565) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd TUBING 41/2 3.958 21.7 12,211.9 6,748.6 12.60 L-80 IBTM Completion Details Top Depth (ND) Top Incl Noma... Top(ftKB) MB) (*) Item Description Comment ID(In) 21.7 21.7 -0.01 HANGER FMC TUBING HANGER 3.958 2,062.1 1,988.1 32.76 NIPPLE CAMCO'OB'LANDINGNIPPLE 3.873 12,098.5 6,701.2 65.78 PACKER BAKER PREMIER PACKER 3.875 12,160.6 6,727.0 65.28 NIPPLE HES'XN'NIPPLE(3.813"ID w/3.725"NO GO) 3.725 CONDUCTO14 R, 12,210.5 6,748.0 64.86 WLEG WIRELINE ENTRY GUIDE 4.000 37-1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD) Top Incl Top(ftKB) (MKB) C) Description Comment Run Date ID(In) 2,062.0 1,988.0 32.76 VALVE 3.81"DB LOCK w/A-1 INJECTION VALVE(HRS-309) 5/27/2012 1.250 VALVE,2,062 NIPPLE,2062 _ Perforations&Slots I Shot - Top(TED) She(TVD) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (n1- Type Comment 12,361.0 12,371.0 6,814.1 6,818.6 KUPC, 4232010 6.0 IPERF 3-18"MILLENIUMGUN w/60 deg CD3-302A phase Notes:General&Safety End Date Annotation 4/18/2010 NOTE:Well SIDETRACKED,OLD PROD CSG CUT @ 2673' SURFACE, 4/19/2010 NOTE:View Schematic w/AlaskaSchematic9.0 27-2,669 GAS LIFT, 12,030 PACKER. 12,098 . _ NIPPLE.12,161— ,1._ i ISLEG,/2.211 J 1 • (PERF, l 12,361-12,371 Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run Ste Top(ftKB) (ftKB) CI Make Model (in) Set-a Type Type (In) (psi) Run Date Com... 1 12,029.7 6,673.2 66.10 CAMCO KBG-2 1 GAS LIFT DMY -BK 0.000 0.0 4/162010 i i NTERMEDIATE, 25-12,593 TD(CD3-302A), 12.603 ConocoPh i l l i ps F 1 1 4 Alaska P.O. BOX 100360 AO GCC ANCHORAGE,ALASKA 99510-0360 January 10,2014 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well CD3-302A, PTD 210-035 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, ., ////4 , MJ Lo eland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska,Inc. --O Alpine Well CD3-302A(PTD 210-91-0) SUNDRY NOTICE 10-403 APPROVAL REQUEST January 10, 2014 This application for Sundry approval for Alpine well CD3-302A is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to SC. At some point during normal operations the conductor subsided about 10". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor DATA SUBMITTAL COMPLIANCE REPORT 6/13/2012 Permit to Drill 2100350 Well Name /No. COLVILLE RIV FIORD CD3 -302A Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20522 -01 -00 MD 12603 TVD 6941 Completion Date 4/25/2010 Completion Status WAGIN Current Status WAGIN 1W- REQUIRED INFORMATION Mud Log No Samples No Directional Surve DATA INFORMATION Types Electric or Other Logs Run: GR / RES, CBL (data taken from Logs Portion of Master Well Data Maint Well Log Information: III Log/ Electr Data Digital Dataset Log Log Run Interval 01-1/ Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments EDt/ C Lis 19581 Induction /Resistivity 2624 12550 Open 4/26/2010 EWR logs in PDS, EMF and CGM graphics Log `�/ Induction /Resistivity 25 Col 2669 12603 Open 4/26/2010 MD ROP, DGR, EWR, ALD, CTN Log t/ Induction /Resistivity 25 Col 2669 12603 Open 4/26/2010 TVD DGR,EWR, ALD, CTN ED /C Las 19619 Perforation 12101 12505 Case 5/7/2010 Perf, CCL, GR, Tens Log ✓ Cement Evaluation 5 Col 0 12480 Case 5/7/2010 RCBL I ED './ C Las 19623 Cement Evaluation 12018 12486 Case 5/7/2010 RCBL, Tens, GR ED ✓C Directional Survey 27 12603 Open Rpt - Directional Survey 27 12603 Open Well Cores /Samples Information: Sample III Interval Set Name Start Stop Sent Received Number Comments Cuttings 12325 12425 4/21/2010 1244 ADDITIONAL INFORM ON Well Cored? Y / N Daily History Received? N Chips Received? 4-444- Formation Tops , Analysis .X1 -14� Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 6/13/2012 Permit to Drill 2100350 Well Name /No. COLVILLE RIV FIORD CD3 -302A Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20522 -01 -00 MD 12603 TVD 6941 Completion Date 4/25/2010 Completion Status WAGIN Current Status WAGIN UIC Y Compliance Reviewed By: Date: 2. l • • • 1 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 February 3, 2011 Commissioner Dan Seamount Alaska Oil & Gas Commission Drr3 r T) /° ::: ' 333 West 7 Avenue, Suite 100 AK 99501 - 03 5 FEB 0 4 2011 a 2.A (�� 3 yer ort : G Carrs, Con:..,:ssion Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped January 31, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, 7V7 MJ Loveland ConocoPhillips Well Integrity Projects Supervisor 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Alpine Field Date 2/3/2011 CO3 Pad Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft _ bbis _ ft _ gal CO3 -106 50103206110000 2100010 16" _ NA _ 16" _ NA 7.65 1/31/2011 CD3 - 110 50103205090000 2050410 4" NA _ 6" NA 2.13 1/31/2011 CO3 -112 50103205270000 2060320 3" NA 16" NA 2.73 1/31/2011 CD3 - 114 50103205440000 2070330 5" NA 14" NA 2.55 1/31/2011 CD3 - 121 50103206150000 2100220 32" _ NA 32" _ NA 27.2 1/31/2011 CD3 - 122 50103206090000 2091530' 74" NA _ 74" NA 32.2 1/31/2011 CD3 -124 50103206120000 2100080 17" NA 17" NA 5.1 1/312011 CD3 -301A 50103205430100 _ 2060170 9" NA 15" _ NA 4.25 1/31/2011 50103205220100 2100350 5° NA _ 16" NA 3.83 1/312011 CD3 - 304 50103205980000 2090280 18" NA 18" NA 5.9 1/31/2011 ■ • • • RE ! STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 1 2 2010 WELL COMPLETION OR RECOMPLETION REPORT3 I J o mnissiion la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: Anchorage 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG El WDSPL ❑ No. of Completions: Service El Stratigraphic Test ❑ 2. Operator Name: Date Comp., Susp., V. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: April 25, 2010 210 - 035 / 3. Address: 1g, Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 April 7, 2010 50 103 - 20522 - 01 4a. Location of Well (Governmental Section): Z, Date TD Reached: 14. Well Name and Number: Surface: 3903' FNL, 700' FEL, Sec. 5, T12N, R5E, UM April 13, 2010 CD3 - 302A \Top of Productive Horizon: k KB (ft above MSL): 40.6' RKB 15. Field /Pool(s): 1130' FNL, 1317' FWL, Sec. 33, T13N, R5E, UM GL (ft above MSL): 13.2' AMSL Colville River Field '. Total Depth: "9. Plug Back Depth (MD + TVD): 940' FNL, 3874' FEL, Sec. 33, T13N, R5E, UM 12507' MD / 6887 TVD Fiord Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): ';Q. Total Depth (MD + TVD): 16. Property Designation: Surface: x 388344 y - 6003870 Zone 4 12603' MD / 6941' TVD ADL 372105, 372104, 364471 TPI: x - 393098 y - 6011853 Zone 4 V. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 393189 y - 6012042 Zone 4 landing nipple @ 2062' MD / 1988' TVD 2112 18. Directional Survey: Yes El No ❑ 19. Water Depth, if Offshore: \20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1262' MD / 1250' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re - drill /Lateral Top Window MD/TVD GR/ Res, CBL 2673' MD / 2500' TVD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 37' 114' 37' 114' 24" pre - installed 9.625" 40# L -80 37' 2679' 37' 2503' 12.25" 397 sx AS Lite, 235 sx Class G 7" 26# L -80 37' 12593' 37' 6935' 8.75" 36 bbls Class G 24. Open to production or injection? Yes gi No ❑ If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) 4.5" 12212' 12099' MD / 6701' TVD N. 12361'- 12391' MD 6814' -6819' TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. COi1iP ® '" DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ( ." � 01 e 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) April 29, 2010 WAG injector Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 1946 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10 -407 Revised 12/2009 RBDMS MAY 12 11 v INUED ON REVERSE Submit original only r3/ 71 ;eirif / er c 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? 0 Yes 0 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 1262' 1250' needed, and submit detailed test information per 20 AAC 25.071. C -30 2694' 2516' C -20 3160' 2878' K -3 5061' 3907' K -2 5536' 4096' Nanuq 10338' 6007' K -1 12156' 6725' Kuparuk D 12251' 6765' Kuparuk C 12358' 6813' N/A Formation at total depth: Kuparuk C 30. LIST OF ATTACHMENTS Summary of Daily Operations, final directional survey, schematic �4 - /tO`z ANO 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: M. infree, Jr. 265 - 6820 Y fY e9 9 Y 9 Printed Name G. L. Alvord Title: Alaska Drilling Manager Signature - e. Phone 265 - 6120 Date 1 r l2O l o Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 la: 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 12/2009 w% WNS II CD3 -302A ConocoPhinips „ _ Well Attributes Max Angle & MD TD Ai6.8(60 1rx' ,_, Wellborn APVUWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) fIgPS 5010320522_01 _FIORD KUPARUK INJ 68 48 11,63423 12,603.0 "' Cammont H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date Well Con c.3.3o2A 6026 /20101 634 PM SSSV.WRDP I CI Last WO- 43 18 4/18/2010 Srnemanc- Ac108I Annotation Depth (ftKB) End Date Annotation Last Mod.. End Date Last Tag' SLM 12.503.0 4/19/2010 Rev Reason' PERFORATE Imosbor14 /24/2010 i Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... (String ... String Top Thrd CONDUCTOR 16 15.250 37.0 114.0 54.50 11-00 Casing Description String 0... Siring ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd Tubing Hanger, t SURFACE 95/8 8.835 368 2,678.5 2,503.0 40.00 L BTC 22 : ? Casing Description String 0 ... Siring ID ... To (ftKB) S et Depth f Set Depth TVD String Wt... String String T Thrd 9 O< 9 9 P ) ( th P( 1 - -- 9 9- 9 P INTERMEDIATE 7 6.276 24.8 12,592.9 6 935 2 26.40 L -80 BI CM AIR Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) . String Wt... Sir ng String Top Thrd ! '< TUBING 41/2 3958 21.7 12,2119 67486 l 1260 L80 IBTM Completion Details Top Depth 1 7 't.'. TVD Inc I Komi... (TVD) Top Top (ftKB) (ftKB) ( Item Description Comment ID(in) 2,062.1 1,988.1 32.76 NIPPLE CAMCO'DB' LANDING NIPPLE 3.813 r 12,098.5 6,701.2 65.78 PACKER ' BAKER PREMIER PACKER 3.875 ' 12,160.6 6,727.0 65.28 NIPPLE HES'XN'NIPPLE 3.725 12,210.5 6,7480 64.86 WLEG WIRELINE ENTRY GUIDE 4.000 L Perforations & Slots ' Shot , Top (TVD) Btm (TVD) Dens j ; Top (ftKB) Bun Mks) (ftKB) (ftKB) Zone Date f"--- Type Comment "� 12,361 1 2, 3 7 1 6,814.1 6,818.6 4/23/2010 6.0 IPERF 3 -1/8" MELLENIUM GUN w /60 deg i phase Notes: General & Safety End Date 1 Annotation 4/18/2010 'NOTE: Well SIDETRACKED NIPPLE, 2,062-- — 4/19/2010 ,NOTE: VIEW SCHEMATIC w /Alaska Schema6ic9.0 I ; • I M1 SURFACE, ! 37 -2,679 v1 IN GAS LIFT, ' F=, 12,030 - x ' i l �. PACKER, L 12,098 .77 NIPPLE, 12,161 1 WLEG, 12,211 — I [': ::� IPERF, 12,361- 12,371 Mandrel Details 'Top Depth Top Port (TVD) Ind OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) ( °) Maks Model (in) 5600 Type Type (in) (Pei) Run Date Com... 1 12,029.7 6,673.2 66.10 CAMCO KBG 1 GAS LIFT DMY BK 0.000 0.0 4/16/2010 TERMEDWTE, 25- 12,593 7D (CO3- 302A), 12,603 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Wnton_Aubert@admin.state.ak.us; Bob_ Fleckenstein @admin.state.ak.us; Jim_Regg @admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: ConocoPhillips Alaska FIELD / UNIT / PAD: Alipne DATE: 04/17/10 OPERATOR REP: D. Lutrick / D. Mickey AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well CD3 -302A Type Inj. TVD 6,703' Tubing 500 500 500 Interval P.T.D. 2100350 Type test P Test psi Casing 0 3,500 3,500 3,500 P/F P Notes: OA 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P /F_ Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waist M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Waistewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form BFL 9/1/05 CD3 -302A MIT.xls • 0 ,; ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad 1 CD3 -302A 50103205220100 1 P Sperry Drilling Services Definitive Survey Report 22 April, 2010 f I HALLIBURTON y Sperry Drilling Services 4 • fio ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -302 Project Westem North Slope TVD Reference: CD3 -302A @ 40.60ft (D141) Site: CD3 Fiord Pad MD Reference: CD3 -302A @ 40.60ft (D141) Well: CD3 - 302 North Reference: True Wellbore: CD3 - 302A Survey Calculation Method: Minimum Curvature Design: CD3 -302A Database: CPAI EDM Production Protect Westem North Slope 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 Well CD3 - 302 Well Position +N / -S 0.00 ft Northing: 6,003,869.51 ft Latitude: 70° 25' 10.290 N +E/ - 0.00 ft Easting: 388,344.47 ft Longitude: 150° 54' 34.595 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.20ft Welibore CD3 - 302A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 4/5/2010 21.23 80.78 57,630 Design CD3 -302A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 2,630.73 Vertical Section: Depth From (TVD) +W-S +E/ -W Direction (ft) (ft) (ft) r) 27.40 0.00 0.00 30.00 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 69.90 248.00 CD3- 302PB1 gyro (CD3- 302PB1) CB- GYRO -SS Camera based gyro single shot 3/13/2006 1: 248.40 2,630.73 CD3- 302PB1 (CD3- 302PB1) MWD +IFR -AK- CAZ -SC MWD +IFR AK CAZ SCC 3/13/2006 1: 2,679.00 10,253.06 CD3 -302A (R200) (CD3 -302A) MWD +IFR -AK- CAZ -SC MWD +IFR AK CAZ SCC 4/6/2010 12: 10,344.86 12,564.69 CD3 -302A (R300) (CD3 -302A) MWD +IFR -AK- CAZ -SC MWD +IFR AK CAZ SCC 4/12/2010 1: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) ( ( (ft) (ft) (ft) (ft) (ft) (ft) (° /10(y) (ft) Survey Tool Name 27.40 0.00 0.00 27.40 -13.20 0.00 0.00 6,003,869.51 388,344.47 0.00 0.00 UNDEFINED 69.90 0.10 278.00 69.90 29.30 0.01 -0.04 6,003,869.52 388,344.43 0.24 -0.01 CB- GYRO -SS (1) 158.90 0.10 246.00 158.90 118.30 -0.02 -0.18 6,003,869.50 388,344.29 0.06 -0.11 CB- GYRO -SS (1) 247.90 1.10 86.00 247.89 207.29 0.01 0.60 6,003,869.51 388,345.07 1.34 0.31 CB- GYRO -SS (1) 382.09 2.81 79.45 382.00 341.40 0.70 5.12 6,003,870.14 388,349.60 1.28 3.17 MWD +IFR -AK- CAZ -SC (2) 471.39 4.27 64.79 471.13 430.53 2.52 10.28 6,003,871.88 388,354.78 1.91 7.32 MWD +IFR -AK- CAZ -SC (2) 560.99 7.41 64.41 560.25 519.65 6.44 18.51 6,003,875.67 388,363.07 3.50 14.83 MWD +IFR -AK- CAZ -SC (2) 650.15 9.50 64.73 648.44 607.84 12.06 30.35 6,003,881.12 388,374.99 2.34 25.62 MWD +IFR -AK- CAZ -SC (2) 738.60 9.14 71.47 735.73 695.13 17.41 43.61 6,003,886.27 388,388.33 1.30 36.88 MWD +IFR -AK- CAZ -SC (2) 831.43 9.85 62.01 827.29 786.69 23.48 57.61 6,003,892.13 388,402.42 1.84 49.14 MWD +IFR -AK- CAZ -SC (2) 926.41 11.16 46.61 920.69 880.09 33.61 71.47 6,003,902.05 388,416.43 3.25 64.84 MWD +IFR -AK- CAZ -SC (2) 4/22/2010 9:43:53AM Page 2 COMPASS 2003.16 Build 69 • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -302 Protect Westem North Slope TVD Reference: CD3 -302A © 40.60ft (0141) Site: CD3 Fiord Pad MD Reference: CD3 -302A © 40.60ft (D141) Well: CD3 - 302 North Reference: True Wellbore: CD3 - 302A Survey Calculation Method: Minimum Curvature Design: CD3 - 302A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E! -W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) ( °!100') (ft) Survey Tool Name 1,021.31 11.35 28.15 1,013.80 973.20 48.16 82.55 6,003,916.43 388,427.73 3.79 82.98 MWD +IFR -AK- CAZ -SC (2) 1,116.75 11.61 16.95 1,107.34 1,066.74 65.63 89.78 6,003,933.78 388,435.22 2.35 101.73 MWD +IFR -AK- CAZ -SC (2) 1,211.84 11.97 16.06 1,200.42 1,159.82 84.26 95.30 6,003,952.33 388,441.01 0.42 120.62 MWD +IFR -AK- CAZ -SC (2) 1,306.74 12.54 23.24 1,293.17 1,252.57 103.18 102.09 6,003,971.14 388,448.08 1.71 140.40 MWD +IFR -AK- CAZ -SC (2) 1,401.63 15.52 34.22 1,385.23 1,344.63 123.15 113.30 6,003,990.94 388,459.59 4.20 163.30 MWD +IFR -AK- CAZ -SC (2) 1,496.69 18.19 36.74 1,476.20 1,435.60 145.56 129.33 6,004,013.11 388,475.95 2.91 190.73 MWD +IFR -AK- CAZ -SC (2) 1,591.33 19.76 36.98 1,565.70 1,525.10 170.18 147.79 6,004,037.45 388,494.78 1.66 221.28 MWD +IFR -AK- CAZ -SC (2) 1,686.31 22.34 34.30 1,654.33 1,613.73 197.93 167.62 6,004,064.89 388,515.02 2.90 255.22 MWD +IFR -AK- CAZ -SC (2) 1,781.50 25.12 30.60 1,741.47 1,700.87 230.27 188.11 6,004,096.92 388,535.99 3.31 293.47 MWD +IFR -AK- CAZ -SC (2) 1,877.73 26.75 33.31 1,828.01 1,787.41 265.95 210.40 6,004,132.26 388,558.81 2.09 335.52 MWD +IFR -AK- CAZ -SC (2) 1,973.09 29.81 34.50 1,911.98 1,871.38 303.43 235.62 6,004,169.36 388,584.58 3.26 380.59 MWD +IFR -AK- CAZ -SC (2) 2,068.49 32.83 37.55 1,993.47 1,952.87 343.49 264.82 6,004,208.97 388,614.37 3.57 429.88 MWD +IFR -AK- CAZ -SC (2) 2,163.57 33.85 38.15 2,072.90 2,032.30 384.75 296.89 6,004,249.74 388,647.05 1.13 481.64 MWD +IFR -AK- CAZ -SC (2) 2,258.41 34.30 38.53 2,151.46 2,110.86 426.42 329.85 6,004,290.92 388,680.63 0.52 534.22 MWD +IFR -AK- CAZ -SC (2) 2,353.61 33.96 35.68 2,230.27 2,189.67 469.01 362.07 6,004,333.01 388,713.48 1.72 587.21 MWD +IFR -AK- CAZ -SC (2) 2,449.05 32.54 35.07 2,310.08 2,269.48 511.67 392.37 6,004,375.21 388,744.41 1.53 639.31 MWD +IFR -AK- CAZ -SC (2) 2,544.11 32.86 36.12 2,390.08 2,349.48 553.43 422.26 6,004,416.52 388,774.92 0.69 690.41 MWD +IFR -AK- CAZ -SC (2) 2,630.73 32.83 36.49 2,462.85 2,422.25 591.29 450.07 6,004,453.95 388,803.30 0.23 737.11 MWD +IFR -AK- CAZ -SC (2) 2,679.00 32.69 36.31 2,503.44 2,462.84 612.31 465.57 6,004,474.74 388,819.11 0.35 763.07 MWD +IFR -AK- CAZ -SC (3) 2,745.29 36.64 45.70 2,557.99 2,517.39 640.59 490.36 6,004,502.64 388,844.31 10.01 799.94 MWD +IFR -AK- CAZ -SC (3) 2,844.34 38.83 41.38 2,636.34 2,595.74 684.54 532.05 6,004,545.96 388,886.66 3.46 858.86 MWD +IFR -AK- CAZ -SC (3) 2,932.14 39.89 43.49 2,704.22 2,663.62 725.62 569.63 6,004,586.47 388,924.84 1.94 913.22 MWD +IFR -AK- CAZ -SC (3) 3,026.92 39.63 43.70 2,777.08 2,736.48 769.53 611.43 6,004,629.74 388,967.29 0.31 972.14 MWD +IFR -AK- CAZ -SC (3) 3,116.21 40.67 43.77 2,845.33 2,804.73 811.12 651.23 6,004,670.73 389,007.70 1.17 1,028.07 MWD +IFR -AK- CAZ -SC (3) 3,209.97 43.04 44.23 2,915.16 2,874.56 856.12 694.69 6,004,715.07 389,051.82 2.55 1,088.77 MWD +IFR -AK- CAZ -SC (3) 3,306.05 44.17 44.03 2,984.73 2,944.13 903.68 740.83 6,004,761.93 389,098.66 1.18 1,153.02 MWD +IFR -AK- CAZ -SC (3) 3,398.58 45.84 44.01 3,050.16 3,009.56 950.73 786.29 6,004,808.30 389,144.83 1.80 1,216.51 MWD +IFR -AK- CAZ -SC (3) 3,492.10 47.65 43.55 3,114.24 3,073.64 999.91 833.42 6,004,856.76 389,192.68 1.97 1,282.66 MWD +IFR -AK- CAZ -SC (3) 3,583.91 49.01 44.14 3,175.27 3,134.67 1,049.37 880.92 6,004,905.50 389,240.91 1.56 1,349.24 MWD +IFR -AK- CAZ -SC (3) 3,672.51 49.61 43.75 3,233.04 3,192.44 1,097.74 927.54 6,004,953.16 389,288.25 0.75 1,414.44 MWD +IFR -AK- CAZ -SC (3) 3,769.17 51.74 45.46 3,294.29 3,253.69 1,150.96 980.06 6,005,005.58 389,341.55 2.59 1,486.79 MWD +IFR -AK- CAZ -SC (3) 3,861.16 54.35 43.42 3,349.60 3,309.00 1,203.45 1,031.50 6,005,057.29 389,393.76 3.34 1,557.97 MWD +IFR -AK- CAZ -SC (3) 3,954.36 55.15 42.61 3,403.39 3,362.79 1,259.10 1,083.42 6,005,112.16 389,446.51 1.11 1,632.12 MWD +IFR -AK- CAZ -SC (3) 4,045.86 56.67 40.48 3,454.67 3,414.07 1,315.81 1,133.66 6,005,168.11 389,497.58 2.54 1,706.36 MWD +IFR -AK- CAZ -SC (3) 4,139.97 59.02 38.45 3,504.76 3,464.16 1,377.33 1,184.28 6,005,228.85 389,549.11 3.09 1,784.94 MWD +IFR -AK- CAZ -SC (3) 4,233.39 60.46 36.68 3,551.84 3,511.24 1,441.29 1,233.46 6,005,292.06 389,599.24 2.25 1,864.92 MWD +IFR -AK- CAZ -SC (3) 4,326.84 60.14 36.32 3,598.14 3,557.54 1,506.54 1,281.74 6,005,356.58 389,648.49 0.48 1,945.57 MWD +IFR -AK- CAZ -SC (3) 4,419.19 62.22 34.00 3,642.66 3,602.06 1,572.69 1,328.32 6,005,422.02 389,696.05 3.15 2,026.15 MWD +IFR -AK- CAZ -SC (3) 4,512.09 63.61 32.00 3,684.96 3,644.36 1,642.05 1,373.35 6,005,490.70 389,742.11 2.43 2,108.74 MWD +IFR -AK- CAZ -SC (3) 4,602.16 64.99 30.67 3,724.02 3,683.42 1,711.37 1,415.55 6,005,559.37 389,785.34 2.03 2,189.87 MWD +IFR -AK- CAZ -SC (3) 4/22/2010 9:43:53AM Page 3 COMPASS 2003.16 Build 69 • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -302 Project Western North Slope TVD Reference: CD3 302A 40.60ft (D141) Site: CD3 Fiord Pad MD Reference: CD3 -302A © 40.60ft (D141) Well: CD3 - 302 North Reference: True Welibore: CD3 - 302A Survey Calculation Method: Minimum Curvature Design: CD3 - 302A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/ -W Northing Easting DLS Section (ft) (°) r) (ft) (ft) (ft) (ft) (ft) (t) (°/100') (ft) Survey Tool Name 4,695.38 65.35 27.97 3,763.17 3,722.57 1,785.13 1,456.97 6,005,632.50 389,827.86 2.66 2,274.46 MWD +IFR -AK- CAZ -SC (3) 4,787.51 66.53 26.89 3,800.73 3,760.13 1,859.80 1,495.72 6,005,706.57 389,867.71 1.67 2,358.49 MWD +IFR -AK- CAZ -SC (3) 4,881.43 67.39 27.53 3,837.49 3,796.89 1,936.66 1,535.24 6,005,782.83 389,908.38 1.11 2,444.82 MWD +IFR -AK- CAZ -SC (3) 4,974.06 66.65 26.54 3,873.65 3,833.05 2,012.62 1,574.01 6,005,858.19 389,948.27 1.27 2,529.98 MWD +IFR -AK- CAZ -SC (3) 5,064.27 67.52 28.07 3,908.78 3,868.18 2,086.44 1,612.12 6,005,931.43 389,987.48 1.84 2,612.98 MWD +IFR -AK- CAZ -SC (3) 5,158.59 66.68 28.32 3,945.48 3,904.88 2,163.02 1,653.18 6,006,007.38 390,029.67 0.92 2,699.82 MWD +IFR -AK- CAZ -SC (3) 5,252.43 66.59 28.05 3,982.70 3,942.10 2,238.95 1,693.86 6,006,082.68 390,071.48 0.28 2,785.92 MWD +IFR -AK- CAZ -SC (3) 5,343.21 66.70 27.59 4,018.69 3,978.09 2,312.66 1,732.76 6,006,155.80 390,111.47 0.48 2,869.20 MWD +IFR -AK- CAZ -SC (3) 5,436.04 66.50 26.97 4,055.55 4,014.95 2,388.38 1,771.81 6,006,230.92 390,151.65 0.65 2,954.30 MWD +IFR -AK- CAZ -SC (3) 5,528.61 66.03 26.67 4,092.81 4,052.21 2,464.00 1,810.04 6,006,305.95 390,191.00 0.59 3,038.91 MWD +IFR -AK- CAZ -SC (3) 5,620.18 65.79 26.57 4,130.19 4,089.59 2,538.74 1,847.50 6,006,380.11 390,229.57 0.28 3,122.36 MWD +IFR -AK- CAZ -SC (3) 5,710.75 66.56 26.82 4,166.78 4,126.18 2,612.76 1,884.72 6,006,453.56 390,267.89 0.89 3,205.07 MWD +IFR -AK- CAZ -SC (3) 5,807.37 66.60 26.41 4,205.18 4,164.58 2,692.02 1,924.44 6,006,532.22 390,308.79 0.39 3,293.58 MWD +IFR -AK- CAZ -SC (3) 5,899.70 66.38 26.27 4,242.01 4,201.41 2,767.90 1,962.00 6,006,607.52 390,347.48 0.28 3,378.07 MWD +IFR -AK- CAZ -SC (3) 5,989.05 66.43 26.75 4,277.77 4,237.17 2,841.17 1,998.55 6,006,680.23 390,385.12 0.50 3,459.80 MWD +IFR -AK- CAZ -SC (3) 6,085.22 67.41 27.56 4,315.47 4,274.87 2,919.89 2,038.93 6,006,758.32 390,426.67 1.28 3,548.16 MWD +IFR -AK- CAZ -SC (3) 6,175.92 66.59 27.04 4,350.91 4,310.31 2,994.07 2,077.22 6,006,831.93 390,466.06 1.05 3,631.56 MWD +IFR -AK- CAZ -SC (3) 6,264.17 66.68 26.98 4,385.91 4,345.31 3,066.25 2,114.01 6,006,903.54 390,503.93 0.12 3,712.46 MWD +IFR -AK- CAZ -SC (3) 6,359.66 65.41 27.27 4,424.68 4,384.08 3,143.92 2,153.80 6,006,980.59 390,544.87 1.36 3,799.61 MWD +IFR -AK- CAZ -SC (3) 6,453.22 65.54 27.24 4,463.52 4,422.92 3,219.59 2,192.78 6,007,055.66 390,584.97 0.14 3,884.63 MWD +IFR -AK- CAZ -SC (3) 6,539.23 66.02 27.30 4,498.80 4,458.20 3,289.31 2,228.72 6,007,124.83 390,621.94 0.56 3,962.98 MWD +IFR -AK- CAZ -SC (3) 6,638.01 66.47 27.32 4,538.59 4,497.99 3,369.64 2,270.20 6,007,204.53 390,664.62 0.46 4,053.29 MWD +IFR -AK- CAZ -SC (3) 6,730.48 67.53 27.17 4,574.72 4,534.12 3,445.31 2,309.17 6,007,279.61 390,704.71 1.16 4,138.31 MWD +IFR -AK- CAZ -SC (3) 6,823.88 67.36 26.88 4,610.55 4,569.95 3,522.15 2,348.36 6,007,355.84 390,745.04 0.34 4,224.45 MWD +IFR -AK- CAZ -SC (3) 6,917.26 67.02 26.64 4,646.75 4,606.15 3,599.01 2,387.12 6,007,432.11 390,784.94 0.43 4,310.39 MWD +IFR -AK- CAZ -SC (3) 7,008.70 67.58 26.54 4,682.04 4,641.44 3,674.44 2,424.87 6,007,506.96 390,823.82 0.62 4,394.60 MWD +IFR -AK- CAZ -SC (3) 7,102.71 66.93 27.00 4,718.39 4,677.79 3,751.85 2,463.92 6,007,583.77 390,864.02 0.83 4,481.16 MWD +IFR -AK- CAZ -SC (3) 7,194.58 66.27 26.69 4,754.87 4,714.27 3,827.08 2,502.00 6,007,658.41 390,903.21 0.78 4,565.35 MWD +IFR -AK- CAZ -SC (3) 7,286.12 66.73 26.85 4,791.37 4,750.77 3,902.03 2,539.81 6,007,732.78 390,942.14 0.53 4,649.16 MWD +IFR -AK- CAZ -SC (3) 7,380.63 66.62 26.34 4,828.79 4,788.19 3,979.63 2,578.66 6,007,809.79 390,982.14 0.51 4,735.79 MWD +IFR -AK- CAZ -SC (3) 7,465.76 67.13 26.34 4,862.23 4,821.63 4,049.79 2,613.40 6,007,879.42 391,017.92 0.60 4,813.92 MWD +IFR -AK- CAZ -SC (3) 7,565.47 65.93 26.80 4,901.94 4,861.34 4,131.59 2,654.31 6,007,960.59 391,060.04 1.28 4,905.22 MWD +IFR -AK- CAZ -SC (3) 7,658.70 65.84 26.65 4,940.03 4,899.43 4,207.60 2,692.57 6,008,036.00 391,099.44 0.18 4,990.17 MWD +IFR -AK- CAZ -SC (3) 7,750.71 65.79 26.76 4,977.72 4,937.12 4,282.58 2,730.29 6,008,110.41 391,138.27 0.12 5,073.97 MWD +IFR -AK- CAZ -SC (3) 7,844.62 66.42 26.39 5,015.76 4,975.16 4,359.37 2,768.70 6,008,186.61 391,177.83 0.76 5,159.67 MWD +IFR -AK- CAZ -SC (3) 7,937.06 66.95 26.49 5,052.35 5,011.75 4,435.38 2,806.50 6 ,008, 262.04 391,216.75 0.58 5,244.40 MWD +IFR -AK- CAZ -SC (3) 8,029.84 67.15 26.43 5,088.53 5,047.93 4,511.87 2,844.57 6,008,337.94 391,255.96 0.22 5,329.67 MWD +IFR -AK- CAZ -SC (3) 8,116.90 66.01 26.10 5,123.13 5,082.53 4,583.50 2,879.92 6,008,409.03 391,292.38 1.35 5,409.39 MWD +IFR -AK- CAZ -SC (3) 8,212.70 66.48 26.32 5,161.72 5,121.12 4,662.17 2,918.65 6,008,487.11 391,332.27 0.53 5,496.88 MWD +IFR -AK- CAZ -SC (3) 8,302.42 66.33 26.35 5,197.63 5,157.03 4,735.86 2,955.12 6,008,560.23 391,369.84 0.17 5,578.93 MWD +IFR -AK- CAZ -SC (3) 4/2212010 9:43:53AM Page 4 COMPASS 2003.16 Build 69 1 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -302 Protect: Westem North Slope TVD Reference: CD3 -302A © 40.60ft (D141) Site: CD3 Fiord Pad MD Reference: CD3 -302A © 40.60ft (D141) Well: CD3 - 302 North Reference: True Wel!bore: CD3 - 302A Survey Calculation Method: Minimum Curvature Design: CD3 - 302A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (ft) r) t°) (ft) (ft) (ft) (ft) (ft) (ft) ( °1100') (ft) Survey Tool Name 8,397.43 66.41 26.39 5,235.72 5,195.12 4,813.84 2,993.79 6,008,637.63 391,409.66 0.09 5,665.80 MWD +IFR -AK- CAZ -SC (3) 8,487.44 66.95 27.63 5,271.35 5,230.75 4,887.48 3,031.32 6,008,710.69 391,448.29 1.40 5,748.35 MWD +IFR -AK- CAZ -SC (3) 8,582.22 67.26 27.09 5,308.22 5,267.62 4,965.03 3,071.45 6,008,787.62 391,489.57 0.62 5,835.57 MWD +IFR -AK- CAZ -SC (3) 8,674.84 66.13 27.44 5,344.87 5,304.27 5,040.64 3,110.42 6,008,862.63 391,529.66 1.27 5,920.53 MWD +IFR -AK- CAZ -SC (3) 8,771.03 66.06 27.08 5,383.84 5,343.24 5,118.81 3,150.70 6,008,940.19 391,571.10 0.35 6,008.37 MWD +IFR -AK- CAZ -SC (3) 8,857.45 66.57 27.10 5,418.56 5,377.96 5,189.27 3,186.74 6,009,010.09 391,608.19 0.59 6,087.41 MWD +IFR -AK- CAZ -SC (3) 8,954.58 66.58 28.15 5,457.17 5,416.57 5,268.23 3,228.06 6,009,088.42 391,650.68 0.99 6,176.45 MWD +IFR -AK- CAZ -SC (3) 9,048.32 66.25 27.00 5,494.68 5,454.08 5,344.38 3,267.83 6,009,163.96 391,691.58 1.18 6,262.28 MWD +IFR -AK- CAZ -SC (3) 9,136.59 66.38 27.27 5,530.14 5,489.54 5,416.32 3,304.70 6,009,235.33 391,729.52 0.32 6,343.02 MWD +IFR -AK- CAZ -SC (3) 9,228.79 67.14 25.67 5,566.52 5,525.92 5,492.15 3,342.45 6,009,310.59 391,768.40 1.79 6,427.57 MWD +IFR -AK- CAZ -SC (3) 9,325.40 67.09 25.55 5,604.09 5,563.49 5,572.41 3,380.93 6,009,390.26 391,808.07 0.13 6,516.32 MWD +IFR -AK- CAZ -SC (3) 9,418.15 67.14 25.83 5,640.16 5,599.56 5,649.42 3,417.97 6,009,466.69 391,846.26 0.28 6,601.52 MWD +IFR -AK- CAZ -SC (3) 9,508.98 67.14 25.74 5,675.45 5,634.85 5,724.78 3,454.38 6,009,541.49 391,883.78 0.09 6,684.99 MWD +IFR -AK- CAZ -SC (3) 9,603.89 66.67 25.57 5,712.68 5,672.08 5,803.48 3,492.17 6,009,619.61 391,922.75 0.52 6,772.04 MWD +IFR -AK- CAZ -SC (3) 9,689.47 66.91 26.75 5,746.40 5,705.80 5,874.07 3,526.85 6,009,689.67 391,958.48 1.30 6,850.52 MWD +IFR -AK- CAZ -SC (3) 9,782.95 65.88 26.81 5,783.84 5,743.24 5,950.54 3,565.44 6,009,765.55 391,998.21 1.10 6,936.04 MWD +IFR -AK- CAZ -SC (3) 9,875.63 66.21 26.88 5,821.47 5,780.87 6,026.11 3,603.69 6,009,840.53 392,037.58 0.36 7,020.61 MWD +IFR -AK- CAZ -SC (3) 9,967.28 66.14 27.02 5,858.49 5,817.89 6,100.85 3,641.69 6,009,914.68 392,076.68 0.16 7,104.33 MWD +IFR -AK- CAZ -SC (3) 10,065.06 66.42 26.63 5,897.82 5,857.22 6,180.73 3,682.09 6,009,993.95 392,118.27 0.46 7,193.71 MWD +IFR -AK- CAZ -SC (3) 10,153.28 66.69 27.16 5,932.92 5,892.32 6,252.91 3,718.70 6,010,065.57 392,155.95 0.63 7,274.53 MWD +IFR -AK- CAZ -SC (3) 10,253.06 66.13 25.73 5,972.85 5,932.25 6,334.78 3,759.42 6,010,146.81 392,197.89 1.43 7,365.79 MWD +IFR -AK- CAZ -SC (3) 10,344.86 66.68 27.22 6,009.60 5,969.00 6,410.08 3,796.93 6,010,221.54 392,236.52 1.60 7,449.76 MWD +IFR -AK- CAZ -SC (4) 10,436.63 67.09 27.73 6,045.63 6,005.03 6,484.96 3,835.87 6,010,295.82 392,276.57 0.68 7,534.08 MWD +IFR -AK- CAZ -SC (4) 10,523.94 67.17 27.52 6,079.56 6,038.96 6,556.24 3,873.17 6,010,366.53 392,314.93 0.24 7,614.45 MWD +IFR -AK- CAZ -SC (4) j 10,621.49 65.98 27.41 6,118.34 6,077.74 6,635.66 3,914.45 6,010,445.31 392,357.39 1.22 7,703.87 MWD +IFR -AK- CAZ -SC (4) 10,709.90 66.60 26.99 6,153.89 6,113.29 6,707.66 3,951.45 6,010,516.74 392,395.46 0.83 7,784.72 MWD +IFR -AK- CAZ -SC (4) 10,804.08 66.73 26.87 6,191.19 6,150.59 6,784.75 3,990.61 6,010,593.24 392,435.77 0.18 7,871.08 MWD +IFR -AK- CAZ -SC (4) ■ 10,899.77 66.54 26.84 6,229.14 6,188.54 6,863.12 4,030.30 6,010,671.00 392,476.62 0.20 7,958.79 MWD +IFR -AK- CAZ -SC (4) 10,992.69 66.51 26.69 6,266.16 6,225.56 6,939.22 4,068.68 6,010,746.51 392,516.13 0.15 8,043.88 MWD +IFR -AK- CAZ -SC (4) 11,084.96 66.90 26.33 6,302.65 6,262.05 7,015.06 4,106.51 6,010,821.76 392,555.08 0.55 8,128.47 MWD +IFR -AK- CAZ -SC (4) 11,173.93 66.53 26.59 6,337.82 6,297.22 7,088.22 4,142.92 6,010,894.37 392,592.58 0.49 8,210.04 MWD +IFR -AK- CAZ -SC (4) 11,267.59 66.27 26.97 6,375.32 6,334.72 7,164.84 4,181.59 6,010,970.40 392,632.39 0.46 8,295.73 MWD +IFR -AK- CAZ -SC (4) 11,359.82 65.34 27.09 6,413.12 6,372.52 7,239.78 4,219.82 6,011,044.75 392,671.74 1.02 8,379.74 MWD +IFR -AK- CAZ -SC (4) 11,448.98 66.48 26.46 6,449.51 6,408.91 7,312.45 4,256.49 6,011,116.85 392,709.48 1.43 8,461.01 MWD +IFR -AK- CAZ -SC (4) 11,542.61 67.83 28.10 6,485.86 6,445.26 7,389.13 4,296.04 6,011,192.93 392,750.17 2.16 8,547.19 MWD +IFR -AK- CAZ -SC (4) 11,634.23 68.48 27.79 6,519.95 6,479.35 7,464.25 4,335.89 6,011,267.44 392,791.14 0.78 8,632.18 MWD +IFR -AK- CAZ -SC (4) 11,727.52 67.67 27.68 6,554.78 6,514.18 7,540.85 4,376.16 6,011,343.42 392,832.55 0.88 8,718.65 MWD +IFR -AK- CAZ -SC (4) 11,821.69 67.41 26.76 6,590.76 6,550.16 7,618.24 4,415.97 6,011,420.20 392,873.51 0.94 8,805.57 MWD +IFR -AK- CAZ -SC (4) 11,919.20 66.61 27.42 6,628.85 6,588.25 7,698.16 4,456.85 6,011,499.49 392,915.57 1.03 8,895.22 MWD +IFR -AK- CAZ -SC (4) 12,006.58 66.21 26.19 6,663.82 6,623.22 7,769.63 4,492.96 6,011,570.40 392,952.74 1.37 8,975.17 MWD +IFR -AK- CAZ -SC (4) 4/22/2010 9 :43.53AM Page 5 COMPASS 2003.16 Build 69 • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well CD3 -302 Project Westem North Slope TVD Reference: CD3 -302A © 40.60ft (D141) Site: CD3 Fiord Pad MD Reference: CD3 -302A © 40.60ft (D141) Well: CD3 - 302 North Reference: True Welibore: CD3 - 302A Survey Calculation Method: Minimum Curvature Design: CD3 - 302A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/ -W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ff) (ft) (ft) (11001 (f() Survey Tool Name 12,104.68 65.75 26.21 6,703.75 6,663.15 7,850.03 4,532.52 6,011,650.19 392,993.50 0.47 9,064.58 MWD +IFR -AK- CAZ -SC (4) 12,196.49 64.98 26.48 6,742.02 6,701.42 7,924.81 4,569.55 6,011,724.41 393,031.64 0.88 9,147.86 MWD +IFR -AK- CAZ -SC (4) 12,290.16 64.20 26.75 6,782.21 6,741.61 8,000.45 4,607.46 6,011,799.47 393,070.67 0.87 9,232.32 MWD +IFR -AK- CAZ -SC (4) 12,380.50 62.10 25.13 6,823.01 6,782.41 8,072.92 4,642.72 6,011,871.40 393,107.01 2.82 9,312.71 MWD +IFR -AK- CAZ -SC (4) 12,474.27 58.88 24.68 6,869.20 6,828.60 8,146.93 4,677.08 6,011,944.87 393,142.48 3.46 9,393.99 MWD +IFR -AK- CAZ -SC (4) 12,564.69 54.46 24.57 6,918.87 6,878.27 8,215.59 4,708.56 6,012,013.05 393,174.97 4.89 9,469.18 MWD +IFR -AK- CAZ -SC (4) 12,603.00 54.46 24.57 6,941.13 6,900.53 8,243.94 4,721.52 6,012,041.20 393,188.35 0.00 9,500.22 PROJECTED to TD 4/22/2010 9 :43.53AM Page 6 COMPASS 2003.16 Build 69 . • ConocoPhillips Time Log & Summary We1Nlew Web Reporting Report Well Name: CD3 - 302 Rig Name: DOYON 141 Job Type: DRILLING SIDETRACK Rig Accept: 4/2/2010 4:00:00 PM Rig Release: 4/18/2010 11:59:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/02/2010 24 hr Summary Move ria f/ CD3 -301A to CD3 -302A, Rig up, Accept rig @ 1600: hrs 4/2/10, Pull BPV, Rig pump lines to kill well, Pump 50 bbls fresh water down ann. taking returns out tbg to recover diesel out tbg, Switch & Pump 250 bbls at 3 bpm 11.2 ppg kill mud down tbg holding back pressure according to kill schedule, Monitor well - Static, Blow down pump lines, Set BPV, N/D Tree, Install Blanking plug, N/U BOPE. 00:00 06:00 6.00 MIRU MOVE DMOB P Rigged down and moved modules off well. Sub off well @ 0600. 06 :00 12:00 6.00 MIRU MOVE MOB P Prepared location and laid rig malts, Spot Sub over CD3 -302. 12:00 13:30 1.50 MIRU P 30 50 U MOVE MOB Spot Pits, Pump room, Motor room, Boiler room. 13:30 14:45 1.25 MIRU MOVE MOB P Spot Rock Washer & Pipe shed. 14:45 16:00 1.25 MIRU MOVE RURD P Rig up & work on rig acceptance check list. Accepted Rig @ 16:00 hrs 4/2/10. 16:00 17:45 1.75 SLOT DRILL RURD P Pull BPV, Rig pump lines to kill well to well & tiger tanks.. 17:45 21:30 3.75 SLOT DRILL CIRC P PJSM, Test lines to 2000 psi, Pump 50 bbls fresh water down annulus at rate of 3 bpm holding 900 psi on choke to recover diesel out tubing, Switch and pump 250 bbls 11.2 ppg kill mud at rate of 3 bpm hold back pressure according to kill sheet, Monitor well - Static. 21:30 22:00 0.50 SLOT DRILL RURD P Blow down lines to tiger tank, Rig down pump lines. 22:00 22:30 0.50 SLOT WHDBO NUND P Set BPV. 22:30 23:30 1.00 SLOT WHDBO NUND P PJSM, Nipple down Tree, Install blanking plug, Plug control line, Nipple up Adapter flange. 23:30 00:00 0.50 SLOT WHDBO NUND P PJSM, Nipple up BOPE. 04/03/2010 Nipple up BOPE, Rig & test same BOP t/ 250/3500, Hydril 250/2500 w/ 4" & 4 -1/2" test jts- test waived by AOGCC Bob Noble, Pull hanger to floor, Circ, Pump dry job, POOH & UD w/ 4 -1/2" Completion string, Rig & test lower 4" pipe rams to 250/3500, M/U 7" faker K -1 cement retainer & single in hole w/ 4" DP, 00:00 02:30 2.50 SLOT WHDBO NUND P Finished Nipple up BOP. 02:30 09:30 7.00 SLOT WHDBO BOPE P Rigged up and Tested BOPE 250/3500 psi Rams Except lower p, °P Pipe, Bag, Choke Valves, Floor t/" valves, IBOP, and Chokes, Tested with both 4" & 4 -1/2" test joints. Tested Closing unit. Laid down Blanking plug. Recovered BPV. Page 1 of 14 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 11:00 1.50 5,865 SLOT WHDBO PULD P Picked up landing Jt and backed out Lockdown Screws. Unseated Tubing hanger and pulled to the floor. 11:00 12:45 1.75 5,835 5,835 SLOT DRILL CIRC P Rig & Circ & cond mud, Rigged up to lay down tubing and recover control lines. 12:45 13:00 0.25 SLOT DRILL CIRC P Pump dry job. 13:00 14:00 1.00 5,835 5,835 SLOT DRILL RURD T Change out Double stack tongs for conventional tongs due to trouble with back ups on Double stack tongs. 14:00 14:15 0.25 5,835 5,835 SLOT DRILL CIRC T Pump second dry job - First one didn't take. 14:15 16:15 2.00 5,835 2,075 SLOT DRILL PULD P Lay down 4 -1/2" Completion string & control line to SSSV, Lay down same. 16:15 19:15 3.00 2,075 1,826 SLOT DRILL PULD P Continue to lay down 4 -1/2" Completion string to 1,826'. 19:15 19:30 0.25 1,826 1,826 SLOT DRILL PULD T Change out power tongs (Jaws slipping). 19:30 21:00 1.50 1,826 0 SLOT DRILL PULD P Continue to lay down 4 -1/2" Completion string. (Total of 142 jts plus Space out pups & SSSV). 21:00 21:30 0.50 0 0 SLOT DRILL PULD P Clean floor, Lay down tubing tongs. 21:30 22:30 1.00 0 0 SLOT WHDBO BOPE P PJSM, Pick & make up 4" test jt., a K Set test plug & test lower 4" pipe _ rams to 250 low & 3500 psi high, Rig down, Set wear bushing. 22:30 00:00 1.50 0 200 SLOT DRILL PULD P PJSM, Pick up & Make up Baker 7" K -1 Cement retainer & single in with 4" drill pipe from pipe shed. 04/04/2010 Single in w/ cmt retainer to 5765', Set ret., Squeeze below ret. w/ 21 bbls cmt & dump 5 bbls on top, POOH to 5270, Circ 3x BTU, POOH, M/U Bridge plug, RIH & Set same @ 2810, POOH, M/U 7" csg cutter, RIH & cut 7" csg @ 2772' (Unable to circ annulus), POOH, Change top pipe rams to 7 ". 00:00 07:30 7.50 200 5,765 SLOT CEMEN "TRIP P Single in Cement Retainer with 4" drill pipe from pipe shed to 5,765'. 07:30 08:30 1.00 5,765 5,765 SLOT CEMEN" PLUG P Set Baker Cement Retainer on DP @ 5,765'. Unsting from Cement Retainer. Broke circulation. 08:30 09:00 0.50 5,765 5,765 SLOT CEMEN" SQEZ P Sting in and estabilished injection rate 1950 psi @ 2 BPM. 09:00 10:00 1.00 5,765 5,765 SLOT CEMENT SQEZ P Tested lines to 3500 psi. Mixed and pumped 26.4 Bbls Class G Cement , @ 15.8 PPG with 5 Bbls water Behind and 5 Bbls ahead. Squeezed 21.4 Bbls of cement Below Retainer set @ 5,765'. FSP 1350 psi @ 2 BPM. Pressure after squeeze 575 psi with pump off. CIP 0950. Droped 5 Bbls cement on top of retainer. 10:00 11:00 1.00 5,765 5,270 SLOT CEMEN" TRIP P Pull out of retainer, Rig down cement equip., Lay down single, POOH to 5270. 11:00 12:00 1.00 5,270 5,270 SLOT CEMEN" CIRC P Circ 3 times bottoms up. Page 2 of 14 • Time Logs Date From To Dur S. Depth E. Depth Phase • Code Subcode T Comment 12:00 13:15 1.25 5,270 0 SLOT CEMEN" TRIP P POOH & Lay down running tool. 13:15 16:00 2.75 0 2,810 SLOT DRILL MPSP P Make up Baker 7" Mechanical Bridge plug, RIH & set bridge plug @ 2,810'. 16:00 16:45 0.75 2,810 0 SLOT DRILL MPSP P POOH & Lay down running tool. 16:45 21:00 4.25 0 2,772 SLOT DRILL CPBO P Make up 7" Mechanical casing cutter, RIH & tag Bridge plug @ 2,810', Pick up & locate collar @ 2,792', Pick up 20' & cut 7" casing @ 2,772', Observed 150 psi pressure increase on 7" x 9 -5/8" annulus when pipe cut, Attempt to let pipe U -Tube (No good), Close Hydril and attempt to circ 7" x 9 -5/8" annulus (No good) annulus just pressured up to 500 psi and held, Monitor well - Slight flow, Circ & balance mud in & out, (Observed diesel and very little gas on bottom's up), Monitor well - Static. 21:00 22:30 1.50 2,772 0 SLOT DRILL CPBO P POOH & Lay down casing cutter. 22:30 23:00 0.50 0 0 SLOT DRILL PULD P Clean floor & pick up Baker spear & tools from beaver slide. 23:00 00:00 1.00 0 0 SLOT WHDBO BOPE P PJSM, Start changing top pipe rams to 7 ". 04/05/2010 Change top pipe rams to 7 ", Rig & test 7" rams to 250/3500 & Hydril to 250/2500, Pull pack off, M/U Spear, Engage csg & pull to floor w/ 310K, Attempt to circ- N.G., UD 2 jts 7" csg, Rig & circ 7" csg at rate 6.5 bpm @ 400 psi, UD 64 jts 7" csg + cut off, Change top rams back to 3 -1/2 "x 6" & test same to 250/3500, Rig & P/U 15 jts 3 -1/2" tbg, RIH & tag plug @ 2810', Circ, Lay cmt plug f/ 2810' to 2537' w/ 19.2 bbls 17.0 ppg cmt, POOH to 2326', Circ, POOH UD tbg, Rig & L/D 4" DP. 00:00 02:00 2.00 0 0 SLOT WHDBO NUND P Changed top rams from VBR to 7 ". Installed test plug and tested 250/3500 psi. 02:00 03:30 1.50 0 0 SLOT WHDBO PULD P Recovered 7" packoff and installed thin wear bushing. 03:30 05:30 2.00 0 2,772 SLOT FISH FISH P Made up Spear and engaged fish. Pulled on fish and came free @ 310 K on the Weight Indicator. Laid down hanger & Spear. Laid down 2 Jts of casing lost 25 K drag after 60' of casing pulled. 05:30 06:30 1.00 2,772 2,772 SLOT FISH CIRC P Circulated working pumps up from 2 BPM to 6.5 BPM taking returns to Rock washer. FCP 400 psi. 06:30 10:30 4.00 2,772 0 SLOT FISH PULD P Pump dry job, POOH & Lay down 64 jts + Cut off of 7" casing. 10:30 11:30 1.00 0 SLOT FISH RURD P Rig down casing equip., Pick up casing spear & break down same. 11:30 14:00 2.50 SLOT WHDBO BOPE P Change out top pipe rams back to 3 -1/2" x 6" VBR's. Pull wear bushing, Set test plug and test rams to 250 psi low & 3500 psi high, Reinstall wear bushing. 14:00 15:00 1.00 477 SLOT CEMEN" PULD P Rig & pick up 3 -1/2 ", 9.3# Mule shoe + 15 jts 3 -1/2 ", 9.3# tubing for laying cement kick off plug. Page 3 of 14 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:00 1.00 477 2,810 SLOT CEMEN" TRIP P RIH w/ 4" Drill pipe & tag bridge plug @ 2,810' 16:00 17:15 1.25 2,810 2,810 SLOT CEMEN" CIRC P Circ & Cond mud f/ cement plug at rate of 7 bpm @ 400 psi. 17:15 18:15 1.00 2,810 2,810 SLOT CEMEN" CMNT P PJSM, Blow down top drive, Rig up head pin and pump lines, Turn over to Dowell & pump 7.0 bbls fresh ' water ahead, Test lines to 2000 psi, Q Mix & pump 19.2 bbls 17.0# (107 sacks) Class G cement followed by 2.3 bbls fresh water behind, Turn over to rig & displace cmt w/ 20.0 bbls 11.2 ppg mud at rate of 7 bpm @ 550 psi, Good returns thru out job, Calc. TOC @ 2,537', C.I.P. @ 18:20 hrs 4/5/10 18:15 18:45 0.50 2,810 2,326 SLOT CEMEN "TRIP P Rig down pump lines & POOH to 2,326'. 18:45 19:30 0.75 2,326 2,326 SLOT CEMEN" CIRC P Circ 3 time bottom's up at rate of 600 gpm @ 900 psi, Had trace of cement on first bottom's up. 19:30 20:30 1.00 2,326 477 SLOT CEMEN" TRIP P Monitor well- Static, POOH to tubing. 20:30 21:30 1.00 477 0 SLOT CEMEN PULD P Rig tubing tools, Lay down 15 jts 3 -1/2" tubing. 21:30 00:00 2.50 0 0 SLOT DRILL PULD P PJSM, Rig & lay down 28 stands 4" drill pipe f/ off drillers side. 04/06/2010 Finish LD 4" DP - PU & std back 113 stds 5" DP - Change lower pipe rams to 5" & test - Change saver sub to 4 1/2" IF - Slip & cut drill line - MU BHA #1 - Bent house motor 1.3° - MWD w/ Dens /Neu - RIH f/ 754' to 2144' w/ singles f/ pipe shed - RIH to 2390' w/ DP f/ derrick - Wash down & tag top of cmt plug @ 2554' 00:00 00:30 0.50 0 0 SLOT DRILL PULD P Finish laying down 4" DP. 00:30 01:00 0.50 0 0 SLOT DRILL RURD P Rigged up to pick up 5" DP. 01:00 10:30 9.50 0 0 SLOT DRILL PULD P Picked up and stood back 113 stands of 5" DP from the pipeshed via mousehole. 10:30 11:15 0.75 0 0 SLOT DRILL RURD P Cleared rig floor and pulled wear bushing. 11:15 12:00 0.75 0 0 SLOT WHDBO NUND P Set test plug and change lower rams to 5 ". 12:00 14:00 2.00 0 0 SLOT WHDBO NUND P Finish chnaginq lower pipe rams to 5" & test to 250 & 3500 psi 14:00 17:00 3.00 0 0 SLOT RIGMNT SLPC P Slip & cut drill line & change saver sub 17:00 21:30 4.50 0 754 SLOT DRILL PULD P MU BHA # 1 - Bent housing motor w/ 1.3° bend - MWD w/ Nuetron/ Density - Up load MWD - found commuication problem - trouble shoot & found problem DM & RLL tools - PU flex DC - perform shallow pulse test - Load RA sources - PU remaining flex DC's HWDp & jars to 754' 21:30 22:30 1.00 754 2,144 SLOT DRILL TRIP P RIH f/ 754' to 2144' - picking up 45 jts 5' Dp f/ pipe shed Page 4 of 14 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 23:30 1.00 2,144 2,554 SLOT DRILL WASH P Cont. RIH w/ DP f/ derrick to 2390' - Wash down f/ 2390' to 2554' - 408 gpm @ 1050 psi w/ 30 rpm - 4 k torque - PU wt. 100 SO wt. 80 Rot wt 90 - tagged up of cmt pl;ug @ 2554' 23:30 00:00 0.50 2,554 2,554 SLOT CEMEN DRLG P Drill cement @ 2554' 04/07/2010 Clean out cmt f/ 2554' to 2673' - time drill - discovered error in drill pipe count ( actual depth of time drill 2579' to 2581') - Cleaned out cmt to 2639' - RU & test csg to 3500 psi - No good - Circ btms up - POOH - LD BHA - MU test packer - RIH to 2522' - set packer & test f/ 2522' to surface to 2500 psi OK - release packer & RIH & set @ 2596' - set packer & test casing f/ 2596' to surface to 1100 psi OK - POOH w/ test packer - MU BHA #2 (bent housing motor) - RIH to 2607' fill pipe - RIH to 2639' - clean out cmt to 2673' - Begin time drilling @ 2673' - Time drilled to 2678' 00:00 04:00 4.00 2,554 2,639 SLOT DRILL DDRL P Clean out cmt f/ 2554' to 2673' - ( Set 20 k on plug w/ no pump) Began to time drill off plug @ 2673' - 475 gpm 4 -5 k WOB - 1 to 2 ft/hr. - discovered error in drill pipe count ( actual depth of time drilling was 2579' to 2581' still inside 9 5/8" casing) - cleaned out cmt to 2639' 04:00 05:00 1.00 2,639 2,639 SLOT DRILL PRTS T Blow down TD- RU 7 test 9 5/8" casing to 3500 psi for 30 mins. bled down to 650 psi over the 30 min period RD. 05:00 06:00 1.00 2,639 2,639 SLOT DRILL OTHR T Notified Drilling engineer to discuss options - monitor well on trip tank 06:00 06:30 0.50 2,639 2,639 SLOT DRILL CIRC T Circ btms up @ 400 gpm @ 950 psi 06:30 07:30 1.00 2,639 754 SLOT DRILL TRIP T POOH f/ 2639' to 754' ( top of BHA) 07:30 10:30 3.00 754 0 SLOT DRILL PULD T Handle BHA - std back HWDP, jars - LD 2 MN flex DC's - Unload RA sources f/ MDW tools - Down load MWD - LD MWD & motor - clean up rig floor 10:30 11:30 1.00 0 0 SLOT RIGMNI SVRG T Service rig - bring BHA componets to rig floor 11:30 12:00 0.50 0 0 SLOT DRILL PULD T Make up Baker test packer 12:00 14:00 2.00 0 2,596 SLOT DRILL TRIP T RIH w/ baker test packer & 2522' - Set packer & tested 9 5/8" casing f/ _2522 to_surface 2500 psi for 10 mins. OK - release packer & RIH to 2596' - set packer & test 9 5/8' casing f/ 2596' to surface to 1100 psi for 10 mins. OK 14:00 15:00 1.00 2,596 0 SLOT DRILL TRIP T POOH w/ test packer - Break down packer @ sevices breaks & LD packer 15:00 17:45 2.75 0 754 SLOT DRILL PULD T MU BHA #2 - bent housing motor (1.3° bent) MWD- Plug in & up load MWD - Shallow pulse test tools - Load RA sources into MWD tools - finish MU BHA to 754' 17:45 18:45 1.00 754 2,607 SLOT DRILL TRIP T RIH w/ BHA to 2607' - fill pipe & set depth on Totco & MWD Page 5 of 14 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:45 19:00 0.25 2,607 2,673 SLOT DRILL COCF P RIH to 2639' - Clean out cmt f/ 2639' to 2673' 19:00 00:00 5.00 2,673 2,678 SLOT DRILL DDRL P Time drill off cmt plug @ 2673' to 2678' MD 2502' TVD to side track well qq AST - 5 hrs EDC - 11.34 ppg ` WOB 1 k GPM 500 2 1200 psi String wt. PU 104 SO 85 Rot 95 04/08/2010 Time drill f/ 2678' to 2699' ( off plug @ 2679') Circ btms up - RU & perform FIT- went to leak -off @ 570 psi 15.6 ppg EWM - Changed over to 10.0 ppg LSND - Drilled w/ motor f/ 2699' to 2974' - Pulled back to 2782' - V took check shot surveys @ 2782', 2789', 2793' - Ran back to btm - Drilled 8 3/4" hole w/ motor f/ 2974' to 4605' isf 00:00 02:30 2.50 2,678 2,699 SLOT DRILL DDRL P Time drill off cmt plug Cad 2,678' to 517' 2,699' MD 2,517' TVD to side track well AST - 2.5 hrs EDC- 11.4 ppg FROP 3 FH. Sidetrack @ 2,673'. WOB 1 k GPM 500 2 1250 psi String wt. PU 105 SO 85 Rot 95 02:30 03:00 0.50 2,699 2,699 SLOT DRILL CIRC P CBU @ 400 gpm 875 psi. 80 rpm 03:00 03:30 0.50 2,699 2,699 SLOT DRILL LOT P Performed LOT to 15.6 PPG EMW. 03:30 04:00 0.50 2,699 2,699 INTRM1 DRILL CIRC P Changed mud to 10 PPG LSND. 04:00 08:00 4.00 2,699 2,974 INTRM1 DRILL DDRL P Directionally drilled 8 3/4" hole w/ motor f/ 2,699' to 2,974' MD 2,558' TVD ADT 2.23 hrs = ART- 1.44 hrs AST.- .79 hrs ECD- 11.3 ppg WOB 3 -6 k RPM 100 GPM 600 @ 1300 psi String wt. PU 115 SO 95 ROT 105 Torque on /off bmt.- 7,000/3,000 ft/lbs. 08:00 09:00 1.00 2,974 2,974 INTRMI DRILL SRVY P Pulled up 2 stands and took check shots @ 2782', 2789', & 2793'. 09:00 12:00 3.00 2,974 3,252 INTRMI DRILL DDRL P Drilled 8 3/4" hole w/ motor f/ 2974' to 3252' MD 2946' TVD ADT- 7.42 hrs.= ART- 2.69 hrs AST -4.73 hrs. ECD- 11.3 ppg WOB 5 -10 k RPM 100 GPM 600 @ 1300 psi String wt. PU 115 SO 95 Rot 105 Toruqe on /off btm.- 5,000 /5,000 ft/lbs 12:00 00:00 12.00 3,252 4,605 INTRMI DRILL DDRL P Drilled 8 3/4" hole w/ motor f/ 3252' to 4605' MD 3725' TVD ADT- 7.77 hrs. = ART- 5.71 hrs AST- 2.06 hrs. ECD- 11.81 ppg WOB 5 -15 k RPM 100 GPM 600 @ 1900 psi String wt. PU 118 SO 105 Rot 112 Torque on /off btm.- 5,000 /6,000 ft/lbs 04/09/2010 Drilled 8 3/4' hole w/ motor f/ 4605 to 4950' - Trouble shoot MWD(density tool - No response - tool not sending data) - Drilled 8 3/4" hole w/ motor f/ 4950' to 5382' - Service rig - Drilled 8 3/4" hole w/ motor f/ 5382' to 6862' Page 6of14 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:00 4.00 4,605 4,950 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ motor f/ 4605' to 4950' MD 3864' TVD ADT- 2.47 hrs. = ART- 1.84 hrs AST- .63 hrs. ECD- 11.5 ppg WOB 5 -15 k RPM 100 GPM 600 @ 1900 psi String wt. PU 118 SO 105 Rot 112 Torque on /off btm.- 5,000 /6,000 ft/Ibs 04:00 04:30 0.50 4,950 4,950 INTRM1 DRILL CIRC T Nuetron Density failed on MWD. Troubleshooting tool. 04:30 08:30 4.00 4,950 5,382 INTRMI DRILL DDRL P Drilled 8 3/4" hole w/ motor f/ 4950' to 5382' MD 4034' TVD ADT- 2.51 hrs. = ART- 2.26 hrs AST- .25 hrs. ECD- 11.4 ppg WOB 5 -15 k RPM 100 GPM 600 @ 2000 psi String wt. PU 120 SO 105 Rot 115 Torque on /off btm.- 5,000 /6,500 ft/Ibs 08:30 09:00 0.50 5,382 5,382 INTRMI RIGMNT SVRG P Serviced Top Drive and rig. 09:00 12:00 3.00 5,382 5,568 INTRMI DRILL DDRL P Drilled 8 3/4" hole w/ motor f/ 5382' to 5568' MD 4108' TVD ADT- 2.3 hrs. = ART- 1.24 hrs AST - .99 hrs. ECD- 11.4 ppg WOB 5 -15 k RPM 100 GPM 600 @ 2000 psi String wt. PU 123 SO 106 Rot 117 Torque on /off btm.- 5,000 /4000 ft/Ibs 12:00 00:00 12.00 5,568 6,862 INTRMI DRILL DDRL P ODrilled 8 3/4" hole w/ motor f/ 5568' to 6862' MD 4623' TVD ADT -7.45 hrs = ART -5.64 hrs AST -1.81 hrs ECD- 11.62 ppg WOB 5/15 k RPM 120 GPM 630 @ 2525 psi String wt. PU 130 SO 114 Rot 125 Torque on /off btm.- 7500 /5000 ft/Ibs. 04/10/2010 Drilled 8 3/4" hole w/ motor f/ 6862' to 9278' 00:00 12:00 12.00 6,862 8,071 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ motor f/ 6862' to 8071' MD 5105' TVD ADT -7.31 hrs = ART -5.16 hrs AST -2.15 hrs ECD- 11.64 ppg WOB 5/15 k RPM 120 GPM 630 @ 2200 psi String wt. PU 156 SO 113 Rot 135 Torque on /off btm.- 1000/11000 ft/lbs. 12:00 00:00 12.00 8,071 9,278 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ motor f/ 8071' to 9278' MD 5585' TVD ADT- 7.57 hrs. = AST- 2.35 hrs. ART- 5.22 hrs. ECD- 11.58 ppg WOB 15/22 k RPM 110 GPM 620 @ 2600 psi String wt. PU 165 SO 123 Rot 144 Troque on /off btm.- 11,500/10,500 ft/Ibs. Page 7of14 . . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/11/2010 24 hr Summary Drilled 8 3/4" hole to 10,383' - Circ btms up - Backream out f/ 10,383' to 9460' @ 550 gpm @ 1800 psi / 100 rpm - Circ btms up - POOH on elevators f/ 9460' to 754' (top of BHA) Hole took proper fill & no tight spots - Flow cked @ 9 5/8" shoe & © BHA - Well static - POOH w/ BHA - Changed out Neutron /density tool - changed out pulser - Shallow tested MWD tools - RIH to 1,032' 00:00 10:00 10.00 9,278 10,383 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ motor f/ 9278' to 10383' MD 6024' TVD ADT- 6.7 hrs. = AST- 1.82 hrs. ART - 4.88 hrs. ECD- 11.53 ppg WOB 15/20 k RPM 110 GPM 620 @ 2600 psi String wt. PU 185 SO 127 Rot 155 Troque on /off btm.- 15,000/12,000 ft/Ibs. Took check shots @ 10,291' and 10,383'. 10:00 10:30 0.50 10,383 10,383 INTRM1 DRILL CIRC P CBU 650 gpm 2500 psi 110 rpm. 10:30 12:15 1.75 10,383 9,460 INTRMI DRILL REAM P POOH Backreaming from 10,383' to 9,460'. 550 gpm 1800 psi 100 rpm. Torque 12 k - PU wt. 150 So wt. 140 12:15 13:00 0.75 9,460 9,460 INTRM1 DRILL CIRC P Circ btms up @ 600 gpm @ 2150 psi w/ 100 rpm - Torque 11/12 k 13:00 13:15 0.25 9,460 9,460 INTRMI DRILL OWFF P Flow check (Static) Blow down TD 13:15 18:15 5.00 9,460 2,607 INTRMI DRILL TRIP P POOH f/ 9460' to 7678' - Hole taking proper fill - Pumped dry job - Blow down TD - Cont. POOH on elevators f/ 7678' to 2607' hole taking proper fill - No tight hole (monitor well - Static) 18:15 18:45 0.50 2,607 200 INTRM1 DRILL TRIP P Cont. POOH f/ 2607' to 754' (top of BHA) flow ck. Static - Std back HWDP to 200' 18:45 22:30 3.75 200 200 INTRM1 DRILL PULD P PJSM on handling RA sources - Pull up & Std back NMflex DC's - Unload RA sources f/ MWD tool - Down load MWD - set TM in mouse hole & pull pulser - LD neutron /density tool - Pull up & ck. bearing housing on motor, bit, & motor to MWD alignment - All OK - PU & MU new neutron /density tool - Install new pulser in TM collar - PU TM collar f/ mouse hole & make up to tool string - up load MWD 22:30 23:15 0.75 200 292 INTRM1 DRILL TRIP P PJSM on handling RA sources - Load RA sources in MWD tool - RIH w/ NM flex DC's & 1 std HWDP to 292' - Shallow pulse test MWD tools string - OK 23:15 00:00 0.75 292 1,032 INTRM1 DRILL TRIP P RIH f/ 292' w/ HWDP & 5" DP to 1032' 04/12/2010 RIH to 2607' - Slip & cut drill line - RIH to 5478' - MAD pass through K -2 formation w/ Neutron /Density tools f/ 5478' to 5800' - RIH to 10,294' - Wash & reamed to 10,383' - Drilled 8 3/4" hole w/ motor f/ 10,383' to 11,478' 00:00 00:30 0.50 1,032 2,607 INTRM1 DRILL TRIP P Cont. RIH f/ 1032' to 2607' 00:30 02:00 1.50 2,607 2,607 INTRM1 RIGMNT SLPC P PJSM - Slip & cut drill line & service rig 02:00 04:30 2.50 2,607 5,478 INTRMI DRILL TRIP P Cont. RIH f/ 2607' to 5478' - No problems hole in good condition Page 8 of 14 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 07:00 2.50 5,478 5,800 INTRMI EVALFN DLOG P Performed MAD pass w/ neurton /density tools through K -2 f/ 5478' to 5800' (bit depths) - 570 gpm @ 1700 psi w/ 100 rpm's - torque 10 k - PU wt. 115 SO wt. 94 Rot wt 110 Observed increase in flow @ btms up f/ 5478' w/ 586 units gas 07:00 10:00 3.00 5,800 10,294 INTRMI DRILL TRIP P RIH f/ 5800' to 10,294' - No problems 10:00 10:15 0.25 10,294 10,383 INTRM1 DRILL REAM P Washed & reamed f/ 10,294' to 10,383' - 570 gpm @ 2400 psi w/ 100 rpm's - 12 k torque - took check shot survey on btm. 10:15 12:00 1.75 10,383 10,478 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ motor f/ 10,383' to 10,478' MD 6062' TVD ADT- .80 hrs = ART- .37 hrs. AST - .43 hrs. ECD- 11.8 ppg Max. gas 461 units WOB 20/25 k RPM 110 GPM 600 @ 2800 psi String wt. PU 185 SO 127 Rot 152 Torque on /off btm.- 13,000/12,000 ft/lbs. Performed 550 bbls mud dilution while drilling - New mud contained product for drilling HRZ formation & mud wt. was bumped up to 10.5 ppg 12:00 00:00 12.00 10,478 11,493 INTRM1 DRILL DDRL P Drilled 8 3/4' hole w/ motor f/ 10,478' to 11,493' MD 6470' TVD ADT- 7.39 hrs. = ART -5.11 hrs. AST -2.28 hrs ECD- 11.86 ppg Max. gas 609 units WOB 15/22 k RPM 120 GPM 600 @ 2775 psi String wt. PU 197 SO 132 Rot 160 Torque on /off btm.- 14,500/12,000 ft/Ibs. 04/13/2010 Drilled 8 3/4" hole to 12,351' - Circ while waiting on well planner to run anticollision data for drilling deeper the planned TD if necessary due to formation top coming in lower - Drilled 8 3/4" hole to 12,421' - Circ btms up below base of Kup C - Drilled 8 3/4" hole to TD of 12,603' MD 6912' TVD - Circ 3 X btms up - standing back 1 std DP every 45 min.s to 12,239' 00:00 10:30 10.50 11,493 12,351 INTRM1 DRILL DDRL P Drilled 8 3/4' hole w/ motor f/ 11,493' , to 12,351' MD 6809' TVD ADT- 7.50 hrs. = ART -6.31 hrs. AST -1.19 hrs ECD- 12.24 ppg Max. gas 609 units WOB 20/25 k RPM 110 GPM 600 @ 3200 psi String wt. PU 210 SO 132 Rot 164 Torque on /off btm.- 14,00/13,000 ft/lbs. Page 9 of 14 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 13:30 3.00 12,351 12,351 INTRMI DRILL CIRC P Pull back to 12,332' - Circ btms up + @ 550 gpm @ 2400 psi w/ 100 rpm's - 14 k torque - Recrip f/ 12,332' to 12,239' - Due to formation tops coming in lower than prognosis - Well planner checking on anticollision data for drilling deeper than planned TD in necessary - Found close approach w/ CD3 -107 - Hard line TD @ 12,625' MD 6955' TVD 13:30 15:45 2.25 12,351 12,421 INTRM1 DRILL DDRL P Drilled 8 3/4" hole w/ motor f/ 12,351' to 12,421' MD 6843' TVD ADT. -1.63 hrs. = ART- .62 hrs. AST -1.01 hrs. ECD- 11.69 ppg Max. gas 249 units WOB 7/10 k RPM 100 GPM 600 @ 3150 psi String wt. PU 212 SO 133 Rot 165 Torque on /off btm.- 15,000/13,000 ft/Ibs. Note: Top of Kup C @ 12,360' & base @ 12,400' - Drilling Supervisor's picks 15:45 16:45 1.00 12,421 12,421 INTRM1 DRILL CIRC P Flow ck for 5 mins. slight flow - Circ btms up @ 600 gpm @ 2600 psi w/ 100 rpm's - torque 12 k - Max gas 136 units 16:45 20:45 4.00 12,421 12,603 INTRMI DRILL DDRL P Drilled 8 3/4" hole w/ motor f/ 12,421' to 12,603' MD 6941' TVD ADT.- 2.97 hrs.= ART- 1.22 hrs. AST- 1.75 hrs. ECD - 11.78 ppg Max. gas 90 units WOB 7/15 k RPM 100 GPM 600 @ 3000 psi String wt. PU 217 SO 134 Rot 168 Torque on /off btm.- 16,000/14,000 ft/lbs. 20:45 00:00 3.25 12,603 12,239 INTRM1 DRILL CIRC P Circ 3 X btms up while standing back 1 std DP every 45 mins.- f/ 12603' to 12,239' - 600 gpm @ 2625 psi w/ 100 rpm's torque 12,500 k - PU wt. 155 04/14/2010 Cont. Circ 3 X btms up & standing back Dp to 12,147' - Wiper trip f/ 12,147' to 11,405' - Flow Ck. Static - RIH to 12,517' - Wash & ream f/ 12,517' to 12,603' (TD) - Circ btms up - Spot casing lube pill to bit - POOH spotting lube pill f/ 12,603' to 11,405' - Monitor well (static) blow down TD & POOH on elevators f/ 11,405' to 754' (top of BHA - pumped dry job @ 10,479' - Worked through tight spot f/3065' to 3005' - Flow cked @ 9 5/8" shoe Static - LD 2 jts HWDP, jars, & 2 NM flex DC's - Remove RA sources f/ MWD - Down load MWD - LD BHA - Change top pipe rams to 7" & test - RU to run 7" casing - Ran 7" casing to 130' (3 jts + FS & FC) 00:00 00:30 0.50 12,239 12,147 INTRM1 DRILL CIRC P Finish circulate 3X bottoms up at 600 gpm - 2500 psi - 100 rpm. Std back one stand to 12,147'. 00:30 01:00 0.50 12,147 11,405 INTRM1 DRILL WPRT P Flow check well. Static. Backream out of hole at 550 gpm - 2150 psi - 100 rpm to 11,405'. No hole problems. Page 10 of 14 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:00 1.00 11,405 12,517 INTRM1 DRILL WPRT P Flow check well. Static. RIH to 12,517'. 02:00 03:15 1.25 12,517 12,603 INTRM1 DRILL CIRC P Wash last stand to bottom at 12,603'. Circulate and condition mud at 550 gpm - 1900 psi - 100 rpm. Max gas = 268 units. 03:15 03:30 0.25 12,603 12,603 INTRMI DRILL CIRC P Spot csg running pill to bit. 03:30 05:45 2.25 12,603 11,405 INTRM1 DRILL TRIP P POH slow while spotting csg running pill to 11,405'. 05:45 06:00 0.25 11,405 11,405 INTRM1 DRILL OWFF P Monitor well. Static. Blow down top drive. 06:00 07:00 1.00 11,405 10,479 INTRM1 DRILL TRIP P POH on trip tank with 10 stds drill pipe to 10,479' 07:00 07:30 0.50 10,479 10,479 INTRM1 DRILL OWFF P Flow ck - Static - Pump dry job. Blow down top drive. 07:30 14:30 7.00 10,479 138 INTRM1 DRILL TRIP P POOH on elevators f/ 10,479' to 3065' ( worked through spot f/ 3065' to 3005') Cont. POOH to 2607' (monitor well @ 9 5/8" shoe (static) Cont. POOH to 754' (top of BHA) Std back 4 stds HWDP & LD 2 jts HWDP & jars - Std back 1 std HWDP & LD 2 NMflex DC's to 138' 14:30 17:15 2.75 138 0 INTRM1 DRILL PULD P PJSM on removing RA sources - Removed RA sources f/ MWD tool - LD 1 NM flex DC - Down load MWD - LD MWD tools - Break bit & LD motor - clean & clear rig floor 17:15 20:45 3.50 0 0 INTRM1 WHDBO BOPE P Drain stack - Pull wear bushing - set test plug - PJSm on changing rams - Changed top VBR to 7" rams - Test to 250 & 3500 psi - RD test equipment - Pull test plug & test jt. - Install thin wall wear bushing - PU stack washer & flush BOP stack - LD washer 20:45 23:45 3.00 0 0 INTRMI CASING RURD P RU to run 7" casing - PU long bails - casing elevators - MU fill up tool - PU casing spider - 23:45 00:00 0.25 0 130 INTRMI CASING RNCS P PJSM on running 7:" casing - Ran 7" 26# L -80 BTCM casing as follows: Float shoe (Ray Oil Tools - silver bulltet) 2 jts casing - FC (Weatherford) to 130' 04/15/2010 Finished running 7" casing - 301jts total & 2 marker jts Landed w/ shoe @ 12593' - FC @ 12505' 00:00 00:30 0.50 130 170 INTRMI CASING RNCS P PJSM. Continue running 7" 26# L -80 BTCM casing f/ 130' to 170' - 4 jts total (Baker Locked 1st 4 connections - Fill pipe & check floats) 00:30 04:00 3.50 180 2,664 INTRMI CASING RNCS P Cont. RIH w/ 7" 26# L -80 BTCM csg f/ 170' to 2664' (63 jts total in + 2 markerjts.(20.01 & 9.94') 04:00 04:30 0.50 2,664 2,664 INTRMI CASING CIRC P Circulate csg volume at 4 bpm @ 375 psi.- PU wt. 90 SO wt. 90 Page 11 of 14 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 07:30 3.00 2,664 5,009 INTRM1 CASING RNCS P Cont. RIH w /7" 26# L -80 BTCM casing to 5009' (120 jts. total) 07:30 08:30 1.00 5,009 5,009 INTRM1 CASING CIRC P Circulate and condition mud at 3.5 bpm - 450 psi.- PU wt. 132 SO wt 95 08:30 11:00 2.50 5,009 7,502 INTRM1 CASING RNCS P Cont. RIH w/ 7" 26# L -80 BTCM csg to 7502'.(180 jts total) 11:00 12:45 1.75 7,502 7,502 INTRMI CASING CIRC P Circ & condition mud @ 7502' - stage pump up to 4 bbls /min @ 550 psi - PUwt165 SOwt.105 12:45 16:15 3.50 7,502 10,014 INTRMI CASING RNCS P Cont. RIH w/ 7" 26# L -80 BTC cag f/ 7502' to 10,014' (240 jts total) PU wt. 230 SO wt. 120 16:15 18:15 2.00 10,014 10,014 INTRM1 CASING CIRC P Circ & condition mud @ 10014' - Stage pump up to 4 bbls /min 650 - 550 psi - PU wt. 240 SO wt. 120 18:15 20:30 2.25 10,014 11,479 INTRMI CASING RNCS P Cont. RIH w/ 7" 26# L -80 BTCM csg f/ 10014' to 11479' (275 jts total) - PU wt. 240 SO wt 120 20:30 22:00 1.50 11,479 11,479 INTRM1 CASING CIRC P Circ & condition mud @ 11,479' - stage pump up to 4 bbls /min @ 550 psi - PU wt. 263 SO wt. 121 22:00 00:00 2.00 11,479 12,593 INTRMI CASING RNCS P Cont. RIH w/ 7" 26# L -80 BTCM csg f/ 11479' to 12565' (301 jts total) PU FMC fluted mandral hanger & landing jt. - Land casing on hanger in wellhead w/ shoe @ 12,592.86' - Float collar @ 12,505' - Marker jt #1 @ 12,402' - Marker jt # 2 @ 12,311' - Ran 51 Ray Oil Tool 7" x 8 3/8" straight blade centralizers - jts 1 -20 - jts. 237,238,239 & every other jt f/241 to 295 - PU wt 305 SO wt. 121 04/16/2010 RD cmt equipment - LD landing jt. Pull WB & set pack -off - test to 5000 psi - Change top pipe rams f/7" to 3 1/2" x 6 VBR & test - RU & Ran 4 1/2" completion to 9463' 00:00 00:30 0.50 12,593 12,593 INTRM1 CASING RURD P RD Franks fill up tool. Blow down top drive. RU cement head. 00:30 03:00 2.50 12,593 12,593 INTRMI CEMEN' CIRC P Circulate and condition mud stage pumps up to 5 bpm - 700 psi. Up wt - 260k. Down wt - 120k. 03:00 05:30 2.50 12,593 12,593 INTRMI CEMEN - CMNT P PJSM. Dowell pumped 5 bbls CW100. tested lines to 3500 psi, pumped 15 bbls CW100, 20 bbls 12 ppg MudPush, dropped bottom plug, pumped 36 bbls 15.8 ppq cement, flushed cement lines, dropped top plug rig displaced with 475 bbls sea water at 5 bpm. Reciprocated csg until cement was around shoe. Bumped plug to 500 psi above circulating pressure to 1700 psi. CIP at 05:12 hrs. Check floats OK 05:30 07:30 2.00 0 0 INTRM1 CEMEN" RURD P RD cement head. RD csg equipment. LD landing jt. 07:30 08:30 1.00 0 0 INTRMI WHDBO PRTS P Pull wear bushing. Install 7" pack -off and test to 5000 psi. Page 12 of 14 • i Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 10:15 1.75 0 0 INTRMI WHDBO BOPE P PJSM. Change upper rams f/ 7" to 3 1/2" X 6" VBR's. Test rams to 250 - 3500 psi. 10:15 10:45 0.50 0 0 INTRM1 WHDBO RURD P Pull test plug. Install wear bushing. RD test jt and equipment. 10:45 11:15 0.50 0 0 INTRMI DRILL RURD P RU to flush OA. 11:15 12:30 1.25 0 0 INTRM1 DRILL FRZP P Pump 100 bbls FW with rig pump at 4 bpm - 830 psi. Little Red Hot Oil pumped 45 bbls warm diesel for freeze protect. 12:30 14:00 1.50 0 0 COMPZ RIGMNT SLPC P PJSM. Slip and cut drilling line 107' - Service top drive. 14:00 15:00 1.00 0 0 COMPZ RPCOM RURD P RU to run 4 1/2" completion - Held PJSM on running tbg 15:00 00:00 9.00 0 9,463 COMPZ RPCOM RCST P Ran 4 1/2" 12.6# L -80 IBTM tbg & completion euqipment as follows: WELG - 1 jt tbg - tbg pup jt. - XN nipple w/ 3.813" ID w/ RHC plug installed w/ 3.725" No -Go- 1 jt tbg - tbg pup jt - Baker Premier packer 7" x 4 1/2" - tbg pup jt.- 1 jt. tbg - tbg pup jt.- Camco KBG -2 GLM w/ 1" dummy valve & BK latch - tgb pup jt. - 217 jts tbg to 9463' 04/17/2010 Finish running 4 1/2" completion - Test hanger seals to 5000 psi - ND BOPE - NU tree & test - Displace well w/ 3% inhibited brine (190 bbls) & 225 bbls diesel w/ DRA - Dropped rod /ball assembly - Set packer & test tbg & IA to 3500 psi for 30 mins. - RD lines - Set BPV - Secure well - Clean &clear cellar area - LD DP f/ derrick 00:00 03:15 3.25 9,463 12,211 COMPZ RPCOM RCST P Cont. running 4 1/2" 12.6# L -80 IBTM tbg w/ completion equipment f/ 9463' to 10,148' (236 jts total) - Install 4 1/2" Camco DB nipple (3.813" ID) - Cont. RIH f/ 10,148' to 12,186' (283 jts w/ 1 space out jt.) - MU tbg wear bushing retrieving tool - RIH & engaged WB - back out LDS - Pull tbg wear bushing - Break out retrieving tool - MU FMC 11" x 4 1/2" tubing hanger - MU landing jt. - Land tbg string in wellhead on hanger w/ tail @ 12,211.89' - XN nipple @ 12160' - Packer @ 12098' - GLM @ 12029' - DB nipple @ 2062' 03:15 04:00 0.75 12,211 12,211 COMPZ RPCOM RURD P RILDS - RD tbg running equipment - LD landing jt. 04:00 05:30 1.50 12,211 12,211 COMPZ RPCOM OTHR P Set TWC - Install landing jt. B - RU test euqipment - Test tbg hanger seals to 5000 psi for 10 mins. OK - RD test equipment & LD landing jt B 91 - Clear & clean up rig floor 05:30 05:45 0.25 12,211 12,211 COMPZ DRILL SFTY P PJSM on ND BOPE & NU tree 05:45 10:30 4.75 12,211 12,211 COMPZ WHDBO NUND P ND BOP stack - Remove Alipne wellhead adaptor spool - NU tree - RU & tree tree to 5000 psi for 10 mins. RD test equipment Page 13 of 14 • 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 12:00 1.50 12,211 12,211 COMPZ DRILL FRZP P RU squeeze manifold & lines to tbg & annulus 12:00 12:15 0.25 12,211 12,211 COMPZ DRILL SFTY P PJSM w/ Little Red & crew on displacing well 12:15 15:30 3.25 12,211 12,211 COMPZ DRILL FRZP P Test lines to 3500 psi OK - Displace well w/ 190 bbls 3% inhibited brine - 3 bbls /min @ 350 psi - followed by 185 bbls diesel w/ DRA - tbg volume plus 40 bbls to freeze IA to 2102' - 2.6 bbls /min @ 1300 psi 15:30 16:45 1.25 12,211 12,211 COMPZ DRILL PACK P RD hose on tbg side - RU lubricator - Drop packer setting rod /ball assembly - RU hose back to tbg - & test lines to 3500 psi 16:45 20:45 4.00 12,211 12,211 COMPZ DRILL PACK P Pressure up on tbg to 3500 psi to set packer & test tbg for 30 mins.- bleed tbg to 0 psi - pressure up on IA to 3500 psi & test for 30 mins.- bleed to 0 psi - vac out lines & RD lines - Set BPV - Secure well & clear & clean cellar area 20:45 21:00 0.25 0 0 COMPZ DRILL SFTY P PJSM on laying down DP 21:00 00:00 3.00 0 0 COMPZ DRILL PULD P Lay down DP f/ derrick via mouse hole - 72 jts 5" DP & 15 jts. 5" HWDP 04/18/2010 Finish LD DP - Clean rig for ice road move Released rig @ 2359 hrs. Rig off high line power @ midnight 00:00 08:00 8.00 0 0 COMPZ DRILL PULD P Finish LD DP 5" DP & 4" DP f/ derrick for rig move. 08:00 00:00 16.00 0 0 COMPZ DRILL OTHR P Clean rig floor - mud pits - under rig floor mats - pipe racks & drip pans - Clean pump room - Remove ConocoPhillips radios & computers f/ rig - Turn off gycol heater - clean cellar area - remove water f/ cellar box - Clean rock washer - Clean out vac unit Released rig @ 2359 hrs 4/18/2010 Move rig to Prudhoe Bay for BP Page 14 of 14 CD3 -302A Post Rig Summary Ai DATE SUMMARY 4/19/10 PULLED BALL & ROD FROM RHC PLUG @ 12160' RKB, PULLED RHC PLUG BODY FROM XN NIPPLE @ 12160' RKB, TAG BOTTOM @ 12503' SLM W/ 22' X 3.5" DUMMY GUN. COMPLETE MOVE TO CD3 -304 4/21/10 UNABLE TO RIG UP UNITL 18:45 DUE TO NON - AVAILABILITY OF A THIRD PARTY CRANE. RCBL TOOL FAILED AT 11,200' BEFORE LOG OF THE DESIRED INTERVAL COULE BE MADE. IN PROGRESS... 4/22/10 24 HOUR OPERATIONS: COMPLETE RADIAL BOND LOG FROM 12480' TO 12100' AND PERFORATE FROM A DEPTH OF 12371' TO 12391' WITH A 3 1/8 ", 6 SPF, 60 DEG PHASING GUN. 4/23/10 24 HOUR OPERATIONS: PERFORATE FROM A DEPTH OF 12361' TO 12371' WITH A 3 1/8" MILLENIUM GUN, 6 SPF, 60 DEG PHASING. 4/25/10 TUBING OPEN 3.80 TO 12160' RKB, MEASURED BHP @ 12157' SLM MAX (PSI 3092.31 / TEMP 165.74), SET 3.812 A -1 INJ VALVE @ 2060' RKB (SIN: HRS -53) GOOD CLOSURE TEST. MOVE TO CD3 -304 5/3/10 (ISW) INITIAL STATE WITNESSED MITIA - PASSED. , 0 • If..r.CHANICA.L Tynan REPORT • s PUD ID.1.7.!: - . 1 4 /7/ 2.° '" OPER E FIELD RIG R EL Eft:. : : . 2 --//z0 614) Val NUMBER CD 3 - 3 oz_A- 11 DATA 'YD : 12( ICI. (D TV) .; ?TD: i 2 5 °711D 6,8E7 Tvi) 7 " Casing : Shoe : /2.5,3 HD 7 g s TVD ; DV : - 11D .7 4.--:,:alliiFT Sboe: IC rip ; TOP: HD Tv-D 1 . S .5 :ubing : P &cker 12-__EILte) Tvp ; Set at ........,...,,.............. cle Size and ; Perfs 12 36) 1 to /2..S/ t .' . 111.°CRA.NICAL INTEGRITY - PART 11 . Annulus Press Test: IP S50b 1 15 min ; 30 rain . C omments: L.,_7412......lere.s.54r , eSA ,...... . . KECHANICAI, INTEGRITY - PART ? 2 1 Cement Volumes: Amt. Limor, ----- G 7 " ag ; DV Cmr vol to cover perfs ' .................. Theoretical TOG 4-- ....................................÷.........................,................ 7 .. Cement Bond Log (ies or No) V-A ; In AOGCC File CBL Evaluation, on above perfs er creA__ 2:4: t --' O ProducZion Log: Typt A i 14 1 Evaluation . ,marposr 4110911111•■•■•0181011.MMINIMM.¢0 • • CONCLUSIONS 7. ir t 11 : it- W;4-rtess c.....0 M ( ( CS ( 2 .44, ,,,j - PolUe-P Par: i 2 c C --meTe...-,-=-4zrzarzscomgracr=ssarsaguic-a-avn.- tic seve A • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday, May 07, 2010 P.I. Supervisor I 'l "It 14° SUBJECT: Mechanical Integrity Tests 6 CONOCOPHILLIPS ALASKA INC CD3 -302A FROM: John Crisp COLVILLE RIV FIORD CD3 -302A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: COLVILLE RIV FIORD CD3 - 302A API Well Number: 50 103 - 20522 - 01 - 00 Inspector Name: John Crisp Insp Num: mitJCr100504063857 Permit Number: 210 - 035 - Inspection Date: 5/3/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well C D3- 302A' Type Inj. W /TVD 6701 / IA 80 3000 ✓ 2960 2940 P.T.D 2100350 ' TypeTest SPT Test psi 1675.25 ' OA 360 423 385 369 Interval INITAL P/F P -' Tubing 2080 2080 2080 2080 Notes: 5 bbls pumped for test. Friday, May 07, 2010 Page 1 of 1 • . WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 29, 2010 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: CD3 -302A Run Date: 4/23/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD3 -302A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20522 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Of Office: 907 - 273 -3527 , 9 60 /9 Fax: 907 - 273 -3535 1 rafael.barret ubrmo Date: ' ' `° ,i .3, Signed: ..,42a113 1_7111T133P,P w • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 29, 2010 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: CD3 -302A Run Date: 4/22/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD3 -302A in DLIS format, Digital Log Image file 1 CD Rom Digital Data g S e 8 50- 103 - 20522 -01 Radial Cement Bond Log 1 Color Log 50 -103- 20522 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. o - 03 5 Anchorage, Alaska 99518 � 6093 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 rafael.barret o com Date: s ?;l i : ,a illr' Signed: _ • WELL LOG TRANSMITTAL To: State of Alaska April 26, 2010 Alaska Oil and Gas Conservation Commission Attn.: Christine Mahnken 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 RE: MWD Formation Evaluation Logs: CD3 -302A AK -MW- 0006991493 CD3 -302A 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 50 -103- 20522 -01 2" x 5" TVD TRIPLE COMBO Logs: 1 Color Log 50 -103- 20522 -01 Digital Log Images & LWDG- formatted LIS Data w /verification listings; 1 CD Rom 50 -103- 20522 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3536 7/ C� _ d Fax: 907 - 273 -3535 Bryan.Burinda @halliburton.com ` J ( REC Date: APR G - Signed: CA :1 3as CC9.3. nIrr+n9ie ' AilettCrOrk' I 1 1 STATIE DIF ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GA 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Colville River Field, Fiord Oil Pool, CD3 -302A ConocoPhillips Alaska, Inc. Permit No: 210 -035 Surface Location: 3902' FNL, 699' FEL, Sec. 5, T12N, R5E, UM Bottomhole Location: 999' FNL, 3905 FEL, Sec. 33, T13N, R5E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to redrill the above referenced service 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 in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. incerely, Daniel T. Seamount, Jr. Chair DATED this 30 day of March, 2010. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e -mail) Department of Environmental Conservation w/ o encl. (via e -mail) RECEIVED III STATE OF ALASKA • R 2 '2010 ALASKA OIL AND GAS CONSERVATION COMMISSION MA PERMIT TO DRILL 20 AAC 25.005 Q2 1a. Type of Work: . 1 b. Current Well Class: Exploratory ❑ Development Oil ❑ 1c. Specify if well is proposed for: Drill ❑ Re -drill El Stratigraphic Tesl l Service In • Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone❑ Single Zon 1 . Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180 • CD3 - 302A • 3. Address: 6. Proposed Depth: Aty •z.,.,c_ 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD:,B'' ( Z ,- TVD: 6869' • Colville River Field 4a. Location of Well (Govemmental Section): 7. Property Designation: y - /t' Surface: 3902' FNL, 699' FEL, Sec 5, T12N, R5E, UM . ADL 372105, 364471 f 2,7K / ` ' Fiord " 3iI Pool • Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1168 FNL, 3990 FEL, Sec 33, T13N, R5E, UM LAS2112 4/6/2010 Total Depth: 9. Acres in Property: 14. Distance to 999 FNL, 3905 FEL, Sec 33, T13N, R5E, UM 2560 Nearest Property: - 3000' from Fiord PA 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 41.5 feet 15. Distance to Nearest Well Open to Surface: x - 388344.47 y - 6003869.5 Zone - KB Elevation above GL: 28 feet Same Pool: Fiord 5 , 1383' @ 12343' MD . 16. Deviated wells: Kickoff depth: x.1-96 / f 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: S6.5 de Downhole: 3750 psig • Surface: 3063 psig • 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8.75" 7" 26# L -80 BTCM 12495 28 28 12523 6871 150 sx 15.8 cl G + adds -67175" 4.5" 12.6# L -80 IBTM 12158 23 23 12181 6750 Production tubing 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor /Structural 114 16" Pre - installed 114 114 Surface 3,196 9 -5/8" 440sx ASL3, 230 sx cl G 2,669 2,504 Intermediate 12,024 7" 248 sk cl G 8,543 6,791 Liner 11,863 4.5" 11,630 6,800 Perforation Depth MD (ft): Perforation Depth TVD (ft): 8782 -9743, 10064 -11628 6796 -6813, 6817 -6801 20. Attachments: Filing Fee ❑ BOP Sketch Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis 0 Property Plat 0 Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements El 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Mike A. Winfree @ 265 - 6820 Printed Name G. L. Alvord Title Alaska Drilling Manager Signature Phone 265 -6120 Date 3/22/2010 7 Commission Use Only Permit to Drill API Number: 1 Permit oval See cover letter Number: /('� C ' "=>` �C _ -•" 50 - /[. 3 - C.., X 2-2 - (,, / __eC Date: .1,1 for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed mane, gas hydrates, or gas contained in shales: 4 3500 ps4 B 8r 7Zot Samples req'd: Yes 111 No Mud log req'd: Yes ❑ No j Other: • 2 5 2 : 6 e•` Ahn. 7 , F6 )2S measures: Yes ❑No IY Directional svy req'd: Yes Er No ❑ - De! )� - tes t- La a,c� - � Zo M 2S. z 85CA) par Cam..e- -t �" 1 L G C ( .4,4.,.„..-L.. ape_r. ..-.- i s � e e c e O A IO 30 MI APPROVED BY THE COMMISSION Co C2 DATE: 1� , COMMISSIONER Form 10 -401 (Revised 1/2009) ubmit in Duplicate 4 3• �y•ic ` . �/d ) .7'E. • CD3 -3O2A Drilling Hazards Summary (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 8 -3/4" Hole / 7" Casing Interval Event Risk Level Mitigation Strategy Abnormal Pressure . Low BOPE drills, Keep mud weight above 9.6 ppg. Check for flow during connections and if needed, increase mud weight. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material. Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir . Low Well control drills, increased mud weight. No Pressure mapped faults occur within 500' of the planned wellbore. Sub - seismic faults are possible. Hydrogen Sulfide gas Low H drills, detection systems, alarms, standard well control practices, mud scavengers ORIGINAL • Fiord : CD3 -302A Procedure 1. Move on Doyon 141. Confirm that a BPV is installed before MIRU. 2. Pull BPV. RU to wellhead and circulate 11.3 PPG KWF through tubing cut at 5,865' MD' a. Note: PT on pre -rig cement plug failed (1/19/2010). Plug broke down at 1,800 psi and was able to inject 0.75 bbls /min at 1,800 psi. Pumped 6 bbls away. b. 11.3 PPG KWF based on 10.5 PPG reservoir and a seawater gradient below the tubing cut. 3. Install two way check. %r t �' � r ° `r` � 7ct, ( �',�lf�1_ t'e7f . c,`( re 4. ND Tree. (2 barriers: TWC and KWF) 5. Install blanking plug and NU BOPE. 6. Test all BOPE except for lower rams. Defer lower ram test until tubing is out of the hole and a test plug can be run. (Interference with blanking plug crossover) 7. Pull two way check. 8. Pull 4 -1/2" Tubing Hanger and LD 9. RU to pump cement through tubing. 10. Lay in plug and perform hesitation squeeze to isolate Kuparuk 11. Pull and LD 4 -1/2" tubing 12. Set test plug and test lower rams to 3500 psi. 13. RIH with CIBP and set at 2,820' MD 14. MU and RIH with Baker Mechanical Casing Cutter to 2,769' MD 301 '� 15. Cut 7" Casing with mechanical cutter at +/- 2,769' MD and pull. 16. RU and pump a cement kick off plug from the top of the CIBP at 2,820' MD to 100' inside the surface casing (2,570' MD). 17. Open hole sidetrack below surface casing with 8 -3/4" Drilling assembly at 2,700' MD 18. Drill out 20' of new hole. Perform leak off test. 19. Drill 8 -3/4" intermediate hole to target in the Kuparuk C sand. (LWD Program: GR/RES /PWD) 20. Run and cement 7" casing as per program. Cement 2 stage to cover Qannik if found to be hydrocarbon V bearing. Carry out a leak off test down the 9 -5/8" x 7" casing annulus to confirm the fracture pressure ,, referenced to the casing shoe. Freeze protect casing annulus and casing. -l" 21. RU and run cement bond log. 22. Run upper completion of 4 -%2, 12.6 #, L -80 tubing with DB profile, packer, 1 GLM, XN profile and wireline entry guide. Land hanger. 23. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 24. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Tr cc- ' 25. Shear valve in the gas lift mandrel. ORIGINAL • • 26. Circulate tubing to diesel and install freeze protection in the annulus. 27. Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 28. Set BPV and secure well. Move rig off. ' Post rig well work will include pulling the ball and rod assembly, perforating and GLV change out. ORIGINAL • Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in the following attachments. The following wells are close proximity risks to the CD3 -302A plan: • CD3 -302 Ellipse overlap: 0.90' @ 2,791' MD • CD3 -302 PB1 Ellipse overlap: 11.96' @ 2,790' MD • CD3 -302 PB2 Ellipse overlap: 11.96' @ 2,790' MD • CD3 -302 PB3 Ellipse overlap: 1.00' @ 2,791' MD Drilling Area Risks: Lost circulation: Sub seismic faulting within the Kuparuk reservoir section is considered to be the most likely • cause of lost circulation. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation. Well Control: Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. There are good pore pressure estimates based on 2 recent Kuparuk cut points on CD3 -106 and CD3 - 301 APB1. Annular Pumping Operations: Incidental fluids developed from drilling operations on well CD3 -302A will be injected into a permitted annulus on CD3 pad or the class 2 disposal well on CD1 pad. The CD3 -302A surface /intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The significant hydrocarbon zones are the Kuparuk, and the Qannik reservoir. There will be 500' of cement above the top of the Qannik reservoir. Upon completion of CD3 -301A form 10 -403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable /industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2494') + 1,500 psi = 3056 psi Pore Pressure = 1,128 psi Therefore Differential = 3056 —1128 = 1928 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9 -5/8" 40 L -80 3 BTC - Mod 3,090 psi 2,626 psi 5,750 psi 4,887 psi 7" 26 L -80 3 BTC -Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi ORIGINAL • • DRILLING FLUID PROGRAM Production Long String Hole Section — 8 -3/4" Density 10.0 —10.5 ppg PV 10 -16 YP 13 -16 in upper clay section /18 -22 in lower section 6 RPM 4 -8 through the K@ / 9 -11 Albian to TD Initial Gels 8 -10 10 minute gels <20 API Filtrate <5 cc / 30 min HPHT <8 cc /30 min by the HRZ PH 9.0 -9.5 Production Long String Hole Section: The production /longstring section will be drilled with fresh water LSND mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Weight up to 10 PPG before drilling the HRZ and gradually weight up to 10.5 before penetrating the Kuparuk production zone. ORIGINAL 41 • Completion Schematic Planned CD3 -302A Fiord Kuparuk Injector Completion Al 16" Insulated Conductor to Sperry Sun 114' CD3- 302Awp14 3 ° 4 -' /z' 12.6 ppf L - 80 IBT Mod. Tubing Updated 03 -22 -2010 4 - '/2" DB Nipple 9 -5/8" 40 ppf L -80 BTCM Surface Casing il; . 0 E I tu,a% C 7ec dPdtut. r' Upper Completion: Top MD TVD 1) Tubing Hanger 32' 32' 2) 4 -W ", 12.6#/ft, IBT -Mod Tubing 3) 4 -'/2" DB Landing Nipple (3.813 ") 2074' 2000' with DB Profile 4) 4-W", 12.6#/ft„ IBT -Mod Tubing K2 /Qannik sand 5) Camco KBG -2 GLM with DV 11981' 6670' +/- 5445' MD / 6) 4- ' /2 "', 12.6#/ft„ IBT -Mod Tubing 4104' TVD 7) 4 -'/2" x 7" Baker Premier Packer 12081' 6710' • 8) 4- '/2 " ", 12.6#/ft„ IBT -Mod Tubing (1 jt) 9) 3.813" HES No -Go "XN" (3.725" NoGo) 12131' 6730' with RHC Plug 10) 4- '/2 " ", 12.6 # /ft„ IBT-Mod Tubing Stage Cementing Tool 11) Wireline entry guide 12181' 6750' If Required Perforate Post Rig: +/- 14348' - 14368' SLB 2 -7/8" Powerjet Omega 6SPF Top of intermediate cement 300' above packer depth 11781' MD / 6660' TVD ' 0 © �� , 6 -1/8" TD @ 441,`_e 1 2523' MD / 6,870' TVD Kuparuk C 12,317' MD / 6,789' TVD 7" 26 ppf L -80 BTC Mod Production Casing @ +/ -50° 12,513' MD, 6,869' TVD ORIGINAL • 0 CD3 -301A PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling (in) MD/TVD(ft) (Ibs. / gal) (psi) (psi) 16 114 / 114 10.9 52 53 9 5/8 2669 / 2495 14.5 1128 1631 7" / TD 12513 / 6869 16.0 3750 3063 NOTE: The Doyon 141 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb./gal to psi /ft 0.1 = Gas gradient in psi /ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP =FPP — (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16 ") ASP = [(FG x 0.052) — 0.1] D = [(10.9 x 0.052) — 0.1] x 114 = 53 psi OR ASP = FPP — (0.1 x D) = 1128 — (0.1 x 2495') = 879 psi 2. Drilling below surface casing (9 5/8 ") ASP = [(FG x 0.052) — 0.1] D = [(14.5 x 0.052) — 0.1] x 2495 = 1632 psi OR ASP = FPP — (0.1 x D) = 3750 — (0.1 x 6869') = 3063 psi ORIGINAL • • Cementing Program: 7" Casing 12,513' MD / 6,869' TVD Cement from 12,513' MD to 11,781 + / -' MD (minimum 500' MD above top of Kuparuk C reservoir) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (12,513' — 11,781') X 0.1503 ft /ft X 1.4 (40% excess) = 154 ft annular vol. 80' X 0.2148 ft /ft = 17.2 ft shoe joint volume Total volume = 154 + 17.2 = 172 ft => 150 Sx @ 1.17 ft /sk ORIGINAL • • N IN 1 _ii ConocoPhillips(Alaska) Inc. Western North Slope CD3 Fiord Pad CD3 -302 Plan: CD3 -302A Plan: CD3- 302Awp14 Standard Proposal Report - " fc 15 March, 2010 Changed Kuparuk C target (12' ull shallower) and changed the RKB ___L 1 to Doyon 141's. required _ _ 1, .. - , liALL-IBIJRTOrd Sperry Drilling Services P Y 9 ORIGINAL • • I 3 ° 2 xm V22J mi Y I I I I I I I I I 1 I 8g8m ^^ �° 82 1 1 1 1 _ O o10� LL x 3 x'$ s s° 1 �g� „ - _ ° C --I X003"°° � �C - 6 �,pi Ri,B��n i°nuu�n�e Ww n n S t 22222222 1 8888 n a°•! O I 4 N9RE - 0 — Z Eniiimmmm �Se�mmmme ^u A - ^or^,2.9 - NN &R 11 'moo $rm�mmm a R� g° 1 1 0° — ° Fn ° � m'$ S$ n � °��mee ^ o - 1` $ 1 1 c Y ti 0000 _ E ` �' 0 - R 8 ° S 1 ', 00 - + y I I I I I I 1 I I I I 1 3 1 . ■ 1 00 —8 1 2 A 0 m - G N c h - O - u ^ L 3 0 0 S O — 1° n 'o w O _ D - T.:.— a m \ 00 - N 3_ - n a p : . h 0 0 ° o �` v ri - LL O I 2 o ice' ~ LL H 0 0 - - N m J N _ ` f= I - - 0 ° c - in Y M 1 1 I I 1 1 1 1 I I i I 1 1 1 1 1 - 1 -- 00 i ` Y - (Un 0002) ( +)4Y 1 . ' � _S 0000 1. ^ I 1 1 o _ II n N 888 — - 0006 ! m - - it r c 2 NS 292 t I .... 1 U d M g m'R r � rcLLZ - g 1; - 8 S M � cc °g -i - II 46 -Wg 1 - II _._& o Q II 0��3 u $_ :1,,, O _ 4 11111 1 ,. : 1 I�1 — g o0 N 8 S 2 * g0 7 - m O °- & F _te .: gl 1 I c 11 2 _ 1 I.I o �g „, ar, m u � mm -nmmm - ° o 0 1 m � DOpg I - - Vm m 8u � N m` voS � 000 j - a l E � �n .°, o m \ ` \ 0009 1 \ 00 I ! 1 1 1 ! Pg �� i mg� v ��nn a$ oo!n!!o °d °d— r �� 1 1 ,g 1 11 I — a 1 Q 8 �_ U „ff §§sa €3 €' °08842E8 - a J \ 1 ‘, p ,e�Q I II I ! - o s S 3 �� = e� �$ Wmm?.emerm \ 1 "9y 1 1 1 1 0 ° _g nn nO �nnn _ rc a \ S g1 1 1 - 3 snH �& 'IA ' Y �� 1 .41.'9 _ I II 1 o ° $$ E r 22. - # - 1 1 E N 111 s $m °°N°n a . S S 1151t$ = m 1 1 1 1 ' - 1 p Q m U § � o Hr m mm Sm o ` f 1 1 11 � 1 - U U a gig a 3 ' ;me m - o ` N 1 11 I .I - � 99 p mmm -m ° m m In 11 I �� == ti c42 S°mnw 4 ..:43 1 1 - I ,I —9 8 T. a mmem E. M om s ;!E,°!!!!;".1'.1 1 1 1 1 1 ' , I a` 3 g228 m'FS — 1 11 1 1.1 '- •• tan Q� �/1IA�' ''A - 1 1 1 1 — M/ j fw.. m 0NH"m''6ee _ 1 1 I 1 1 1 1 - y � nm I I 1 1 - _ 1 1 o •� V 8 den ry_� 111 g 1 _ 1 1 2 �It '+ `3 nnne^,A63m _ I II C I Y 11 $. - ( z ^ ^n m��^ 11 m I.1 Y ° tam iv c ^.m,S °n I II N '1' 1 1 U ,. 1 ^ � y mm nmmmm _ 1 Ti 1 11 Y m 1 �1 1 ,. k I — cZ r fim �m�W Nmmme 1 11 I ..ft' m ` I I 2 r.” ®m me _ 1 m 1 I I v` ¢ 1 1 m 1 I 1 I . - kg m m - I \1 I m - ie 2, N M I II I m rn \ 111 l Y n r\ yym r� «m �^^ - 11 I I N . 11 0 u i ' _ > � n� O \ I Y-- \\\Iy1� Y Q 11 �. 11 . C „a t m 1 1 I I I I 1 I I I. I < 1 10i� v 1 W s 8 s (a!M OOSZ) 41da4 !eo!}lan owl ORIGINAL • 0 S *w« °rvxsxm in. o f I I I I I I I I I I I I I I 1 1 1 I I 1 1 1 I g sr a u m x m xi 1.1 - �$� Y 5 - - Q as —I Q smw s °r ,9a8em�� o m °__rvrvrvry - � = o / _ s � aa mm �� ..meggm sssassooso ass - MIMI r - �< �i ➢�$o_ «RRm ma vssss so 7 _ Ma NRRRRR° ii ' 1 / ti p — 8 ,i, 01 „ II /.x n v o; Q 0 - c a/ 1 c/ / / 2 f\ s a G - m e ° n - ° I. 0? /. o _ + S g % n `�' p 0 I I I I I I I I O n O - i- a C ry — 8 m a O — Sf o O t Op 3 n _ ,,c, ❑ o U c H \ Np0 o 1° N \ O Op o z m Q ® � 4 2 O _ o N G 1 -° W d l �-'\ 3 1 r o ,..— % t 0 / O 4.'4 N I / / N W C 8 '11 11LL l a 0 c U - J N 0 0 l7 . !� \ / r m = o ❑ m F r �\ &2 \ \\ y n a 2p N Y .... 'm m Op p • �i: I I I I I I 1 I I 1 I 1 I —T ° I I 1 1 L- - -+r 8 $ M a / '' I I - 'I c.„ -- ( °V8 00S6 ( +)4iioNd r Y ' 00,04, I y ~ I 'lI / m - v.' I I / a 3 1 N —§ ° N q, g � I 7 OL I I M N 41� m '.I/ ' U C mm • YY p / gg N \ Q 1 J .-E 1_ D o r „' e. I , U 0 O ° g $ ° m s — a i— a m o 1 I N u O M t� mS: o o I- 1 N 000 n o 0 M CC 'pp o yy H `ma mm _«mna _ m 1°n N " "o' 1 v 6 ae N m r U _ F � k a ! P m O s 0 °nns.1 -- _ c o \ m ` Opp 9 II I I - > e m $s n 3222,212E-22 c oo S \ \ _ _ I i @ 9 S , $ S' ° o mig - oa C1 � y rn \ li F ` it Z I T :n °a °a��vea ° s\ \\ \\ \ 1 a= 8 � -� uuc € '�'C: °cres - c \ \ oa\ I , 1 1 !I ill I µy, � � • �a °s g 3 ° a � 8 e ° p av ,;2 ,;2 t F 3 $c n�a F � J,1 S°°S F mm °° °° m m F. qPmmm R i// 1 I II —. 8882=-828 ry 'I N � 2. p °CAmRdR« — 1 1 11 - °° � ssRmR6mm I _ .. u ' a Zed °' "5Nm 1 0 MOM X ` 3 F rvn «nnmm.e Z 1 Y 'I f m ' - OWEN €a - e .mm; �F: - pmj o id : �m n n mmm ° ' I I ' Y S V vino nrvrvrvry N I ° `r- y °nn � c9nmry °n,n °m, °n, W 1 / Y .n i1 1 11 i U - E awn zu n — 3 1 / , Q \,. 1 coo 'I I a —P U mm ANN - M m Y - ■ � IT I 1 W \ I I�1 \ I / Z N I,' \Ia l \\1 6 / / �Mc m�rvmanm�m 1 I I I I I I 1 • 1 I I I I i I \ I I I �o S I 11,11 (u!M OOSZ) 41de0 ImpeA Imp arul ■ UhIUIN L • • o M Northing (3500 ft/in) o I I I I I I' 1 1 mil 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 J1 i I 1 1 1 1 1 1 1 1 mil 1 1 1 l l 1 P1 11 1 1 1 1 1 1 1 1 I 1 1 _ o - — o - n a - 0 c0 L, c O M ❑ - - L M M U — U M - 0 0 - M O - — r n — 3 o - cn - I I - fly o - M Q - - o O - '? U N M ■ - o p M - Q U - 0 U N — N d - c) 3 3 o 0 U N �‘TI c� — r� C. C? 7 Ca 10111 U o ..0 N _ 0 11 o — CL 44111111k641%, CO C_ m 3 0? Nv\‘:' ❑ 0 c a) Q on , N O U, ❑ I l i , co o - W ❑ - _ U J M U - A — ❑ — U N M _ - U - M p U d- — U Q ? — a _ c -a _ M YLa _ U r.... M C . 1- ❑ M - °D0 - - t w' V - �� — - N O - - 0 O - 0 0 - 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 T 1 r 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 T 1 1 1 1 1 1 1 1 1 1 1 1 1 1 t7RTGrNA L • • ConocoPhillips HALLIBURTON Standard Proposal Report 1 Database EDM v16 Prod Local Co- ordinate Reference: 11111 Well CD3 -302 Company: ConocoPhillips(Alaska) Inc. iwference: Plan: CD3 -302A (28 +13.2) @ 41.20ft (Doyon 14 f Project: Western North Slope = + Refire ce: I Plan: CD3 -302A (28 +13.2) @ 41.20ft (Doyon 14 Site: u ' CD3 Fiord Pad ri4lortil Reference: 0 True ir Well: CD3 -302 Survey Calculation Method: Minimum Curvature .1Nellbore: Plan: CD3 -302A ;Design: CD3- 302Awp14 Plan Annotations Measured Vertical Local Coordinates Depth Depth +NI +El W "" (ft) (ft) �. (ft) (ft) Comment 1 Illdu01 2,770.20 2,580.29 652.40 493.62 KOP: DLS 1.30 TFO 30.00 2,810.20 2,613.79 670.75 505.50 Start DLS 3.00 TFO 30.00 2,910.20 2,696.03 717.64 537.67 Start DLS 2.50 TFO 35.00 3,791.20 3,311.02 1,161.82 974.86 Start DLS 2.50 TFO -68.18 4,745.45 3,779.25 1,809.82 1,483.17 Start 7572.47 hold at 4745.45 MD 12,317.92 6,789.23 8,016.66 4,606.84 Start 55.35 hold at 12317.92 MD 12,373.27 6,811.23 8,062.03 4,629.68 Start 150.00 hold at 12373.27 MD 12,523.27 TD at 12523.27 110 11 Ii 0 3/15/2010 5:28:28PM Page 7 COMPASS 2003.16 Build 69 D RIGINAL 6 1 0, I q ' p lh 11 l00 11 ll �, l ,I ConocoPhillips(Alaska) Inc. -WNS 11 0 {' Western North Slope V 011 CD3 Fiord Pad CD3 -302 1 ' n Plan: CD3 -302A r , 0 CD3- 302■wp14 • l I nti'1 X il l q 11 ' � '�' r" Drilling Services L immilmin ll �!�1�i v Clearance Summary II, Anticollision Report required ....' , 1 p pli 15 March, 2010 i l & ' B' Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) C '� Reference Design: CD3 Fiord Pad - CD3 -302 - Plan: CD3 -302A - CD3- 302Awp14 • Well Coordinates: 6,003,616.73 N, 1,528,376.38 E (70° 25' 09.12" N, 150° 54' 45.97" W) F El Datum Height: Plan: CD3 -302A (28 +13.2) 641.20ft (Doyon 141) X11 � u Scan Range: 2,770.20 to 12,523.27 ft. Measured Depth. 'I Scan Radius is 1,449.53 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied II G �6 Version: 2003.16 Build: 69 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference al A da 1 � Scan Type: 25.00 i i a HALLIBURTC3N Sperry 'Drilling Services u' 1111 ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for CD3 -302 - CD3- 302■wp14 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - CD3 -302 - Plan: CD3 -302A - CD3- 302Awp14 Scan Range: 2,770.20 to 12,523.27 ft. Measured Depth. Scan Radius is 1,449.53 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft CD3 Fiord Pad CD3 -106 - CD3 -106 - CD3- 106wp10 2,787.07 484.44 2,787.07 430.85 3,025,00 9.041 Clearance Factor Pass - Major Risk CD3 -106 - CD3 -106 - CD3 -106 2,773.60 461.32 2,773.60 410.18 3,000.00' 1 11 9.020 Clearance Factor Pass - Major Risk CD3 -106 - CD3 -106L1 - CD3- 106L1wp11 2,787.07 484.44 2,787.07 430.85 3,025.00 9.041 Clearance Factor Pass - Major Risk CD3 -106 - CD3 -106L1 - CD3 -106L1 2,773.60 461.32 2,773.60 410.18 3,000.00 9.020 Clearance Factor Pass - Major Risk CD3 -107 - CD3 -107 - CD3 -107 12,514.90 664.54 12,514.90 394.99 16,700.00 2.465 Clearance Factor Pass - Major Risk cD3.107 CD3 - 107L1 - CD3 -107L1 12,520.12 558.83 12,520.12 28806 40,800.00 2.041 Clearance Factor Pass - Major Risk CD3 -107 - CD3 -307 - CD3 -307 2,776.87 822.13 2,776.87 770 ,13 3,075.00 15.809 Clearance Factor Pass - Major Risk CD3 -108 - CD3 -108 - CD3 -108 5,770.57 420.32 5,770.57 308.92 5,575.00 3.773 Centre Distance Pass - Major Risk CD3 -108 - CD3 -108 - CD3 -108 5,887.42 422.83 5,887.42 1111 305.91 5,700.00 3.616 Clearance Factor Pass - Major Risk 1 D3 -109 - CD3 -109 CD3 - 109 4,646.19 209.45 x#,646.19 115.29 4,600.00 2.224 Clearance Factor Pass - Major Risk CD3 -110 - CD3 -110 - CD3 -110 2,789.39 365.49 2,789.39 1 315.23 2,825.00 7.273 Centre Distance Pass - Major Risk CD3 -110 - CD3 -110 - CD3 -110 2,860.46 366.18 2,860.46 314.68 2,900.00 7.111 Clearance Factor Pass - Major Risk CD3 -111 - CD3 -111 - CD3 -111 2,776.09 1,194.51 1 2,776.09 1,143.62 3,100.00 23.471 Clearance Factor Pass - Major Risk CD3 -111 - CD3-111L1 - CD3-111L1 2,776.09 1,194.51 2,776.09 1,143.62 3,100.00 23.471 Clearance Factor Pass - Major Risk CD3 -301 - CD3 -301 - CD3 -301 2,784.08 844.49 1 11 2,784.08 795.66 2,900.00 17.293 Clearance Factor Pass - Major Risk CD3 -301 - CD3 -301 PB1 - CD3 -301 PB1 2,784.08 844.49 2,784.08 795.65 2,900.00 17.293 Clearance Factor Pass - Major Risk CD3 -301 - Plan: CD3 -301A - CD3- 301Awp07 2,770.20 835.84 2,770.20 787.22 2,875.00 17.191 Clearance Factor Pass - Major Risk CD3 -301 - Rig: CD3- 301APB1 - CD3- 301APB1 RigSu 2,770.46 836.16 770.46 787.53 2,875.00 17.195 Clearance Factor Pass - Major Risk CD3 -301 - Rig: CD3- 301APB1 - CD3- 301APB1wp07 2,770.20 1 835.84 2,770.20 787.22 2,875.00 17.191 Clearance Factor Pass - Major Risk MEND CD3 -303 - CD3 -303 - CD3 -303 2,780.36 1,381.32 2,780.36 1,328.57 3,350.00 26.187 Clearance Factor Pass - Major Risk Plan: CD3 -198 - Plan: CD3-198 - CD3- 198wp01 7263,17; ,316 17,263!17' 172.34 7,025.00 2.195r Centro Distance Pass - Major Risk Plan: CD3 -198 4 Plan: CD3 -198 - CD3- 198wp01 1,530.32P 322.05 7,530.32 165.59 7,300,00; 2.058 Clearance Factor Paso - Major Risk Plan: CD3 -199 - Plan: CD3 -199 - CD3- 199wp01 5,580,39 275.79 5,580.39 147.87, 5,375.001 2.156 Clearance Factor Pass Major Risk: 15 March, 2010 - 13.51 Page 2 of 5 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURTDN Western North Slope Anticollision Report for CD3 -302 - CD3- 302Awp14 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad - CD3 -302 - Plan: CD3 -302A - CD3- 302Awp14 Scan Range: 2,770.20 to 12,523.27 ft. Measured Depth. Scan Radius is 1,449.53 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft WNS Non -Pad Fiord 5 - FIORD 5 - Fiord 5 12,519.33 1,372.53 12,519.33 1,169.66 6,850.00 6.766 Clearance Factor Pass - Major Risk • Survey tool program t From To Survey /Plan Survey Tool (ft) (ft) 70.50 248.50 CB- GYRO -SS 249.00 2,631.33 MWD +IFR -AK- CAZ -SC 2,706.20 2,770.20 MWD +IFR -AK- CAZ -SC 2,770.20 12,523.27 CD3- 302Awp14 „ MWD +IFR -AK- CAZ -SC >a 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. All station coordinates were calculated using the Minimum Curvature method. 11 p p an) • • Clearance Factor = Distance Between Profiles /Distance Between Profiles + Ellipse Sep 15 March, 2010 - 13:51 Page 3 of 5 COMPASS 4-on7,-,.13-; • • N N 01 O • N N N N O N 10 L C7 L O t0 O h M N N N N O N -' Cl N c '1 c'1 f0 O N N N N - _- .._....- _.._ r V' d• d• C d• d• `` .' . V n- N N N 1s- N & T V' CO cD O N A I p ' p 3 I _ U O V' V 7 O V' V �� O h N N N N 1 Ci U h W V' 0 cD 01 % ��'1,9` N V - 7 V' W d• d• 7 V' O p �� i '' `1m)., O ,_ 111 N h V' ::I' N N 1� co .C� ® J.� /�� \� in N N f`1 1{) t0 h c I -- , Igifilrff-gliv5w7211,1 s, 5 , , ,0 r P a. 7 1,ri 6 N I� V N N N ../ cc V . 1 . d CO d .7 cr "Itgal 0 4 'O 4 s o 7 N ..1- 1---"7. ' (0 1 4 11W ie, ' - - - - f$.) 4 N ■ a 9 O M N � V rn , d- W 7 0 N V I- 61 CN<I ° o cq H `� Y�Y N N -U- MI d lY O O) U W t CD ■ U C 2 I off, fr ' W „ , , o N ° N ■ (O o o vsf 109$0404/400/00 �o ► ++ ►1 + +�►►�i� r N O r te ; •�-`.."._ -� ``a�..� „ r 0 1 1 11 L 0 d � ti 3 ipi g � w Cr) — � kr S lit: 4 4 t, _ o m J O e � / ma y p p a �° . / //1/ /i1d i Iiiiik N M i M Q .OF a /•Ii ♦P w'''' 'I� j::, OD _i IMF/ ii6i l '� , • �j ' // %: 0 - - - -- ._ $ t r , .e Vi p - ;. - µr- D .... a ' 4, 414 , 440/1/1 ' .*s °ik s� � .,y / , mo o 3 O aR f O ` a T M . / !® 4 r f , N , N N 0 4Ir O F• ° o ° d. ° M . 0 It 0 N O M c , 0 h G LILI) NI lH U ❑ -1‘...7•Ii k..) Northing (3000 ft/in) . i . i i i , . ill,[iilltiiiiiii i iiiiili, li(ii I 1,1,1 iiiiIiiiiIIIIIIII[illiiilirillm 0 - o ..1 o _ _ . o ...e."‘ Z i - % - a) 0 = - Ow-. o 9% =_ .- _, a , „._, _ - _mu _, --. - -11 z1 - 4, (.., V') - - o0 - _ -1 _ a) CD - 71. - a) u) a _ 0 - - -0m _ (DP_ c..) - z _, _, - (r) 0 0 1- c,) - _ 0 _ , _, 0 o _ 0 - V ° - __. 2-1C. CO) OT c.) N • I ii. _............ m , . co — - ( e 3 > o co **°"*••., co • 5' - 11\ o o - 5 - to co - -o co - co o — o • 5 - m to 0. 5 0 ..... _ - - A — ___-- 0 0 W _ _ (0 co o - -0 - L.) - - _ ..._ 0) co * _ - 0, o o O o 0) 0) .c. s - _ - 01 E — _ si) — ._ a - - z. 0 0 0 - 0) N - 0) Et - - .i. r 1 1 1 i [ 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 [ 1 1 1 1 1 1 1 1 1 1 1 1 1 1 [ I 1 1 1 I 1 1 1 i 1 1 1 1 1 1 1 1 1 1 i 1 1 1 [ 1 1 1 1 1 1 (u!/).1 000£) Bu!L11- 0 410 0 • HALLIBURTON Conoco Phillips CD3- 302Awp 14 . Alaska Sperry riding ANTI - COLLISION SETTINGS 13:53, March 152010 Interpolation Method: MD, interval: 25.00 Major Risk Depth Range From: 2770.20 To 12523.27 Results Limited By: Centre Distance: 1449.53 GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey /Plan Tool 70.50 248.50 CD3- 302PB1 gyro (CD3- 302PB1) CB- GYRO -SS 249.00 2631.33 CD3-302PB1 (CD3-302PB1) MWD +IFR- AK- CAZ -SC 2706.20 2770.20 CD3-302 SDS (CD3-302) MWD +IFR- AK- CAZ -SC CASING DETAILS TVD MD Name Size 2 495.75 2669.75 9 5/8" x 12 1/4" 9 -5/8 6870.82 12523. 7" x 8 -3/4" 7 2 5. 5. N 4 o i. 8 v ilii ulliiV i t �' i i i 1 , / o0 60 E. r U 030- C U cu - - -... -- - - - - -- 1 '' ... - -/ 1 �- _... � ' 3000 0 I 1 I 1 t I . '... 1 f I I I 1 I I I I I 2800 3200 3400 3600 3800 4000 Measured Depth LEGEND - CD3 -302, CD3- 302PB3, CD3 -30 PPB3 V2 X CD3 -107, CD3- 107L1, CD3 -107L1 VO -e- CD3 -305, CD3-305, CD3 -305 VO - CD3 -302, CD3 -302, CD3 -302 V3 A CD 3 -107, CD3 -307, CD3 -307 V4 X CD3 -305, CD3�O5PB1, CD3- 305PB1 VO - 9- CD3 -302, CD3- 302PB1, CD3- 302PB1 V71- CD3 -107, CD3 -107, CD3 -107 V7 0 CD3 -106, CD3 -106, CD3 -106 VO -9- CD3 -302, CD3- 302PB2, CD3- 302PB2 V6 -9- CD3 -303, CD3 -303, CD3 -303 VO , CD3 -106, CD3- 106L1, CD3 -106L1 VO CD3 -109, CD3-109, CD3 -109 V5 -e - CD3 -304, CO3-304, CD3 -304 VO -El- CD3 -301, Plan: CD3 - CD3- 301Awp07 VO -00- CD3 -111, CD3-111L1, CD3 -111 L1 V7 Plan: CD3 -198, Plan: CD3 -198, CD3- 108w001 VO - CD3 -301, Rig: CD3 30 1APB1, CD3 301APB1 RigSurveys VO -A- CD3 -111, CD3 -111, CD3 -111 V7 ---X-- CD3 -301, DD3a01P81, CD3 -301 PB1 V1 --A- CD3 -301, Rig: CD3- 301APB1, CD3J01APB1wp07 VO - - CD3 -112, CD3 -112, CD3 -112 V3 CD3 -301, CD3 -301, CD3 -301 V4 -X- Fiord 5, FIORD 5, Fob 5 Vt 0 CD3 -110, CD3 -110, CD3 -110 V12 -I- Plan: CD3 -199, Plan: CD3 -199, CD3- 199wp01 VO $- CD3- 302Awp14 O CD3 -113, CD3 -113, CD3 -113 V6 -9- CD3 -106, CD3.106, CD3- 106wp10 VO o CD3 -108, CD3 -108, CD3 -108 V1 -e- CD3 -106 CD3- 106L1, CD3- 106L1wp11 VO O RIG1NAL N N 0 ® N N N O N „, [ C • i f o O as 7 7 V • W O u FE N M M N tl' N N N • 7,3 CO ,, N Y +� V N N N N pK _ ,,,-, ,,,, V m aG N N N it) L7 M y si c v a v v v v �� I v rn v N m ,o-, ��V 6 o , V ✓ v rn v v v v N �� N N N h N Nth7�t0 � '� /, a v a rn c v v � � r N r V N N N , - -„ N N M V (O O O V rn 7 rn N M N .p N V T O O G co N 7 V 01 7 01 N V ti m O H O 1 O f0 N N O O O U C N O N O 0 O O O O O O O O 1) ,s9 M 3 w L :,_c ._ _ O J wOj N / /,�� N M a /% °m Lu J 0 0 M ._ M N O O c c M L O Tr d O r Q. Q O N CI F t0 N C p N M N OR J eThj G1 N V 01 N N N N C • • N N N N O N If) C U O �4 cq R m a 7 .7) O N N N 0) O N N :7 R V h N N N ! � 4., cn r '- N p, N O 0 aD O G _ U 0 v v a v v v v y ' __ _ 12 v rn v v v O /// f '� \ \ � _ W N 7 N N N 71_' O N / � � �/� '1 �'..��\ In co N f"1 t0 1. Iv, ,ilir, O c' "Ft" / 9 v# 7 1 , I °II I... N N M V K ( N O fe • z! ~l•, N O1 �► _ ` ;� �►/ m a p ea M M a u O N o O N Cr M ; 7 rn C o) V' rn f0 ' m ■ N N U CI P o O 1:1- O c� p O) Si G 0 m c 0 U O) N a-' O o N O O O O O O O_ O O O IA N M c __ 3 7 /hr, r J OIIp `-4i mik. ._ 0 GO cu co ._ M : / Lllva N M .... V w o � �I / � j i 414.111.%11111111111120#A101. , ` , , n 1 I /i lk C7 �� ` � 4.1, o VA Y 11 CO V p ., S '�� C ° b'4 o v a Q M ....44„ N d 1 ch 0 t0 N N xi co N O N cn a A 6. 0 h r. y N N 01 O N CO N N O N .,,, ;: ‘0, ...,,, up r q t-.) O O) as v v v '...T) O N N 2 :1 csi 01 o cg N co tC) N N N N C con N r V O V 7 7 7 E V N N N r- N - gyp, 9. N V f0 ca N N ! 1 C O - N ^ N N N N B U h W t0 CO 01 V y O E- v v rn v v v v '° N f� V N N N r M ` Il- N N M V-- h _ � c O N d 8 e '.4.04 a 'am v v .4 I� N N N N N M V In (O - [ v T.; a - -- __ _ cV N v rn 'O 6 o Lo 6' eu .9 o o > v rn v rn v a' M N N 7 h m N 7 0 0 F C N 0 I IIIVIIIII , 0 o I II ) IIII�II I' '1 y N 0 'IT' m TI h o 0 0 0 0 o La 0 + l d l l l II o I I I I I C N M I'�I V II L II I� C CO ' III:II:111k : 2 V N L f0 0 N 3 Q _ O ._ w o Alk _ o °m a g o o d M M c.,...... Q O O co ce J 0 1 9 . r o O Q N o F 0 F- co °� N ts, M O N O O T r 0 . ORI1NL N N N up ir . O N N N N N [ O i O tl� 0) 0 u m N N N N O N - .- N M M f0 _. _.... .__. 0 q 1- N N N N O N V ‘,8,1 • N •- V co N C CO ^ N k. 0I N N M U 0 U N*g N N N ti \ ti t0 CO 0) V v O O 2 - 7 7 rn 7 7 7 7 O p N h V N N N h CO N N O] V ul CO h M ' yyu, V � i, � , IF ▪ N h V N N N • N N M e} LL) CO ^�,. O O 1 v C7) v ' C; c v N V O M O C.) �� OD a C o > 7 0, v o v co CO N N V' N- m N 7 o 0 F ' O 0 N N 0) O 0 C N o- O O �N IWII O IIII I I III o p o o 0 N M LO C L 3 L Q 0_ - TD - •C 0 J O O 0 0_ CO M N H N M d O CC O CO W J 1 J Q m 7 7 ---4*---- 2 / ' 1 ' 4e4 S . 0,4;10 0 -,;( " //I I a F;, ■x ray 2. °o 41 c53 44 N O a ~ N Q9 a N r O CI O 0 0 ORIGIN L 0 Lri N N 0) Ti; p e e N CO M ▪ N N N N C3 N j in r U I O a es E a c o rn o M M O N N CO N N N N fD _.__ -._ - -.._ O N � �V� ci1 1 r" 7 N N N g N 0) V CO CO W N N O 2 O N N N N C) U i• co v co co rn 6 U c o > n a rn v V a v 1p 1 ° W ° -� W N 171: M 7 1 C00 n Cry L C O O 1 + E " NdVNNN N N M a 10 t0 E M t N v CT, N ,- ,- M / _— —_- / ! N 5 M - _. - -. -_ _- 0 i o _ o .� O v O N V' - 0)) N 7 " 0 N f - s- .- o O 1D N N O c) o) 0 m "al O ✓ j N f D / I O 1 O o / Ax. O N O LL) c L 3 L t0 d 3 Q w _ 0 0 J O _ _ O O d O N M a c. o a m o w L CO O 0 0 0 o r ,/ ,--,.... M co N .. Trc, ,... ti ,) /// . Ao Q F c9Q n N 0 ° 0 R1 0 14\J A L r O s V _, C 0 N N ‘C7); O N N N N O N in 1 0 el r C 1.7 0 t5 v v v rn m N G N N N N f a N O �' g N N N h N _ I m O T I' M W A CJ O d G a 7 7 7 7 a 7 U h N N N N h .--•-.' sT (0 aD 0I U v O > o N W N N M tN c min 0 CO u 1 O o t v v v m v v ' N 1-- a N N N C N N M V Lf f0 F c+) N v c. •- •- cn - A o eu 0 0 o v > O N v V a N a co O O E. O CSI N O rn 0 0 C N ' o � �� r��" Ht 11 it i rl /� ` 1 � o sf ! m o \ a J o \---„,,,,., \', max ,RS ` -,'�*. r+'-r. .i "�' 3 tl . w L R O_ N Q w .. 0 0 o ( 0 0 f+ N — '- N M O d M 0 Q c0 ce O W H J J Q m o J O r) N co o O O O o r O r Q CO c°n N N F N O M O ORIGIN N AL ,.. N N CT) d- • • . ® N N N O N ` , L 1 .. O r r r 'd sct, N c M O N N N N N N CO _ .._ -.._- ,- 8 O Y ,' N ,- N NN h N N r V CO DD CA f B"cl CA N : K _ , -- C/1 { N fIi _\ � CC 3 1 .. d • 0 o .crJ --4- O N- N h N N N h U N- m 7 d m m rn U 0 O ° a v rn v v a c o ■ p O N c ' V N N c ii c LL N N M d' 10 m r cn o o '--' O C co I t � 4 N l•-• a N N N E N -6 N ti O 04 . M �' N b O ,�. - -.. O A c? A , b O O O o N 0 N a N rn N d p E- (00 N O 0 N 9) , le N C N d O Z co O o F I(I \ I t X1111 o - � a MI I I II ` :`, CO L = - N L ! C1 U Q a W o o 0 oar o d C M N O ,- N M d M Q o cc O o W _I LL J Q m O J 0 O m. M CI N O o M _ CQ O d 0 O. § Q O N O c ° C M p l N M C o I o rn ca 0 co o e 74 ; 0) e 0 ' N N 0) 'or cz N CO Ca) .0 ,— NNNN 0 C•1 It) 1 I i es, .?. N N N Cif CO - cri cv csi ev cv _ . cv .d ., , q , cr cr •cr v at 'al 8 *'1 N N CV fa. N ,,../ '', ' ...... ' - C a — •cr CO CO a, ,..; ,,., ...,....- -- -- , i , U 2. i i _''.f! -.4. ..4- 01- .4- 0,- aar •at ' , ../ , .., C.) 0 N- 0) .— •7 CD co a, , 7 , • F, ' a) o ' .4- .4- .4- ..:1- o , . In ..._ N N.. act N N CV N. CO Lo u 01 N CI V 10 CO Na. 01 0 0 , I , , 8 t --.... . / , „ a N N VI V' LO CO --. ' 0 - . . ... -" V) - \ - . --... • E N •ct ta- Of a— a— a— .... • _ _. ' , 0 7, g (..) .§°. T,' Et: .., 0 9) - , 0 0 8 A._ 2 -- -- . _ o a. o 2 c0 . `c o o o ff 7._ o o .- O L0 c9 co . - '.' ... .§- 0_ TD 3 0 al < --- v- LL E- -J _1 < co 0 o o c• csi cn ..- -... o o Lo 0 0 1 4' 0 v- 0 a. In c N o o ,r c CE 1- co --- ...._ (s1 0 o o o cs, 0 1.•■ o I, .- cv CI i n , i ' ‘'' ' . ' L ORIGt' .,-.: (..,© �� 0 N N m 7 p N M c') V N N N N O 0. N 1f) T a 0 r r r O N N N 6f O N ?,36) N St' N N N N CO - - -_ i-ill.,,,i1,,,..i. . q r V a 7 a a 7 N N N W 7 W d , 1 u) M d O O U N N r N N N 1 h W (O OJ ■ C 0 O _ a a v rn v v v v o o co W N N M 1p m A n —, CO M O CO a a v rn v v v [ N h N N N N N c'I in co 5 r s, IF' . N rn M N a .E O O ,... M o U P c 0 0 o v C M N N a n rn a 1.9 c H C N N N O - - '4' E m o 1111 I co 0 o 0 o_ o o o O o in N CO C L .- §x , m L (Q Q d 3 0 J O O — O 0 d CO M N M Q W O O O J LL J Q 0 In J O M M N h N 17 C1 r N N r N o oRIGMA M ,_ m r oN C ! C N r g o 0 O N O � rc CO 03 12 ID. Lee gs� A SS 44 O W� 1 Co I r 22 8 a1 I-- 1 ... 3 N ,, `^ O O O Vi .£�@ O O a F Q s CD3 = RRB! O et B o a 6 O W b o a m m� i ` y .... to l S ao €o O i co °m f f O P , 3 c j °� 'i cD o ' � OJ �n p ti ��11 to ' �� 5 � 9 au €�S Q Qy O ' fw C t3 Q 3p'L 0 � C 04 11 l ir p`bQ O + d O 0,0" I' 5 P !d 7 ' \ - — — F — ' ., "*I‘s, ' Co3 3 y1 P .. \ �_ 0 Igo- I r Iii .r \\I 411 O t1 � NI 1 � I ca � =� i � al <CI co a .�I i'i O mow:: CZ l'i id .1 ,ti.b!:::. .14 o i ,- ��' N Cr) —L. M �' � Ncpr i Ak iiIii ... D 0 O . A. O C. I , o v ��' O ;V I i vs C:) O O O O 0 A to O O O 0 O to 0 O 0 O 0 0 co CO N Li (u!/ OOOZ) ( + )u ]Jo Ni( -)uin0s G 1 N Opwdw: CprwcoPNDp66* k66 Fc. -WNS GgCOSrctlon: -0216 ° bb No 28114 Re14: WestwnNwtO Sbpe BMy1WFDCFdbn: 2126 ° AR No: 1N/A 6661: CO3-302A2p14 Dip: 8028 ° APINO: tN /A 8 4 86 44 Dodegper 100 ft System(IVO) Reference: 8.6658616ae1 Surface local. Origind VS Plane: 30.00 ° Parent Wei 006-302 A: 152837628 ft View VS Plane: 30.00 ° RKB lkkfl: 4120 8 V 600361622 ft Unt System: 4210,6661!e3 Bectbn NS) Relwerrce: S44 Comments: POOL: n View 8 8 8 8 _g 8 P$a CD3-302Awp14 Plan: 6650' to 6760' TVDss 6014600 CD3 -302: 8542' to 11708' MD CD3 -301: 12061' to 15140' MD Fiord 5: 6650' to 6760' TVDss 6013600 i n ` �` - — -- • 6 012600 • � _ ll iA I I�IG 4 a .�. A r�P� R � Z AIHi I p II III �M ��q) %J, , — 6011600 i SectionViewl CD3 -3D2Awp14Plan — CD3 -302 — CD3 -301 — Fiord 5 I I I I III - %: *' - i `I IIII a a 11 II 6010600 - - 1 liio i ‘ II � J1[ s hl v l illl I �, I I t } I .cy, �„.. + � -- a B - - , — 6009600 II' I Iu ■ P tll I s L I 6008600 A 1„ ' l i i l ll l� III VI East( -1) /West(-) > X74 , 114rt ill 2 1 "hl lfl ^ _ — 6300 1 c u. _ _ - 7300 Fid Vert loci Section dong'Vlew VS Plane' Combo Preview Page 1 of 1 (CD3- 302Awp14 Toolbox3ds) 3/15/2010 4:34 PM Closest in POOL Closest Approach: Reference Well CD3- 302Awp14 Plan Offset Well Fiord 5 - Coords. - Coords. - ASP ASP 3 -D ctr-ctr Meas. Incl. TRUE Subsea N( +) /S( -) View VS Meas. Incl. TRUE Subsea N( +) /S( -) View VS Distance. 111 1, „ ,v: Depth Angle Azi. TVD E( +) /W(- (30) Comments Depth Angle Azi. TVD E( +) /W(- (30) Comments PUUL Min POOL Min Distance (1382.62 • Distance (1382.62 ft) in POOL (6650 - ft) in POOL (6650 6760 TVDss) to 6760 TVDss) to CD3- 302Awp14 Fiord 5 (6650 - - Plan (6650 - 6760 • ':1382.6 _'9' -(I. 12342.92 66.58 26.71 6758.21 6011584 1533113 9268.83 6760 TVDss) 6906.55 1.17 152.87 6781.73 6012399 1531996 643.69 TVDss) 4 Closest Approach: Reference Well: CD3- 302Awp14 Plan O set Well: CD3 -302 Coords. - Coords. - ASP ASP 3 -D ctr -ctr t 'd �., Meas. Incl. TRUE Subsea N( +) /S( -) View VS Meas. Incl. TRUE Subsea N( +) /S( -) View VS Distance. i , 1 I II1 u:IF Depth Angle Azi. TVD E( +) /W(- (30) Comments Depth Angle Azi. TVD E( +) /W(- (30) Comments POOL min r Distance (2089.58 '+ Distance (2089.56 ft) in POOL (6650 - ft) in POOL (6650 - 6760 TV 6760 TVDss) to s) to ! CD3- 302Awp14 CD3 -302 (8542 - - Plan (8542 - 11708 2089.6 12071.37 66.58 26.71 6650.274 6011363 1532998 9020.084 11708 MD) 11708 90.82 80.57 6750.173 6009331 1532519 7030.645 MD) lr Closest Approach: Reference Well CD3- 302Awp14 Plan Offset Well CD3 - 301 Coords. - Coords. - ASP ASP 3 -D ctr -ctr d :d Meas. Incl. TRUE Subsea N( +) /SO View VS Meas. Incl. TRUE Subsea N( +) /S( -) View VS Distance. r Depth Angle Azi. TVD E( +)/W(- (30) Comments Depth Angle Azi. TVD E( + ) /W (30) Comments • POOL Min Distance (2623.33 Distance (2623.33 ft) in POOL (6650 - ft) in POOL (6650 - 6760 TVDss) to 6760 TVDss) to CD3- 302Awp14 CD3 -301 (12061 - Plan (12061 - 1514C 2623.3 , 12342.92 66.58 26.71 6758.21 6011584 1533113 9268.83 15140 MD) 14644.34 93.63 61.07 6745.81 6013896 1531874 10604.49 MD) PoolSummaryl 3/15/2010 4:52 PM • 0 1 REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 5 4/8/07 AG DB C.A. UPDATED PER K07041ACS 6 4/13/09 AG DB C.A. UPDATED PER K090003ACS N U 1 / ? R J----' 1 7 , �f��tLLSI' !Dr 1 q -.;k A . r e 0' i 00 cD3 v- i ill -is ri :- .... i .11 111 , j7 1,-,' , , \—, r 'j 7\ LOCATION OF THIS SURVEY � . , � P - T M r ALPINE SATELLITE DEVELOPMENT "!�- ,' / <' f T11N ft `� VICINITY VAP NOT TO SCALE III 10, \ F p AD 0 0E9G4 SH OUT OER CD-3 PAD m o$, S roo a n% Ck (u1 .nv� i eO,'Iss0 : tliQQ0O •Pf N N i[ x \ to N1 Yf O O o 1, 0 • * - - � E1M 20 i �� "wo •- — Viko° R � �� aOUCE irojal • PIGGIN SKI : �• 0 000-E W ARE ousE PLANT 101.11RGENCY ASPC E O uA TER N 13'00' 00" - �, i w fl LCIAF LEGEND: ed O PROPOSED CONDUCTOR o z z O C7 � N N • EXISTING CONDUCTOR ° jy 1- 1- 'F v n l '" . "-. 0 Q N Lri v KUUKPIK U U fr W W VI LJ ;„ 1 L C M F � 1seee1rAv.. • NMry.MWI99eO] zre -1aao Npine 011lce ( 991 ) 61oJ)19 Alpine Survey Office `V ALPINE MODULE:CD30 UNIT: CD Conoc.Phillips ALPINE PROJECT CD -3 WELL CONDUCTORS Alaska, Inc. AS —BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05- 03 -03 -1A 11/3/05 CE -CD30 111 1 OF 3 6 • • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 6 4/8/07 AG DB C.A. ISSUED PER K07041ACS 7 4/13/09 AG DB C.A. UPDATED PER K090003ACS ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.5, T 12 N, R 5 E, U.M. SEC.LINE 0/S EXIST � WELL 'Y' 'X' LAT.(N) LONG.(W) FSL FEL GND PAD CO3 -X98 6,003,630.37 1.528.434.35 70' 25' 09 °267" 150' 54' 44.278" 1392' 642' 7.3 12.5 CO3 -X99 6,003,625.99 1,528,415.38 70' 25" 09.221" 150' 54' 44.833" 1387' 661' 7.3 12.8 003 -301 6,003,621.33 1,528,395.58 70' 25' 09.172" 150' 54' 45.411" 1382' 680' 7.3 13.5 CD3 -302 6,003,616.72 1 528,376.38 70' 25' 09.124" 150' 54'. 45.972 ,t 1377' 700' 7.3 13.2J ■ 003 -303 6,003,612.52 1,528,356.72 ' 70' 25' 09.080" 150° ' 46.547-373' 719' . /.3 f . CO3 -304 6,003,607.82 1 528337.04 71• 25' 09.031" 150° 54' 47.1. -" .8' -4 739' 7.3 13.4 003 -305 6 °003,603.48 1,528,317.56 70' 25' 08.985" 150° 54' 47.69T 758' 7.3 13.6 CO3 -106 6,003.599.43 1.528.298.37 70' 25' 08.942" 150° 54' 48.252" 1359 777' 7.3 13.4 003 -107 6,003,594.38 1,528,278.93 70' 25' 08.890" 150° 54'! 48.820" 1354' 797' 7.3 13.2 003 -108 6,003.589.85 1.528.259.61 70' 25' 08.842" 150° 54' 49.385" 1349' 816' 7.3 13.1 CD3 -109 6,003,585.27 1,528,239.85 70' 25 08.794" 150' 54' 49.962'' 1344' 836' 7.3 13.1 003 -110 6,003,580.97 1,528,220.32 70° 25 08.749" 150 54' 50.533" 1339' 855' 7.3 13.0 CD3 -111 6,003,576.13 1,528,201.08 70' 25' 08.699" 150 54' 51.095" 1334' 874' 7.3 12.9 003 -112 6,003,572.43 1,528,181.20 70' 25' 08.660" 150° 54' 51.676" 1330' 894' 7.3 13.1 003 -113 6,003,567.62 1,528,161.38 70' 25 08609" 150° 54' 52.255" 1325' 914' 7.3 13.1 CD3 -114 6,003,563.04 1,528,142.21 70' 25 61" 150° 54' 52.815" 1320' 933' 7.3 13.3 CO3 -115 6,003,558.57 1,528,122.60 70' 2E 08.515" 150'454' 53.388" 1315' 953' 7.3 13.2 003 -116 6,003,554.04 1,528,103.39 70' = 151 ' 54' 53.950" 1311' 972' 7.3 13 2 003 -117 6,003,549.51 1,528,083.99 70 P . '' 420" 150' 54' 54.516" 1306' 991' 7.3 13.1 CD3 -X18 6,003,544.88 1,528,064.44 70' =1y1 °72" 150' 54' 55.086" 1301' 1011' 7.3 12.8 CD3 -X19 6.003.54 1,528 0 74 2 :_ .-322° 150' 54' 55.6 1296' 1030' 7.3 12.8 CD3 -X20 6,003.535.95 1.528,025:39 70 150° 54' 56.229" 1291' 1050' 7.3 12.6 CD3 -X21 6,003.531.41 1.528,006..04 70' 25' 08.230" 150' 54' 56.794" 1786' 1069' 7.3 12.5 CD3 -X22 6,003,527.00 1,527,986.67 70' 25 08.184" 150' 54' 57.360" 1282' 1088' 7.3 12.6 0D3 -X23 6.003.522.43 1,527,967.12 70' 25' 08.136" 150' 54' 57.932" 1277' 1108' 7.3 12.6 CD3 -X24 6 °003,518.17 1.527,947.59, r 70' 25' 08.091" 150° 54' 58.502" 1777' 1127' 7.3 12.5 NOTES: 1. COORDINATES SHOWN HEREON ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL (B.P.M.S.L.) IIP/ ALPINE MODULE:CD30 UNIT: CD C.noc.Ph;II. ALPINE PROJECT 1 " CD -3 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05- 03- 03 -1A -2 3 -17 -05 CE -CD30 - 111 2 of 3 7 0 g 1 G 1-A . 1 N ' 1 • • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 4 4/8/07 AG DB C.A. ISSUED PER K07041ACS 5 4/13/09 AG DB C.A. UPDATED PER K090003ACS NOTES: 1. ALL COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS WERE DERIVED FROM THE AVERAGE ELEVATION ALONG THE TOE OF THE CD -3 GRAVEL PAD. 3. BASIS OF COORDINATES: ALPINE PERMANENT CONTROL MONUMENTS PER SURVEY BY KUUKPIK /LCMF, MARCH 2005 4. DATES OF AS -BUILT SURVEYS: WELL CONDUCTORS CD3 -108, CD3 -109, CD3 -110, CD3 -111, 3/16/05, FB 2005 -08 PGS 52 -53; CD3 -301, CD3 -302, 3/19/05, FB 2005 -09 PGS. 24 -25; CD3 -304, 4/16/05, FB 2005 -12 PGS 35 -37. CD3 -303 2/10/06, FB 2006 -03 PG 11. CD3 -112, 2/23/06, FB 2006 -05 PGS 29 -31. CD3 -107, 3/26/06, FB 2006 -09, PGS.9,25 ; 7 IF CD3 -305, CD3 -106, CD3 -113, CD3 -114, CD3 -115, CD3 -116, CD3 -117, 5/2/06, FB 2006 -11 PGS 57 -61; CD3 -X18, 4/7/07, FB 2007 -07 PG. 67; CD3 -X98, CDX -99, CD3 -X19, CD3 -X20, CD3 -X21, CD3 -X22, CD3 -X23, CD3 -X24, 4/13/09, FB 20' GS. 70 -72. 4 Ii,4, h' I i v 19'11 , 1 l + - OR'S CERTIFICATE .46��.�,, , - HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED - . � 4 lit., � �. AS -BUILT PRACTICE REPRESENTS S MADE B OR�UNDER MY DIRECT • � °;• ••• �� SUPER THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST i � I � *t AS DESCRIBED, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE it : * ' � 49th �\ * � * CORRECT. ° • DATE: REGISTRATION NO. LS -5077 • I/ • /3 Donald G. Bruce o l •.� '• No. LS -5077 • �J``A �� ` �� F a °•• ................. • • ' ' o `� . ∎ • K U U K P I K •♦ I ARO FE.SSIOHM- \..P 4 4 • ' E LCMF � • ..I I. 139 GAatAV.. • Mdla.9., M 39903 (90 72 79.1S10 - _. 61717 OMCe (909)690 -1736 Alpine Survey Office V ALPINE MODULE: CD30 UNIT: CD C.noc.Phillips ALPINE PROJECT CD -3 WELL CONDUCTORS Alaska, Inc. AS -BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05- 03- 03 -1A -3 3 -17 -05 CE -CD30 - 111 3 OF 3 5 Q Page 1 of 2 • • Schwartz, Guy L (DOA) From: Winfree, Michael Alex (Jr.) [Michael.A.Winfree @conocophillips.com] Sent: Thursday, March 25, 2010 2:38 PM To: Schwartz, Guy L (DOA) Subject: RE: CD3 -302A (PTD 210 -035) Guy, 1. We will pressure up under the TWC to ensure it is functioning correctly. 2. If the Qannik (K -2) proves to be a significant hydrocarbon bearing zone, a stage tool will be run to isolate the interval. The Qannik depth prognosis at CD3 -302A is 5,540' MD (4,095' TVD). The stage tool would be placed -500 feet below the base of the K -2 and cement would be pumped to cover 500' above the interval. a. Volumes are based on 40% excess: 0.1503 ft3 /ft x (6,100' - 5,000') x 1.4 (40% excess) = 232 ft3 232 ft3/1.16 ft3 /sk = 200 sks of 15.8 ppg Class G Cement with Additives. 3. The CD3 -107 well is within the 1/4 mile area of review for service wells, however, the distance between the CD3 -302A and CD3 -107 Kuparuk cut points is 5,512'. In addition, the Kuparuk reservoir targeted by CD3 - 302A and the Nechelik reservoir targeted by the CD3 -107 is separated by - 300 feet TVD in this area and the top of cement for the CD3 -107 intermediate string was brought up > 500' above the Kuparuk interval. For these reasons, fluids should not be able to escape from the receiving zone. Please let me know if you need additional information. Thank you, Mike A. Winfree 907 265.6820 From: Schwartz, Guy L (DOA) [mailto:guy.schwa @alaska.gov] Sent: Wednesday, March 24, 2010 10:27 AM To: Winfree, Michael Alex (Jr.) Subject: CD3 -302A (PTD 210 -035) Mike, Had a couple of questions for you on CD3 -302A. 1) Are you planning on trying to do a "rolling " pressure test on the TWC from below in step 3 ? ? ?? The cement plug is not holding but would at least let you know if is functioning correctly. 2) Can you send me some details on the possible 2 stage cement job for the Qannik. 3) A couple of sentences regarding the AOR for new injectors. Looks like the CD3 -107 is with 1/4 mile but the laterals should be below the kupurak strata. That is the only well of concern I can see. I attached the AOR guidelines... Thanks in advance, Guy Schwartz Senior Petroleum Engineer 3/30/2010 Page 2 of 2 • • II AOGCC 793 -1226 (office) 444 -3433 (cell) 3/30/2010 ConocoPhillips Alaska, Inc. Post Office Box 100360 • Anchorage, Alaska 99510 -0360 ConocoPhillips Telephone 907 - 276 -1215 March 22, 2010 RECEIVED Alaska Oil and Gas Conservation Commission MAR 2 3 2010 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Oil & Gas COts.0 Re: Application for Permit to Drill CD3 -302A Dear Commissioner Seamount, ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore slant injection well from the Fiord CD3 drilling pad. The intended spud date for this well is 4/6/10. It is intended that Doyon Rig 141 be used to drill the well. CD3 -302A is intended to be an injection well to support the CD3 -301A horizontal Kuparuk C sand producer. 7" casing will be set in the Kuparuk C sand, and the well will be completed as a pre - produced v injector, perforated and flowed back to mitigate reservoir damage. It is not expected that the K2 (Qannik) sand will be considered a significant hydrocarbon bearing zone, but a stage tool will be run to cement off the Qannik with 500' of cement above and below the interval if logs indicate that the Qannik is a significant hydrocarbon bearing zone. ConocoPhillips also requests permission to defer the testing of the lower rams until after the tubing is - — pulled and a test plug can be run. All other BOPE will be tested prior to pulling the tubing hanger. There is interference between the crossover for the blanking plug and the lower rams that prevent testing the lower rams. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10 -401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. A proposed drilling program 3. A drilling fluids program summary. 4. Proposed completion diagram 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). • • Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Mike Winfree at 265- 6820. Sincerely Mike A. Winfree Drilling Engineer Attachments cc: CD3 -301A Well File / Sharon Allsup Drake ATO 1530 Mark Chambers ATO 1566 Scott Lowry ATO 1504 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation • • TRANSMITTAL LETTER CHECKLIST WELL NAME cv�� (r(: PTD# 2 / ( : c..>_ , Development /Service Exploratory Stratigraphic Test P P rY Non - Conventional Well ry / I FIELD: C7" r 7l ti 1� l t �' POOL: �Pf 7'"cJ Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(0, 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 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name 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 Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 • 1 ❑❑ N 0 a) 0- a i ' N co L I l i E N C O Q ui � O ' �, �, � CO' 0 c � 1 M, 00 J, L C 0, w , O , C' 3 �� L� 0) W1 cats o I 4 (p o , a . I c a o, o o o p 4 m. n o c 2 0 ? N v n c . a L' N N a) E ui ° o a. L i n rn 3 0 o c o. a). L' Y o 3 co ao 3. S O o ar ° N. = 0 1 Q U ` t u) a -`o Y 13 , v T (0 'O _ O 2, to 0 E M m Li) o a a °OC; a �, E �, I' ' M1 a o a a) m m a o- L u' as, m g 0 Ci l 0 o o. a) 0 0 c . ; CO m a o c , a) � t , o 0 � , N C, C C a y N U) O' 0 N , 1 N a p C o, o O m. o M, v Ln, LL.I ' 3 C co co C 3 O, o 0 N N CO C i , 1 O . J, V, L N 0 O, - N, Cl a ) , N, cp RI wl O ( °) o c m > o' M Q a Z a 0 co 11 - 0 , « • O, m, N, I ( J M, cc , I.0 LO It), L U N� � 0 N o . N N . � '� O n, y, 000: TD', 1 o . ) , (( J J, ' p, O O O 3 c ' Lr c ) M, U o , C o, (0, M, a), , o 3, N, N Q ' Z Z , Li Z w T U w � , n N o a c N , 3, Z • 4 I o c° 0 N ' Lu •� •0 T T � � -)� n c � ct) 0 -0 al c .f N' _co, N � - a •7), � y I L O 2 0 >, O O, O o 0 D: o I �, m c c '7)' 3 Q' > c O a ° 6 N Q as a) M, m D o u , o 0 0, o C , N 0 N, ° �, o($ @ (0 n a 0, CC) 1 E O J , � •� •� � a N 1 , N, U � 1 0, O 0, N , a d� > -0 (q . °' E, a - 0' Z � 0; > 0. CD CD', c a' M, .: , 1 c v 0, S, a '� M, 0, o o , d c c 1 0 1 , � , (0 ' ' t' J: c c c a , � � , ' t. , c, cp , E y • x' �, U) Ce' c, a), Z' ' D' ' o' o o' o, V, ° O 0 1 0. 0' °, c), 0, o o 0, m, (0 < N p, o , 4 (L U' U U U U' 0 5 ' Q it U (I) U) U M O 5 2 2 m Q' 1 z L).P w1 I co' I ■ N; N N; co. N> co N' co N N; co N co N' co N; N co co N. ; co co N u) N N ' N 0) 1 Q, 0 N N, a), N, a) a), N, a). a), N, N N m, N Q 1 Q, Q Q. O N, a a), a) a) Q, 0 a) a) a) a) O, a), a) a) Q, Q Q ci z >- >- >- >. >- >- } }, >- >. } >- >- }, >- z , z z z z >- >- >- >- >- z >- >- >- >- >- z >- > >- z, z, z I O N 0 as NO a3 V U ° I J u ' ' ' N - :c E. 3 - E a) I , 0� C) c 0 � 4) #, N � 0 0 ° v RV q c r o 1 d tliP ° U N °' 3 E 3 o, N I p 0, �, c Z J o � L o, 1 , 1 o Z N ' Z:5 l I , , a, @ N, co N y N , 1 1 f(0 I a N , o o , 0. N. °- 1 \ > .0 0� ). 1 _ a f6 0 v N N/ 1 1 a) i Q � � T .LL..i C' J j' O) N. a3 C •O' N � N a) N ° a a ' -' 0 ' *5' O m ( 1 ) a m w o c 0 co 0 m N °' t' c' £ ' s N_ a >. c a) E N 0) r\. Q' c +' � C > l N� M , 1 , 1-..)-, N N � O ...... p y O 3 > -O, N N, LS �' c O 3° O, 3 a 4 a 4 a o N w , U c , t E._> ° i N ' co D 3, o o (0 c o t _ c u F. 'E. O 9 a Q b y N' a) `oi ' 111 Z t 0 0 ' �' 0 O, . U N ,_ 0 0' 0, C N m O °' O a )' N y ' c ' C' N O p N J Q E , E, 'O, C C E @ N O M C C. .(r) F . �, 'c o N °� . cc C� a) L .• , , O ) °- N , L a m 0 o o a c 0 - o c U 3 ' o o c •n o. a) o o a, 0 a, 3 0 >, m N N' T I o 0 o' Q 0 U ' aS' 'N J (O, N O, 4- C C, c. 0 N O O 0 4; C 'D y N C. a) .� .(6 (6 co , "O O, co p �� a) (n Q n o a a) > o > > a m . m. ° Y (0 ° 0 0, o E ` 0 CO' T c O E o . ° °, -c a 0 ' 0 a) C m n i'' o E. ° . ' 3 a)' o' T.) L m' 3 C , N, E U Q, @ C @ @ a a N L L co ( ` 0 , - E a). u) C C a) N M, N. N. L, N �, O, a 3 O c , O > , 3 , 1 1 C co O -0 o ' a' . a a (, v) , - ; •m' O , ° , m ; 3. 3, > a a) .. 0 ' S w o ai 2 0) a o w . a = 3, @, 0 3, o, t �, o l L U o 2 C w� -o > O' a) . a •O 'O O N' O C O a)' O O C Q 0 N , " N. (0 ' O, O) C, •0 a N °, a) d J 'O; L0 N CO ° a ) a) y a) O, E N E w o a) co , C ' od _ _c n 0. a a O - N a No N 0_ L ' a N ° � a a - d - N' m a3 ` ) N ' co' E , U • 3 , N. : �, y , c' O � , c, L . v = v. as E. @ 0, 0 IT a ) O y, v_ ,, (o . c N of as co m 0 o > _, v_) o a N . N C. d 0. N N T N • N , a) 3 C : O p ) 0 c O • O r 0 c C N Ti O 0 @ o� j 0 0 � 1 a) N > -- 0) it p N L v •O 'O 0 C N , _, _o, L U L a) N - ( 7 ) a) a). >, .m co , L Ti N, 0 9 c' u) C E ' U a) E, �, a) a) 0 as o' o -c' c, c 0, 0, c co •° • O o N 3 P 0 N c 0 c o,' c a), C, `. ` O (i) 0 (0 (0 (0 Y 0 0 m , (0 E -• 3 ° a) 0 ° as (0 - N o •_ - 5 a o m = c 0 m N (0 0 c ; I Z C 3 0 0 0 a ) o o .. m 0 ( o c 5' 0 o > o _ . v' N o (0 0 44 ui a E' N (a a) c' 0 m c v � , I a) 0 0 0 O' 0 1 ° > 3 0 > > o ai 3 n ' a) E u Q - - - ° 0 0 `m ,_ E c 3 0 • c ' ° `t 1; F 1 � 0, ' 0' a > c a a o � m 0, E u u) ) m . c, m m a ° i - a)' m a) = D a 4 a ` > a) 0, a) - 0 , 0 1 0, O 2 2' 2. a) - o, m -O `o = O O L, 0 0 = a) a) CO • iu , a). o, p d _1 n �i' (A w O O 4. d O �i ¢' 0 , Z lI U u), U U U U Q, = < w 0 m , m ', 2' d o co, co, U, (0 E O `- N M V Ln (0 P- O) O - N M V (0 (0 N a0 ) O O N F, Log (c9) W O) r ° N co V Lc) O W O �- r 1 N N . N N N N N N N N M M M M M M M M M M U O - - _ - O 1, O .. a) O C 0 N O N I ' . O N O 0 M 0 C N , 0) N O co 0 0 N - a) • at .13) 01 O E • .- o C ` u) ° _ ` a o , ,; a I a Q .0