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Home My WebLink About207-163Originated: Delivered to:31-Jan-26Alaska Oil & Gas Conservation Commiss31Jan26-NR !"#$$%$ !&$$'($)*%+ ($)*%,-.WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED3S-08C 50-103-20450-03-00 207163 Kuparuk River WL Cutter FINAL FIELD 5-Jan-263S-08C 50-103-20450-03-00 207163 Kuparuk River WL SCMT FINAL FIELD 6-Jan-263S-08C 50-103-20450-03-00 207163 Kuparuk River WL IBC-ASLT FINAL FIELD 12-Jan-26CD4-210B 50-103-20533-02-00 217182 Colville River WL LDL FINAL FIELD 19-Jan-26CD2-25 50-103-20418-00-00 202074 Colville River WL RBP-MechCutter FINAL FIELD 21-Jan-26CD1-40 50-103-20298-00-00 199044 Colville River WL RBP-MechCutter FINAL FIELD 24-Jan-263S-624 50-103-20868-00-00 223104 Kuparuk River WL MechCutter FINAL FIELD 26-Jan-26Transmittal Receipt//////////////////////////////// 0///////////////////////////////// + ! 1Please return via courier or sign/scan and email a copy to Schlumberger."2"3 +45 %TRANSMITTAL DATETRANSMITTAL #1 67 8" ! - +"8#!(3 . 8)"3 8#!9 3 : 8" +868 8 "8#!;" " 3 - 3" 3""+ 3 + <+3!% T41299T41299T41299T41300T41301T41302T413033S-08C50-103-20450-03-00207163Kuparuk RiverWLCutterFINAL FIELD5-Jan-263S-08C50-103-20450-03-00207163Kuparuk RiverWLSCMTFINAL FIELD6-Jan-263S-08C50-103-20450-03-00207163Kuparuk RiverWLIBC-ASLTFINAL FIELD12-Jan-26Gavin GluyasDigitally signed by Gavin Gluyas Date: 2026.02.02 09:10:17 -09'00' From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: 3S-08 Sundry 325-675 (PTD 207-163) Date:Monday, January 12, 2026 12:24:40 PM Attachments:12Jan26-CPAI-3S-08C-IBC-ASLT.pdf From: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Sent: Monday, January 12, 2026 11:44 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Germann, Shane <Shane.Germann@conocophillips.com> Subject: 3S-08 Sundry 325-675 Jack, attached are logs and crossplot. We are having a team meeting after lunch to align our plan forward on the FAAB Testing. At this time I don’t see us performing the FAAB pressure testing. Looking at the CBL, we’re moving forward with the Contingency: Isolate/Plug Moraine Formation portion of the program/Sundry. Please let me know if you have any questions. From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, January 12, 2026 8:54 AM To: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Subject: [EXTERNAL]RE: 3S-08 Sundry 325-675 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. Sounds good. Jack From: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Sent: Monday, January 12, 2026 7:52 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Subject: 3S-08 Sundry 325-675 We should be finished with the logging ~8am today. POOH, download, process, etc. I should have a field print of the CBL shortly to determine top of cement for the Moraine interval. James J. Ohlinger CPAI CTD Staff Engineer Cell: 907-229-3338 From: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Sent: Sunday, January 11, 2026 6:05 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: Re: [EXTERNAL]RE: Completed Sundry 325-675 KRU 3S-08C We’re rigging up eline currently I don’t expect to have logs till morning !" # # $% & '()( * +$,- $$.( '() + #+#/# .( ( 0 + - - ..++$-00+1%&&+-$%0+-%%-%%-$%01%&&$-00 $234 $234 !" # # $% & -0 ()( * +10 -&2 34 2+--%&$11$%1$01&$-%0--%0 !" # # $% & -0 #+#/#)( * +%1 ,-.( #) !" # # $% & -0 #+#/#/ ( * / #/ +$0%$ SLG AIBK AI -FA AIAV,AIMZMD (org,coWV,AIFA AI -FA AIBK SLG (org) (org) (org) (org) iHAVDFAI (corr) (corr) (corr) (corr) x _ _ 4000 R Zmud(CZMD), th(meas) CORR UFAO 2 Zmud=185,Zdrfl 1.85 ....... 10 . 4500 ] 8 .......;.h.;.• l............:......... G..... 5500 D �::::..•, — — — — 6500 , 7000— —y- — �- �2 D 2 4 6 8 10 AIBK (MRayo7500 (a) (b) (c) (d) (e) (Q (g) (h) (i) (a) (b) (c) (g) (h) (i) in MRayls in MRayls in MRayls Repair Well Operations shutdownFracture StimulateAbandon Plug Perforations1. Type of Request: Pull Tubing Change Approved ProgramOther StimulatePerforateSuspend Alter Casing Other:Plug for Redrill Perforate New Pool Re-enter Susp Well 5. Permit to Drill Number:4. Current Well Class:2. Operator Name: DevelopmentExploratory 3. Address:ServiceStratigraphic 6. API Number: 8. Well Name and Number:7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? NoYes 10. Field:9. Property Designation (Lease Number): 11. Junk (MD):Effective Depth TVD:Effective Depth MD:Total Depth TVD (ft):Total Depth MD (ft): None12055' CollapseCasing Conductor Surface Intermediate Liner Packers and SSSV MD (ft) and TVD (ft):Packers and SSSV Type: 13. Well Class after proposed work:Proposal Summary Wellbore schematic12. Attachments: Development ServiceExploratory StratigraphicBOP SketchDetailed Operations Program 15. Well Status after proposed work:14. Estimated Date for WINJ WDSPLOILCommencing Operations:Suspended WAG SPLUGGAS GSTORDate:16. Verbal Approval: AOGCC Representative: GINJ AbandonedOp Shutdown Contact Name: Contact Email: Contact Phone: Authorized Title: Sundry Number:Conditions of approval: Notify AOGCC so that a representative may witness Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Date:COMMISSIONER THE AOGCCApproved by: Sr Pet Geo Sr Res EngSr Pet EngComm.Comm. (907) 263-4597 CTD/RWO Engineer KRU 3S-08C 5872' 4203'4203'2636' N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 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: Tubing Size: shane.germann@conocophillips.com AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 8188' MD and 5742' TVD N/A Shane Germann STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380107 207-163 P.O. Box 100360, Anchorage, AK 99510 50-103-20450-03-00 Kuparuk River Field Kuparuk River Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst 8237' MD MD 108' 2661' 5848' 108' 4263' 16" 9-5/8" 75' 7"8769' 4234' 8795' 8750-8790' Perf Pups: 9322-12001' 4-1/2" 5844-5847' Perf Pups: 5844-5870' Perforation Depth TVD (ft): 11/30/2025 12055'3867' 3-1/2" 5872' Packer: HRD ZXP Liner Top SSSV: None Perforation Depth MD (ft): L-80 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann , E=shane.germann@conocophillips.com Reason: I have reviewed this document Location: Date: 2025.10.31 08:45:18-08'00' Foxit PDF Editor Version: 13.1.6 325-675 By Grace Christianson at 9:53 am, Oct 31, 2025 X *AOGCC witnessed BOP and annular test to 2500 psi. *Approved FAAB Tools: Schlumberger Suite Array Sonic Logging Tool (ASLT) & Isolation Scanner (IBC). *Send digital Acoustic Impedance AIAV/AIFAV (MRayls), Flexural Attenuation UFAV (dB/m), and CBL Amplitude (mV) data along with AI vs Flex Attenuation crossplot to the AOGCC for determination of FAAB. *FAAB test interval shall be no more than 90' long.10-407 DSR-11/6/25SFD 11/3/2025 100' long. 2156 psi J.Lau 12/18/25 X Note: See attached conditions of approval addendum. JLC 12/19/2025 12/19/25 AOGCC Addendum: 10-403 Abandonments KRU 3S-08C (PTD 207-163) & 3S-09 (PTD 202-205) AOGCC Conditions of Approval: AOGCC witnessed BOP and annular test to 2500 psi. Approved FAAB Tools: Schlumberger Suite Array Sonic Logging Tool (ASLT) & Isolation Scanner (IBC). Operator verify service providers tool calibration and procedures. Send digital Acoustic Impedance AIAV/AIFAV (MRayls), Flexural Attenuation UFAV (dB/m), and CBL Amplitude (mV) data along with AI vs Flex Attenuation crossplot to the AOGCC for determination of FAAB. FAAB test interval shall be no more than 100' long Log acceptance criteria shall at the minimum meet the General Characteristics of Moderate to High bond quality in the attached FAAB Acceptance Criteria table. Creeping Formation Acceptance Criteria If FAAB criteria is n t me cement isolation is required in the Coyote by either 1) suicide squeeze or 2) perf and wash followed by balanced cement plug. AOGCC witness tag and PT of TOC for the Moraine, Coyote, and SC Shoe abandonment plugs. AOGCC witness casing cuts before any top job commences. Photo evidence of cement tops post-cut. Creeping Formation Acceptance Criteria A. Description 1. The element consists of creeping formation (plastically deforming formation extruded into the wellbore). 2. Located in the annulus between casing/liner and borehole wall. B. Function 3. Must provide a continuous, permanent seal along the casing annulus. 4. Must . 5. Must resist pressures from above and below C. Design, Construction, and Selection Requirements 6. Formation may be considered a WBE only when it is known to have plastic properties and can be expected to form a seal with acceptable integrity toward axial leakage. 7. The minimum formation interval length shall be 100' MD 8. The formation shall be geologically homogeneous and laterally continuous. 9. Accepted creeping-formation types include: o Claystone, shale, salt, or any low-permeability, ductile, mobile formation with: High smectite/clay content Low cementing minerals (quartz, carbonates, etc.) Low friction angle Low cohesion 10. Excluded formations (not acceptable as WBEs): o Silt, sandstone, limestone, basalt, granite or other permeable, non-mobile formations. 11.withstand the maximum pressure that could be applied. Creeping Formation Acceptance Criteria (Continued) 12. Position and length of the creeping-bond logs, with: a. Two independent logging tools/measurements, both providing azimuthal data. , and documented. c. Log acceptance criteria established before logging operations. 13. Pressure integrity across the interval. o 14. Formation integrity testing (FIT) at the base of the interval must meet the following requirements and align with expected formation strength a. Minimum formation stress/fracture closure pressure (FCP) shall exceed the maximum wellbore pressure at formation depth E. Use 1. The creeping-formation WBE is primarily used in permanently abandoned wells. F. Monitoring 2. None required. G. Common Well Barrier Acceptance Criteria 3. Minimum contact length requirements: a.100' MD for a single WBE. b. Must include . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 31, 2025 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Approval to Plug & Abandon 3S-08C. This sundry covers the portion to be performed on-rig by Nabors 7ES starting in late-November 2025. 3S-08C was a producer that has been shut in since early 2021. This well has been suspended with a reservoir cement plug (covered in separate 10-403). The remaining steps to P&A this well include isolating the hydrocarbon bearing intervals behind casing and pumping final abandonment cement plugs with Nabors 7ES and ultimately executing final abandonment. We are also requesting to perform Formation as a Barrier (FAAB) testing on the Coyote confining interval. This testing will likely be focused on the Seabee above the Coyote. Much of the details of the cement program to isolate the Coyote are contingent upon the results of the FAAB testing, but the methodology is described in the program. If you have any questions or require any further information, please contact me at 406-670-1939. Shane Germann Senior Rig Workover Engineer CPAI Drilling and Wells Digitally signed by Shane Germann DN: O=ConocoPhillips, CN=Shane Germann, E=shane.germann@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.10.31 08:46:03-08'00' Foxit PDF Editor Version: 13.1.6 requesting to perform Formation as a Barrier (FAAB) testing on the Coyote confining interval. 3S-08C Kuparuk Producer Plug & Abandon w/FAAB Testing PTD: 207-163 Page 1 of 4 Pre-Rig Work Remaining 1. Abandon Kuparuk (covered in separate suspend sundry #325-392). 2. Slickline drift for punch & cutter. 3. Cut tubing and tubing punch above tagged top of cement. 4. Prepare well for rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3S-08C. No BPV will be set for MIRU due to Nabors 7ES internal risk assessment. 2. Circulate seawater and complete 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2500 psi. Test annular to 250/2500 psi. Retrieve 3-1/2 Completion 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2 tubing string and jewelry from pre-rig cut above TOC. Log to Determine 7 TOC and FAAB Test Zone 6. MU cleanout/drift BHA, PU drillpipe and perform casing cleanout to stub. a. This step may be skipped if tubing conditions warrant or may be performed after logging. 7. Log IBC/DSLT to determine 7 TOC and Formation as a Barrier (FAAB) test zone. Isolate Moraine as follows. a. If TOC is BELOW top of Moraine, set CIBP ~75 below top of Moraine then perforate 50 into Moraine and 100 into confining zone above it to isolate for a total of ~150 cement OA plug. Perforating to be done utilizing Gator tool. Set cement retainer 50 above top perforation and cement squeeze 35 bbls (including excess) of 15.8 ppg Class G cement through retainer. Cement volumes through retainer may be adjusted based on injection capabilities through perforations. Hesitation technique will potentially be used. Lay in 100 of cement on top of retainer (3.8 bbl). WOC. Tag cement and PT to 1500 psi with state witness. b. If TOC is ABOVE top of Moraine, continue to FAAB testing. Perform Formation as a Barrier (FAAB) Testing on Coyote Confining Interval 8. Pick up FAAB testing assembly consisting of CIBP, Gator perforating tool (570 version, 4 blade), and test packer. 9. Set CIBP in 7 casing at bottom of FAAB test zone (near base of Seabee). 10. Perforate 7 casing at base of test interval utilizing Gator perforating tool. a. Three activations, oriented 45° apart and spaced 1 foot apart. 11. Pick up hole, perforate 7 production casing at top of test interval utilizing Gator perforating tool. a. Three activations, oriented 45° apart and spaced 1 foot apart. 12. Conduct injection and circulation tests between zones. Note: IBC = Integrated Cement Bond log; DSLT = Digital Sonic Logging Tool SFD 3S-08C Kuparuk Producer Plug & Abandon w/FAAB Testing PTD: 207-163 Page 1 of 6 Pre-Rig Work Remaining 1. Abandon Kuparuk (covered in separate suspend sundry #325-392). 2. Slickline drift for punch & cutter. 3. Cut tubing and tubing punch above tagged top of cement. 4. Prepare well for rig arrival. Rig Work MIRU 1. MIRU Nabors 7ES on 3S-08C. No BPV will be set for MIRU due to Nabors 7ES internal risk assessment. 2. Circulate seawater and complete 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2500 psi. Test annular to 250/2500 psi. Retrieve 3-1/2 Completion 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2 tubing string and jewelry from pre-rig cut above TOC. Log to Determine 7 TOC and FAAB Test Zone 6. MU cleanout/drift BHA, PU drillpipe and perform casing cleanout to stub. a. This step may be skipped if tubing conditions warrant or may be performed after logging. 7. Log IBC/DSLT to determine 7 TOC and Formation as a Barrier (FAAB) test zone. Isolate Moraine as follows. a. If TOC is BELOW top of Moraine, set CIBP ~75 below top of Moraine then perforate 50 into Moraine and 100 into confining zone above it to isolate for a total of ~150 cement OA plug. Perforating to be done utilizing Gator tool. Set cement retainer 50 above top perforation and cement squeeze 35 bbls (including excess) of 15.8 ppg Class G cement through retainer. Cement volumes through retainer may be adjusted based on injection capabilities through perforations. Hesitation technique will potentially be used. Lay in 100 of cement on top of retainer (3.8 bbl). Perform wash/jetting through perforated interval to clear annular space behind perforations. Place balanced plug from CIBP up to 200 MD above top perforation, apply squeeze pressure as necessary. Pull to safety. WOC. Tag cement and PT to 1500 psi with state witness. b. If TOC is ABOVE top of Moraine, continue to FAAB testing. Perform Formation as a Barrier (FAAB) Testing on Coyote Confining Interval 8. Pick up FAAB testing assembly consisting of CIBP, Gator perforating tool (570 version, 4 blade), and test packer. 9. Set CIBP in 7 casing at bottom of FAAB test zone (near base of Seabee) ~75 below top of Coyote formation. 10. Perforate 7 casing at base of test interval utilizing Gator perforating tool. a. Three activations, oriented 45° apart and spaced 1 foot apart. Note: FAAB test interval shall be no more than 100' long - J.Lau 3S-08C Kuparuk Producer Plug & Abandon w/FAAB Testing PTD: 207-163 Page 2 of 4 a. Set test packer between upper and lower perforated intervals. b. Pressure up to 0.67 psi/ft equivalent BHP down drill pipe below test packer. Establish injection while holding 0.67 psi/ft constant for 30 minutes. i. If unable to achieve 0.67 psi/ft BHP, perform test at maximum achievable pressure while holding injection rate constant for 30 minutes. ii. If unable to achieve injection, hold 0.67 psi/ft constant for 30 minutes. c. Monitor casing side for entirety of test to determine pass/fail. i. If no flow or pressure increase seen on casing side, FAAB criteria is met. Continue with P&A. ii. If communication seen on casing side, attempt to establish circulation. Continue with Coyote annular isolation plug. Execute Coyote Isolation Plug 13. Isolate/plug the Coyote interval based on results of the FAAB testing. a. If no injection in perforations and no communication: i. Place 15.8 ppg Class G cement plug from CIBP to 150 feet above top perforation. WOC. Tag and PT to 1500 psi with state witness. b. If no injection in lower perforations and injection in upper perforations: i. Place 15.8 ppg Class G cement plug from CIBP to above lower perforations. ii. Retainer squeeze into upper perforations. Lay in 100 of cement on top of retainer. WOC. Tag and PT to 1500 psi with state witness. c. If there is injection and communication between upper and lower perforations: i. Set cement retainer between upper and lower perforations and perform suicide squeeze. Lay in 15.8 ppg Class G cement from retainer to 150 above top perforation. WOC. Tag and PT to 1500 psi with state witness. d. If there is injection in upper and lower perforations but no communication between zones: i. Set cement retainer 50 above top perforation and perform cement squeeze pumping 15.8 ppg Class G cement. Hesitation technique will potentially be used. Leave 100 of cement on top of retainer. WOC. Tag and PT to 1500 psi with state witness. Cement to Surface 14. MU CIBP and RIH on used 3.5 tubing string. Set CIBP at surface casing shoe depth. 15. Land tubing string just above CIBP. 16. ND BOPE. NU tree. a. Note: Steps 17 & 18 may be performed off-rig pending timing/resources. Well will be freeze protected in this scenario and dry hole tree installed. If OA downsqueeze is not possible due to injection limitations, cement will be circulated to surface through perforations in the PC above the surface casing shoe. 17. Perform OA downsqueeze to place cement from surface to 4263 RKB. Job is planned for 120 bbls of cement, plus excess. 18. Circulate cement surface to surface until full cement returns observed on surface. Job is planned for 150 bbls of cement, plus excess. 19. RDMO 3S-08C Kuparuk Producer Plug & Abandon w/FAAB Testing PTD: 207-163 Page 2 of 6 11. Pick up hole, perforate 7 production casing at top of test interval utilizing Gator perforating tool. a. Three activations, oriented 45° apart and spaced 1 foot apart. 12. Conduct injection and circulation tests between zones. Note: 0.67 psi/ft was chosen as test pressure as this is the maximum pressure expected for the Coyote in this area. It also aligns with the approved area injection order for Coyote which has a maximum injection limit of 0.67 psi/ft. a. Set test packer between upper and lower perforated intervals. b. Pressure up to 0.67 psi/ft equivalent BHP down drill pipe below test packer. Establish injection while holding 0.67 psi/ft constant for 30 minutes. i. If unable to achieve 0.67 psi/ft BHP, perform test at maximum achievable pressure while holding injection rate constant for 30 minutes. ii. If unable to achieve injection, hold 0.67 psi/ft constant for 30 minutes. c. Monitor casing side for entirety of test to determine pass/fail. Reference FAAB acceptance criteria table at the end of this document which lists desired quantitative ranges as well as qualitative acceptance criteria for each bond quality. The goal is to achieve at least moderate to high bond quality. i. If no flow or pressure increase seen on casing side, FAAB criteria is met. Continue with P&A. ii. If communication seen on casing side, attempt to establish circulation. Continue with Coyote annular isolation plug. Execute Coyote Isolation Plug 13. Isolate/plug the Coyote interval based on results of the FAAB testing. a. If no injection in perforations and no communication: i. Place 15.8 ppg Class G cement plug from CIBP to 150 feet above top perforation. WOC. Tag and PT to 1500 psi with state witness. b. If no injection in lower perforations and injection in upper perforations: i. Place 15.8 ppg Class G cement plug from CIBP to above lower perforations. Perforate 50 into Coyote and 100 into confining zone above it to isolate for a total of ~150 cement OA plug. Perform wash/jetting through perforated interval to clear annular space behind perforations. Place balanced plug from CIBP up to 200 MD above top perforation, apply squeeze pressure as necessary. Pull to safety. ii. Retainer squeeze into upper perforations. Lay in 100 of cement on top of retainer. WOC. Tag and PT to 1500 psi with state witness. c. If there is injection and communication between upper and lower perforations: i. Set cement retainer between upper and lower perforations and perform suicide squeeze. Lay in 15.8 ppg Class G cement from retainer to 150 above top perforation. WOC. Tag and PT to 1500 psi with state witness. d. If there is injection in upper and lower perforations but no communication between zones: i. Set cement retainer 50 above top perforation and perform cement squeeze pumping 15.8 ppg Class G cement. Hesitation technique will potentially be used. Leave 100 of cement on top of retainer. Perforate 50 into Coyote and Note: FAAB test interval shall be no more than 100' long - J.Lau And logs indicate "moderate to high" bond quality - J.Lau 3S-08C Kuparuk Producer Plug & Abandon w/FAAB Testing PTD: 207-163 Page 3 of 6 100 into confining zone above it to isolate for a total of ~150 cement OA plug. Perform wash/jetting through perforated interval to clear annular space behind perforations. Place balanced plug from CIBP up to 200 MD above top perforation, apply squeeze pressure as necessary. Pull to safety. WOC. Tag and PT to 1500 psi with state witness. Cement to Surface 14. MU CIBP and RIH on used 3.5 tubing string. Set CIBP at surface casing shoe depth. 15. Land tubing string just above CIBP. 16. ND BOPE. NU tree. a. Note: Steps 17 & 18 may be performed off-rig pending timing/resources. Well will be freeze protected in this scenario and dry hole tree installed. If OA downsqueeze is not possible due to injection limitations, cement will be circulated to surface through perforations in the PC above the surface casing shoe. 17. Perform OA downsqueeze to place cement from surface to 4263 RKB. Job is planned for 120 bbls of cement, plus excess. 18. Circulate cement surface to surface until full cement returns observed on surface. Job is planned for 150 bbls of cement, plus excess. 19. RDMO Cement Surface Casing Shoe 14. MU CIBP and RIH. Set CIBP in 7 PC near surface casing shoe depth, ~50 below planned PC cut depth (final cut depth will be determined from CBL ran at beginning of program). 15. RIH and cut 7 casing at planned PC cut depth. Cut will be made close enough to surface casing shoe to allow for retainer to be set between 50 and 100 above the surface casing shoe. Circulate OA clean as needed. 16. Pull ~200 of 7 casing from cut and lay down. MU casing hanger and re-land. 17. MU and RIH with inflatable cement retainer. Set retainer in 9-5/8 surface casing at a depth of ~50-100 MD above surface casing shoe. 18. Perform cement squeeze through inflatable cement retainer. Final volumes will be based on injection pressures. Estimated volume is 21 bbls through retainer including 100% excess. 19. Place 50 of cement on top of retainer (3.8 bbls). 20. WOC. Tag and PT to 1500 psi with state witness. Cement to Surface 21. POOH laying down drill pipe. 22. ND BOPE. NU tree. 23. Circulate cement surface to surface until full cement returns observed on surface. Job is planned for 280 bbls of cement, plus excess. 24. RDMO 3S-08C Kuparuk Producer Plug & Abandon w/FAAB Testing PTD: 207-163 Page 3 of 4 Execute Final Abandonment Off-Rig (if not performed on-rig) 1. Perform OA downsqueeze to place cement from surface to 4263 RKB. Job is planned for 120 bbls of cement, plus excess. a. Note: If OA downsqueeze is not possible due to injection limitations, cement will be circulated to surface through perforations in the PC above the surface casing shoe 2. Circulate cement surface to surface until full cement returns observed on surface. Job is planned for 150 bbls of cement, plus excess. Surface Excavation 3. DHD to perform drawdown test on tubing, IA, and OA 4. Remove well house. 5. Bleed off T/I/O to ensure all pressure is bled off the system. 6. Remove tree in preparation for excavation and casing cut. 7. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent loose ground from falling into the excavation. 8. Cut off wellhead and all casing strings at 4 feet below original ground level. 9. Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and photo document required. 10. Send the casing head with stub to materials shop. Photo document. 11. Weld 1/4" thick cover plate (16" OD) over all casing strings with the following information bead welded into the top. Photo document. AOGCC witness required. a. ConocoPhillips b. KRU 3S-08C c. PTD #: 207-163 d. API #: 50-103-20450-03-00 12. Remove cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 13. Obtain site clearance approval from AOGCC. RDMO. 14. Report the final P&A has been completed to the AOGCC. Photo document final location condition after work is completed 3S-08C Kuparuk Producer Plug & Abandon w/FAAB Testing PTD: 207-163 Page 4 of 6 Execute Final Abandonment Off-Rig (if not performed on-rig) 1. Perform OA downsqueeze to place cement from surface to 4263 RKB. Job is planned for 120 bbls of cement, plus excess. a. Note: If OA downsqueeze is not possible due to injection limitations, cement will be circulated to surface through perforations in the PC above the surface casing shoe 2. Circulate cement surface to surface until full cement returns observed on surface. Job is planned for 150 bbls of cement, plus excess. Surface Excavation 1. DHD to perform drawdown test on tubing, IA, and OA 2. Remove well house. 3. Bleed off T/I/O to ensure all pressure is bled off the system. 4. Remove tree in preparation for excavation and casing cut. 5. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent loose ground from falling into the excavation. 6. Cut off wellhead and all casing strings at 4 feet below original ground level. 7. Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and photo document required. 8. Send the casing head with stub to materials shop. Photo document. 9. Weld 1/4" thick cover plate (16" OD) over all casing strings with the following information bead welded into the top. Photo document. AOGCC witness required. a. ConocoPhillips b. KRU 3S-08C c. PTD #: 207-163 d. API #: 50-103-20450-03-00 10. Remove cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 11. Obtain site clearance approval from AOGCC. RDMO. 12. Report the final P&A has been completed to the AOGCC. Photo document final location condition after work is completed 3S-08C Kuparuk Producer Plug & Abandon w/FAAB Testing PTD: 207-163 Page 4 of 4 General Well Information: Estimated Start Date: 11/30/2025 Current Operations: Shut in Well Type: Producer Wellhead Type: FMC Gen V. 11 5M casing head top flange. 11 5M tubing head top flange. Scope of Work: Pull the existing 3-1/2 completion from pre-rig cut above TOC. Perform IBC/DSLT. Isolate Moraine formation. Perform FAAB testing to Coyote confining interval. Isolate Coyote formation. Pump final abandonment plug and ultimately execute final abandonment. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams Well Data Kuparuk Formation: Reservoir pressure 5/2/2023 = 2736 psi @ 5802 TVD = 9.1 ppg EMW MASP = 2156 psi Coyote Formation: Reservoir Pressure estimate from Reservoir Engineering = 1820 psi @ 4158 TVD = 8.4 ppg EMW MASP = 1405 psi Nearest Coyote offset (3S-722 on 11/27/2024) = 1790 psi a@ 4106 TVD = 8.4 ppg EMW Moraine Formation: Reservoir Pressure estimate from Reservoir Engineering = 2297 psi @ 5255 TVD = 8.4 ppg EMW MASP = 1772 psi Planned Kuparuk Reservoir plug TOC = 8055 MD Planned tubing cut depth = ~8000 MD Personnel: Workover Engineer: Shane Germann (406-670-1939) / Shane.Germann@conocophillips.com Intervention Engineer: Jill Simek (907-263-4131) / Jill.Simek@conocophillips.com 3S-08C Kuparuk Producer Plug & Abandon w/FAAB Testing PTD: 207-163 Page 5 of 6 General Well Information: Estimated Start Date: 11/30/2025 12/20/2025 Current Operations: Shut in Well Type: Producer Wellhead Type: FMC Gen V. 11 5M casing head top flange. 11 5M tubing head top flange. Scope of Work: Pull the existing 3-1/2 completion from pre-rig cut above TOC. Perform IBC/DSLT. Isolate Moraine formation. Perform FAAB testing to Coyote confining interval. Isolate Coyote formation. Pump final abandonment plug and ultimately execute final abandonment. BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams Well Data Kuparuk Formation: Reservoir pressure 5/2/2023 = 2736 psi @ 5802 TVD = 9.1 ppg EMW MASP = 2156 psi Coyote Formation: Reservoir Pressure estimate from Reservoir Engineering = 1820 psi @ 4158 TVD = 8.4 ppg EMW MASP = 1405 psi Nearest Coyote offset (3S-722 on 11/27/2024) = 1790 psi a@ 4106 TVD = 8.4 ppg EMW Moraine Formation: Reservoir Pressure estimate from Reservoir Engineering = 2297 psi @ 5255 TVD = 8.4 ppg EMW MASP = 1772 psi Planned Kuparuk Reservoir plug TOC = 8055 MD Planned tubing cut depth = ~8000 MD Personnel: Workover Engineer: Shane Germann (406-670-1939) / Shane.Germann@conocophillips.com Intervention Engineer: Jill Simek (907-263-4131) / Jill.Simek@conocophillips.com 3S-08C Kuparuk Producer Plug & Abandon w/FAAB Testing PTD: 207-163 Page 6 of 6 FAAB Acceptance Criteria: Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTU - RKB 12,055.0 3S-08C 4/27/2018 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled plug 3S-08C 10/24/2025 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: UNABLE TO CIRCULATE EITHER DIRECTION WHEN GLM @ 8138' RKB HAS OPEN POCKET 5/7/2018 zembaej NOTE: ***WARNING*** LINER TOP PACKER IN IA - DO NOT EXCEED 3000 psi 1/22/2008 triplwj NOTE: WELL SIDETRACKED 1/21/2008 1/21/2008 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB)Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 33.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.70 28.7 4,263.0 2,661.1 40.00 L-80 BTCM INTERMEDIATE 7 6.28 26.5 8,795.0 5,847.7 26.40 L-80 BTCM LINER 4 1/2 3.96 8,188.2 12,055.0 12.60 L80 IBTMOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB)22.8 Set Depth 8,237.0 String Max No3 1/2 Set Depth 5,760.9 Tubing DescriptionTUBING Wt (lb/ft)9.30 GradeL-80 Top ConnectionEUE 8rd-Mod ID (in)2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB)Top (TVD) (ftKB)Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 22.8 22.8 0.00 HANGER 10.850 3.5" Gen V Tbg Hanger EUE 8rd & pup ( Hgr .75' - Pup 3.65')FMC 2.992 502.1 500.4 9.39 NIPPLE 5.220 3.5" "DS" Nipple w/2.875" NO-GO profile EUE 8rd-M Camco 2.875 4,588.9 2,816.4 58.04 GAS LIFT 5.968 3.5" x 1.5" GLM MMG Camco MMG 2.920 5,773.9 3,701.8 23.14 GAS LIFT 5.968 3.5" x 1.5" GLM MMG Camco MMG 2.920 6,645.8 4,505.3 23.94 GAS LIFT 5.968 3.5" x 1.5" GLM MMG Camco MMG 2.920 7,360.4 5,146.8 29.82 GAS LIFT 5.968 3.5" x 1.5" GLM MMG Camco MMG 2.920 8,138.1 5,719.3 60.43 GAS LIFT 5.968 3.5" x 1.5" GLM MMG Camco MMG 2.920 8,186.4 5,741.4 65.07 NIPPLE 4.520 3.5" Nipple w/2.812" NO-GO profile EUE 8 rd-M Camco DS 2.812 8,195.6 5,745.2 65.92 LOCATOR 5.000 5" Locator Sub 2.992 8,225.5 5,756.8 68.70 SEAL ASSY 3.980 80-40 Bonded Seal assembly 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 10,689.0 5,861.0 91.20 LINER TOP CTD 2/3" Liner top. Note: Liner top @ 90 degrees deviation. 2/10/2019 1.995 10,700.0 5,860.7 91.43 WHIPSTOCK Baker Gen 2 Delta whipstock, 12.98' OAL. Set by CDR3. 2/3/2019 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB)Top (TVD) (ftKB)Top Incl (°) Station No/S Serv Valve Type Latch Type OD (in)TRO Run (psi) Run Date Com Make Model Port Size (in) 4,588.9 2,816.4 58.04 1 Gas Lift OV RK 1 1/2 0.0 11/2/2023 0.025 5,773.9 3,701.8 23.14 2 Gas Lift DMY RK 1 1/2 0.0 5/3/2023 0.000 6,645.8 4,505.3 23.94 3 Gas Lift DMY RK 1 1/2 0.0 1/20/2008 0.000 7,360.4 5,146.8 29.82 4 Gas Lift DMY RK 1 1/2 0.0 11/2/2023 0.000 8,138.1 5,719.3 60.43 5 Gas Lift DMY RK 1 1/2 0.0 5/12/2018 Notes 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB)Top (TVD) (ftKB)Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,188.2 5,742.2 65.23 PACKER 5.960 5" x 7" "HRD" ZXP Liner top Pkr w/10.60 ext TOL ==> 5.250 8,206.8 5,749.8 66.97 NIPPLE 5.570 "RS" Packoff seal nipple jt w/TKC couplings(5.57" OD) 4.250 8,240.6 5,762.1 69.93 XO BUSHING 5.600 XO Bushing 5" BTC x 4 1/2" IBT (Max OD 5.6)3.950 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB)Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,750.0 8,790.0 5,843.9 5,847.3 C-4, 3S-08C 9/3/2009 6.0 APERF 2.5" HES Millenium gun, 60° ph 9,322.0 9,328.0 5,843.5 5,843.3 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/6½" holes per pup 9,543.0 9,548.0 5,846.8 5,847.0 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 10,011.0 10,016.0 5,868.5 5,868.5 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 10,171.0 10,177.0 5,864.6 5,864.4 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 10,363.0 10,368.0 5,862.7 5,862.6 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 10,524.0 10,528.0 5,861.9 5,861.9 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 10,715.0 10,720.0 5,860.3 5,860.2 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup HORIZONTAL, 3S-08C, 10/29/2025 3:17:43 PM Vertical schematic (actual) LINER; 8,188.2-12,055.0 PERFP; 11,997.0-12,001.0 PERFP; 11,524.0-11,530.0 PERFP; 11,310.0-11,315.0 PERFP; 10,997.0-11,002.0 PERFP; 10,715.0-10,720.0 WHIPSTOCK; 10,700.0 LINER TOP; 10,689.0 PERFP; 10,524.0-10,528.0 PERFP; 10,363.0-10,368.0 PERFP; 10,171.0-10,177.0 Acid Wash; 9,322.0 PERFP; 10,011.0-10,016.0 PERFP; 9,543.0-9,548.0 PERFP; 9,322.0-9,328.0 INTERMEDIATE; 26.5-8,795.0 APERF; 8,750.0-8,790.0 GAS LIFT; 8,138.1 GAS LIFT; 7,360.4 GAS LIFT; 6,645.8 GAS LIFT; 5,773.9 GAS LIFT; 4,588.9 SURFACE; 28.7-4,263.0 Kick-Off Plug; 4,203.0 ftKB Intermediate Casing Cement; 28.0 ftKB Cement Casing; 0.0 ftKB NIPPLE; 502.1 CONDUCTOR; 33.0-108.0 KUP PROD KB-Grd (ft)33.30 RR Date1/21/2008 Other Elev 3S-08C ... TD Act Btm (ftKB)12,055.0 Well Attributes Field NameKUPARUK RIVER UNIT Wellbore API/UWI501032045003 Wellbore StatusPROD Max Angle & MD Incl (°)93.43 MD (ftKB)9,173.50 WELLNAME WELLBORE3S-08C AnnotationLast WO:End DateH2S (ppm)75 Date5/7/2023CommentSSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB)Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,997.0 11,002.0 5,863.1 5,863.4 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 11,310.0 11,315.0 5,860.5 5,860.5 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 11,524.0 11,530.0 5,855.9 5,855.6 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 11,997.0 12,001.0 5,869.6 5,869.8 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup Stimulation Intervals Top (ftKB) Btm (ftKB) Interval Number Type Subtype Start Date Proppant Designed (lb)Proppant Total (lb)Vol Clean Total (bbl)Vol Slurry Total (bbl) 9,322.0 11,000.0 1 Acid Wash 5/14/2009 0.0 0.00 0.00 HORIZONTAL, 3S-08C, 10/29/2025 3:17:43 PM Vertical schematic (actual) LINER; 8,188.2-12,055.0 PERFP; 11,997.0-12,001.0 PERFP; 11,524.0-11,530.0 PERFP; 11,310.0-11,315.0 PERFP; 10,997.0-11,002.0 PERFP; 10,715.0-10,720.0 WHIPSTOCK; 10,700.0 LINER TOP; 10,689.0 PERFP; 10,524.0-10,528.0 PERFP; 10,363.0-10,368.0 PERFP; 10,171.0-10,177.0 Acid Wash; 9,322.0 PERFP; 10,011.0-10,016.0 PERFP; 9,543.0-9,548.0 PERFP; 9,322.0-9,328.0 INTERMEDIATE; 26.5-8,795.0 APERF; 8,750.0-8,790.0 GAS LIFT; 8,138.1 GAS LIFT; 7,360.4 GAS LIFT; 6,645.8 GAS LIFT; 5,773.9 GAS LIFT; 4,588.9 SURFACE; 28.7-4,263.0 Kick-Off Plug; 4,203.0 ftKB Intermediate Casing Cement; 28.0 ftKB Cement Casing; 0.0 ftKB NIPPLE; 502.1 CONDUCTOR; 33.0-108.0 KUP PROD 3S-08C ... WELLNAME WELLBORE3S-08C 3S-08C Pre-rig Schematic3-1/2" Camco DS Nipple @ 502' RKB (2.875" ID)3-1/2" 9.3# L-80 EUE 8rd Tubing from surface to 8237' RKB3-1/2" Camco KBMG gas lift mandrels @ 4589', 5774', 6646', 7360', & 8138' RKB3-1/2" Camco DS Nipple @ 8186' RKB (2.812" ID)4-1/2" 12.6# L-80 EUE 8rd Tubing from 8188 to 12055' RKB5" locator sub @ 8196' RKBLiner topBaker 5" x 7" ZXP liner top packer @ 8188' RKBBaker 5" x 7" Flex-Lock liner hanger @ 8211' RKBBaker 80-40 SBE @ 8221' RKBXO Bushing @ 8241' RKB3S-08CL1 CTD CompletionHalliburton Swell Packer at 11,767' MD (min ID 1.686")- Base pipe 2.063", 3.25 lb.ft, Hydril511 connection 1.781" RN-Profile at 11,732' MD- No-go is 1.640"9-5/8" 40# L-80 shoe @ 4263' MD7" 26.4# L-80 shoe @ 8795' MD4-1/2" 12.6# L-80 shoe @ 12,055' RKBKOP @ 10,702' MD16" 62# H-40 shoe @ 108' MDPerf Pups w/ qty. 6 - 1/2" holes3S-08CL1 TD = 12,958' MD2-3/8" slotted/blank liner w/ shorty deployment sleeveTOL = 10,689' MD, BOL = 12,918' MDHalliburton Swell Packer = 11,767' MDRN-Profile = 11,732' MDProduction Casing(8.5" hole) Calculated TOC: 7202' RKB No CBLSurface Casing Estimated TOC: SurfaceOpen OA shoeMoraineTop: 7472' MDBase: 7611' MDCoyoteTop: 6267' MDBase: 7166' MDConfining IntervalTop: 4434' MDSeabee top: 6060' MDBase: 6267' MD 3S-08C Contingency Moraine Abandonment SchematicCement retainer at ~ 7322' MDPerforate from 7522' up to 7372' MDCIBP at ~ 7547' MD3-1/2" Camco DS Nipple @ 8186' RKB (2.812" ID)4-1/2" 12.6# L-80 EUE 8rd Tubing from 8188 to 12055' RKB5" locator sub @ 8196' RKBLiner topBaker 5" x 7" ZXP liner top packer @ 8188' RKBBaker 5" x 7" Flex-Lock liner hanger @ 8211' RKBBaker 80-40 SBE @ 8221' RKBXO Bushing @ 8241' RKB3S-08CL1 CTD CompletionHalliburton Swell Packer at 11,767' MD (min ID 1.686")- Base pipe 2.063", 3.25 lb.ft, Hydril511 connection 1.781" RN-Profile at 11,732' MD- No-go is 1.640"9-5/8" 40# L-80 shoe @ 4263' MD7" 26.4# L-80 shoe @ 8795' MD4-1/2" 12.6# L-80 shoe @ 12,055' RKBKOP @ 10,702' MD16" 62# H-40 shoe @ 108' MDPerf Pups w/ qty. 6 - 1/2" holes3S-08CL1 TD = 12,958' MD2-3/8" slotted/blank liner w/ shorty deployment sleeveTOL = 10,689' MD, BOL = 12,918' MDHalliburton Swell Packer = 11,767' MDRN-Profile = 11,732' MDProductionCasing(8.5" hole) If TOC is below MoraineSurface Casing Estimated TOC: SurfaceOpen OA shoeMoraineTop: 7472' MDBase: 7611' MDCoyoteTop: 6267' MDBase: 7166' MDConfining IntervalTop: 4434' MDSeabee top: 6060' MDBase: 6267' MD 3S-08C FAAB Schematic3-1/2" Camco DS Nipple @ 8186' RKB (2.812" ID)4-1/2" 12.6# L-80 EUE 8rd Tubing from 8188 to 12055' RKB5" locator sub @ 8196' RKBLiner topBaker 5" x 7" ZXP liner top packer @ 8188' RKBBaker 5" x 7" Flex-Lock liner hanger @ 8211' RKBBaker 80-40 SBE @ 8221' RKBXO Bushing @ 8241' RKB3S-08CL1 CTD CompletionHalliburton Swell Packer at 11,767' MD (min ID 1.686")- Base pipe 2.063", 3.25 lb.ft, Hydril511 connection 1.781" RN-Profile at 11,732' MD- No-go is 1.640"9-5/8" 40# L-80 shoe @ 4263' MD7" 26.4# L-80 shoe @ 8795' MD4-1/2" 12.6# L-80 shoe @ 12,055' RKBKOP @ 10,702' MD16" 62# H-40 shoe @ 108' MDPerf Pups w/ qty. 6 - 1/2" holes3S-08CL1 TD = 12,958' MD2-3/8" slotted/blank liner w/ shorty deployment sleeveTOL = 10,689' MD, BOL = 12,918' MDHalliburton Swell Packer = 11,767' MDRN-Profile = 11,732' MDProduction Casing(8.5" hole) Calculated TOC: 7202' RKB No CBLSurface Casing Estimated TOC: SurfaceOpen OA shoeMoraineTop: 7472' MDBase: 7611' MDCoyoteTop: 6267' MDBase: 7166' MDConfining IntervalTop: 4434' MDSeabee top: 6060' MDBase: 6267' MD 3S-08C Final P&A Schematic3-1/2" Camco DS Nipple @ 8186' RKB (2.812" ID)4-1/2" 12.6# L-80 EUE 8rd Tubing from 8188 to 12055' RKB5" locator sub @ 8196' RKBLiner topBaker 5" x 7" ZXP liner top packer @ 8188' RKBBaker 5" x 7" Flex-Lock liner hanger @ 8211' RKBBaker 80-40 SBE @ 8221' RKBXO Bushing @ 8241' RKB3S-08CL1 CTD CompletionHalliburton Swell Packer at 11,767' MD (min ID 1.686")- Base pipe 2.063", 3.25 lb.ft, Hydril511 connection 1.781" RN-Profile at 11,732' MD- No-go is 1.640"9-5/8" 40# L-80 shoe @ 4263' MD7" 26.4# L-80 shoe @ 8795' MD4-1/2" 12.6# L-80 shoe @ 12,055' RKBKOP @ 10,702' MD16" 62# H-40 shoe @ 108' MDPerf Pups w/ qty. 6 - 1/2" holes3S-08CL1 TD = 12,958' MD2-3/8" slotted/blank liner w/ shorty deployment sleeveTOL = 10,689' MD, BOL = 12,918' MDHalliburton Swell Packer = 11,767' MDRN-Profile = 11,732' MDProduction Casing(8.5" hole) Calculated TOC: 7202' RKB No CBLSurface Casing Estimated TOC: SurfaceOpen OA shoeMoraineTop: 7472' MDBase: 7611' MDCoyoteTop: 6267' MDBase: 7166' MDConfining IntervalTop: 4434' MDSeabee top: 6060' MDBase: 6267' MD 3S-08C Final P&A Schematic3-1/2" Camco DS Nipple @ 8186' RKB (2.812" ID)4-1/2" 12.6# L-80 EUE 8rd Tubing from 8188 to 12055' RKB5" locator sub @ 8196' RKBLiner topBaker 5" x 7" ZXP liner top packer @ 8188' RKBBaker 5" x 7" Flex-Lock liner hanger @ 8211' RKBBaker 80-40 SBE @ 8221' RKBXO Bushing @ 8241' RKB3S-08CL1 CTD CompletionHalliburton Swell Packer at 11,767' MD (min ID 1.686")- Base pipe 2.063", 3.25 lb.ft, Hydril511 connection 1.781" RN-Profile at 11,732' MD- No-go is 1.640"9-5/8" 40# L-80 shoe @ 4263' MD7" 26.4# L-80 shoe @ 8795' MD4-1/2" 12.6# L-80 shoe @ 12,055' RKBKOP @ 10,702' MD16" 62# H-40 shoe @ 108' MDPerf Pups w/ qty. 6 - 1/2" holesProductionCasing(8.5" hole) Calculated TOC: 7202' RKB No CBLSurface Casing Estimated TOC: SurfaceOpen OA shoeMoraineTop: 7472' MDBase: 7611' MDCoyoteTop: 6267' MDBase: 7166' MDSurface Cement Job Option 2:Cut 7" PC ~50' above SC shoe.Pull ~200' of PC, re-land.Run inflatable cement retainer and set above PC stub in 9-5/8" surface casing.Squeeze ~10 bbls cement below retainer. L/D work string.Pump cement surface to surface down PC and up OA.Confining IntervalTop: 4434' MDSeabee top: 6060' MDBase: 6267' MD 1 From:Lau, Jack J (OGC) Sent:Friday, December 19, 2025 8:57 AM To:Christianson, Grace K (OGC) Subject:KRU 3S-08C RE: Formation as a Barrier From: Germann, Shane <Shane.Germann@conocophillips.com> Sent: Monday, December 15, 2025 10:09 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Buck, Brian R <Brian.R.Buck@conocophillips.com> Subject: RE: [EXTERNAL]RE: Formation as a Barrier Hi Jack, Im following up on a couple ac on items from our mee ng last week. Please let me know if there are any other ques ons. De ning qualita ve acceptance criteria: Our internal SME for FAAB advised us to use the General Characteris cs in the table from the AkerBP Norway shale barrier study as our qualita ve acceptance criteria. The quan ta ve values from that table will be used as our star ng point with the acknowledgement that these may need re ned based on our tes ng. Ive re-built the table for our use while adding in the CBL amplitude ranges for 7 casing. See below. 100 min/max (100 max distance between perfora ons for pressure tes ng): Our SME was not aware of intervals of shale greater than 100 being tested. He men oned salt intervals in the UK having longer test intervals but not shale barriers. We acknowledge and understand the 100 min/max being derived from NORSOK D010.v4. Thanks, Shane From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, December 8, 2025 1:34 PM To: Germann, Shane <Shane.Germann@conocophillips.com >; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com >; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE: Formation as a Barrier Greg, Shane, We would like to meet after Thursdays 10 am monthly check in to nalize the formation as a barrier criteria for wells 3S-08C and 3S-09. Please bring CPAIs proposed acceptable ranges for AI, exural attenuation, and CBL amplitude for these two wells specially. We realize that FAAB criteria will be better de ned with additional wells and testing, but a predetermined starting point should be established. Jack From: Germann, Shane <Shane.Germann@conocophillips.com> Sent: Thursday, November 20, 2025 3:53 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: [EXTERNAL]RE: Formation as a Barrier Hi Jack, I apologize for the late response. We wanted to make sure we were aligned with our internal strategy globally. Also, its looking like these projects will be delayed from the an cipated start mes I submi ed with the sundry. I expect Nabors 7ES will be ready to move to 3S around December 20th, but I will keep you informed as we work through the 2P project and have a clearer meline. For the logging tools, well be using a Schlumberger suite with the Array Sonic Logging Tool (ASLT) and Isola on Scanner (IBC) tool. The Digital Sonic Logging Tool (DSLT) has previously been used on 3S for logging FAAB intervals and is also acceptable, but we recently used the newer ASLT tool on the 2P projects and were happy with the performance. Acceptable ranges for AI, exural a enua on, and CBL amplitude havent been de ned, but keep in mind were in the infancy of developing FAAB criteria for the Seabee. This tes ng at 3S will help build out the acceptable ranges. We are looking for intervals that fall into moderate-to-high bond quality or be er based on the table developed from Norway tes ng. The cross plot may be processed if theres uncertainty around the material at depth. If we dont see the bond quality were looking for were not concerned about the nature of the material. Thanks, Shane Germann CTD/RWO Engineer ConocoPhillips Alaska O ice: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 1494, Anchorage, AK 99501 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, November 17, 2025 12:31 PM To: Germann, Shane <Shane.Germann@conocophillips.com > Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]RE: Formation as a Barrier 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. Shane, 4 Im following up on my previous email below and have a few additional questions. Please describe the supplier speci c tools planned for the Azimuthal CBL and Isolation Scanner. Will an AI vs Flex Attenuation cross plot be processed? Jack From: Lau, Jack J (OGC) Sent: Monday, November 10, 2025 2:59 PM To: 'Simek, Jill' <Jill.Simek@conocophillips.com> Cc: Germann, Shane <Shane.Germann@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: RE: Formation as a Barrier Thanks Jill, I appreciate the follow up.. Shane, what are the acoustic impedance, exural attenuation, and CBL amplitude ranges CPAI would accept for formation as a barrier? Jack From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Monday, November 10, 2025 2:40 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Germann, Shane <Shane.Germann@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: Formation as a Barrier Jack, Following up from Thursday, attached are the slides from last time ConocoPhillips updated the AOGCC on Formation as a Barrier (2+ years ago!) This presentation includes examples of Formation as a Barrier log responses and geology/minerology of 3S Coyote and overburden. We plan to update this presentation for the meeting Greg will be scheduling later this month. Regarding 3S-08C, I shared your question about expected impedance, ex attenuation, and CBL amplitude ranges with Shane Germann (in cc). Shane should be able to provide more information on this and any other questions you have regarding the sundry application. Thanks, Jill Simek Well Interventions Engineer | ConocoPhillips Alaska ATO-1400 M: 907-980-7503 / O: 907-263-4131 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. Originated: Delivered to:4-Dec-25Alaska Oil & Gas Conservation Commiss04Dec25-NR !"#$$%$ !&$$'($) *%+ ($)*%,-.WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED2P-447 50-103-20468-00-00 203-154 Kuparuk River WL IBC-CBL FINAL FIELD18-Nov-253S-08&50-103-20450-03-00 207-163 Kuparuk River WL Cutter FINAL FIELD 21-Nov-253S-09 50-103-20432-00-00 202-205 Kuparuk River WL Cutter FINAL FIELD 22-Nov-253S-705 50-103-20915-00-00 225-047 Kuparuk River WL TTiX-iPROF-SCMT FINAL FIELD 28-Nov-253S-721 50-103-20911-00-00 225-025 Kuparuk River WL TTiX-iPROF FINAL FIELD 1-Dec-25Transmittal Receipt//////////////////////////////// 0///////////////////////////////// + ! 1Please return via courier or sign/scan and email a copy to Schlumberger."2"3 +45 %TRANSMITTAL DATETRANSMITTAL #1 67 8" ! - +"8#!(3 . 8)"3 8#!9 3 : 8" +868 8 "8#!;" " 3 - 3" 3""+ 3 + <+3!% T41188T11189T41190T41191T411923S-08&50-103-20450-03-00207-163Kuparuk RiverWLCutterFINAL FIELD21-Nov-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.12.05 11:22:02 -09'00' 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: 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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 12055' 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 Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 10/10/2025 12055'3867' 3-1/2" Packer: 80-40 Bonded Seal Assmby SSSV: None Perforation Depth MD (ft): L-80 8769' 4234' 8795' 8750-8790' Perf Pups: 9322-12001' 4-1/2" 5844-5847' Perf Pups: 5844-5870' Perforation Depth TVD (ft): 108' 4263' 16" 9-5/8" 75' 7" 8237' MD MD 108' 2661' 5848' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380107 207-163 P.O. Box 100360, Anchorage, AK 99510 50-103-20450-03-00 Kuparuk River Field Kuparuk River Oil Pool AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 8226' MD and 5757' TVD N/A Joey Roth Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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: Tubing Size: Joey.Roth@conocophillips.com (907) 265-1513 Staff P&A Engineer KRU 3S-08C 5872' 8186' 5741' 8186' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Joey Roth DN: CN=Joey Roth, E=Joey.Roth@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2025.09.30 15:49:07-08'00' Foxit PDF Editor Version: 13.1.6 Joey Roth 325-392 By Grace Christianson at 8:10 am, Oct 01, 2025 2161 psi 10-407 X Attempt to squeeze cement into both 13-08C and 13-08C L1 laterals below retainer. DSR-10/2/25BJM 10/9/25 A.Dewhurst 01OCT25 June 30, 2026 JLC 10/13/2025 10/13/25 Kuparuk River Unit 3S-08C Suspend PTD #: 207-163 Request to Suspend and plug reservoir of 3S-08C prior to full P&A later in the year API #: 50-103-20450-03-00 The 3S-08CL1 was drilled with coil tubing from the C mother bore in 2019. The well has been Shut in since 1/08/2021 and has been identi ed as a P&A candidate, to allow for slot recovery and slot optimization for Coyote Development. The 3S-08 will require rig assisted P&A operations which are currently being developed. Due to 2025 rig schedule constraints, Conoco Phillips would like to plug the producing interval and perform rig less suspension operations on 3S-08C on October 10, 2025: with P&A operations to follow later in the year. Suspension operations will reduce the work scope and timeline tor future P&A operations. The 3S-08C L1 was drilled with Coil from the C mother bore and is completed with 2 3/8 tubing set at 12,918 MD / 5874 TVD. The tubing is set below a Baker HRD ZXP Liner top packer @ 8,188 MD. Per this procedure, suspend operations will be performed by pumping 58 bbl. of 15.8 ppg, Class G cement through a cement retainer above the liner top packer 8170 MD, then placing 1 bbl. on top of the retainer. A tag and pressure test will con rm planned Top of Cement in the tubing @ 8055 MD. Well Status and History: Last MITs :6/28/2025: MIT-T 2500 psi (good test) SBHP: 5/2/2023: 2736 psi @ 5747 TVD. Min ID: 6/28/2025: 2.81 OD run to 8186 wlm. Last Tag: 6/28/2025: Set CA-2 pug in DS nipple @ 8186 wlm 79 bbls cement per Joey Roth email 10/9/25. volume intended to fill both 3S-08C & 3S-08CL1 -bjm Procedure: Slick line / LRS Objective: Drift for cement retainer, perform injectivity tests to con rm adequate rates for cementing operations. 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU Slickline and Pressure Test equipment as required. 3. Drift 3 ½ tubing (2.8 ID) to 8,180 MD (rkb). Note: schematic shows NO-GO at 8186 MD (rkb). 4. Perform Injectivity Test down tubing: pump 20 bbl. diesel, perform step rate injectivity test from 0.5 3 bpm, in ½ bpm increments, up to a maximum pressure of 2500 psi, to ensure adequate rates for cementing operations. Record injectivity test results (Time/Rate/pressure). Discuss results with the well interventions Engineer prior to pumping cement. 5. RDMO Coil Tubing / Cementing: Objective: Place a full column cement plug across the perforations, hesitate & squeeze 5 bbl. cement into the perforations. Plan to place one bbl. cement on top of the cement retainer @ 8170 MD. Cement Volumes (Planned TOC 8,055 MD above Cement Retainer in 3 ½ TBG): 3 1/2 (ID: 2.992) Tubing: 8055 8237MD (182), Volume (1.58 bbl.) 4 ½ (ID: 3.958) Liner: 8237 10702 MD (2465), Volume (37.5 bbl.) 2 3/8 (ID: 1.99) slotted liner: 10689 12918 MD (2229), Volume (8.6 bbl.+ 100% excess = 17.2 bbl.) Total BBL. Cement to pump: 56.2 bbl. + 1bbl (top of retainer) 58 bbl. 6. Ensure an approved Sundry has been received from AOGCC. 7. Contact Cementers a week before the scheduled suspend date, to allow for adequate pilot testing of the P&A cement design. The job is designed for 58 bbl. of 15.8 ppg, Class G cement with gas block additive. 8. Conduct Pre-job Safety Meeting identifying hazards and responsibilities. Inspect wellhead and surrounding pad to identify hazards. 9. RU Coil Tubing Unit and Pressure Test Surface equipment to 3500 psi. 10. Reference the well view tubing schematic and correlate with CCL. +21 bbls = 79 bbls total. See Joey Roth email dated 10/9/25. -bjm 4-1/2" liner from 10702' - 12055' MD to fill liner below whipstock (21 bbls). See See Joey Roth email dated 10/9/25. -bjm 11. RIH w/ cement retainer, taking returns up the CT x Tubing annulus (reverse). Do not Pump while RIH w/ cement retainer. 12. Set the cement retainer 8170 MD, or as deep as the retainer will safely drift. 13. Line up to pump down the CT w/ the CT x tubing annulus closed. 14. Pump 20 bbl. diesel through the retainer to verify proper set and injectivity required for cementing operations (±2 bpm @ 2000 psi). 15. Pump 10 bbl. freshwater spacer 16. Pump 58 bbl. of 15.8ppg Class G Cement through the cement retainer. If squeeze pressure is seen before pumping the total cement volume, stop pumping and begin the next step. 17. Shut down, unsting from retainer. 18. Lay remaining 1 bbl. cement on top of the retainer (1 bbl = 115 ft / bbl., leaving TOC 8055 MD) 19. POOH above TOC. Circulate Coil tubing clean. 20. RDMO 21. WOC (24 hours minimum). 22. Notify the AOGCC Inspector of the timing for the cement plug tag and test 24 hrs. in advance. Slickline / LRS: Objective: State Witness of TOC & MIT-T 23. Conduct a Pre-Job Safety meeting, equipment & pad inspection and hazard identi cation. Tag and Pressure Test must be Witnessed by AOGCC Inspector. 24. RU Slickline and Pressure test equipment to 2000 psi. 25. RIH and tag TOC 8055 MD. Record the depth of tag and pressure test results in Well View. 26. RU LRS and Pressure test equipment to 2000 psi. 27. Perform MIT-T to 1500 psi. 28. Report results and / or issues to the one call well intervention engineer. 29. RDMO. Tubular Detail: Superseded Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CTU - RKB 12,055.0 3S-08C 4/27/2018 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set plug 3S-08C 6/28/2025 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: UNABLE TO CIRCULATE EITHER DIRECTION WHEN GLM @ 8138' RKB HAS OPEN POCKET 5/7/2018 zembaej NOTE: ***WARNING*** LINER TOP PACKER IN IA - DO NOT EXCEED 3000 psi 1/22/2008 triplwj NOTE: WELL SIDETRACKED 1/21/2008 1/21/2008 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 33.0 108.0 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.70 28.7 4,263.0 2,661.1 40.00 L-80 BTCM INTERMEDIATE 7 6.28 26.5 8,795.0 5,847.7 26.40 L-80 BTCM LINER 4 1/2 3.96 8,188.2 12,055.0 12.60 L80 IBTMOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.8 Set Depth 8,237.0 Set Depth 5,760.9 String Max No 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd-Mod ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 22.8 22.8 0.00 HANGER 10.850 3.5" Gen V Tbg Hanger EUE 8rd & pup ( Hgr .75' - Pup 3.65') FMC 2.992 502.1 500.4 9.39 NIPPLE 5.220 3.5" "DS" Nipple w/2.875" NO-GO profile EUE 8rd-M Camco 2.875 4,588.9 2,816.4 58.04 GAS LIFT 5.968 3.5" x 1.5" GLM MMG Camco MMG 2.920 5,773.9 3,701.8 23.14 GAS LIFT 5.968 3.5" x 1.5" GLM MMG Camco MMG 2.920 6,645.8 4,505.3 23.94 GAS LIFT 5.968 3.5" x 1.5" GLM MMG Camco MMG 2.920 7,360.4 5,146.8 29.82 GAS LIFT 5.968 3.5" x 1.5" GLM MMG Camco MMG 2.920 8,138.1 5,719.3 60.43 GAS LIFT 5.968 3.5" x 1.5" GLM MMG Camco MMG 2.920 8,186.4 5,741.4 65.07 NIPPLE 4.520 3.5" "DS" Nipple w/2.812" NO-GO profile EUE 8 rd-M Camco 2.812 8,195.6 5,745.2 65.92 LOCATOR 5.000 5" Locator Sub 2.992 8,225.5 5,756.8 68.70 SEAL ASSY 3.980 80-40 Bonded Seal assembly 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 8,186.0 5,741.3 65.03 TUBING PLUG 2.81" CA-2 Plug (OAL = 28") 6/28/2025 0.000 10,689.0 5,861.0 91.20 LINER TOP CTD 2/3" Liner top. Note: Liner top @ 90 degrees deviation. 2/10/2019 1.995 10,700.0 5,860.7 91.43 WHIPSTOCK Baker Gen 2 Delta whipstock, 12.98' OAL. Set by CDR3. 2/3/2019 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 4,588.9 2,816.4 58.04 1 Gas Lift OV RK 1 1/2 0.0 11/2/2023 0.025 5,773.9 3,701.8 23.14 2 Gas Lift DMY RK 1 1/2 0.0 5/3/2023 0.000 6,645.8 4,505.3 23.94 3 Gas Lift DMY RK 1 1/2 0.0 1/20/2008 0.000 7,360.4 5,146.8 29.82 4 Gas Lift DMY RK 1 1/2 0.0 11/2/2023 0.000 8,138.1 5,719.3 60.43 5 Gas Lift DMY RK 1 1/2 0.0 5/12/2018 Notes 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 8,188.2 5,742.2 65.23 PACKER 5.960 5" x 7" "HRD" ZXP Liner top Pkr w/10.60 ext TOL ==> 5.250 8,206.8 5,749.8 66.97 NIPPLE 5.570 "RS" Packoff seal nipple jt w/TKC couplings(5.57" OD) 4.250 8,240.6 5,762.1 69.93 XO BUSHING 5.600 XO Bushing 5" BTC x 4 1/2" IBT (Max OD 5.6) 3.950 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,750.0 8,790.0 5,843.9 5,847.3 C-4, 3S-08C 9/3/2009 6.0 APERF 2.5" HES Millenium gun, 60° ph 9,322.0 9,328.0 5,843.5 5,843.3 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/6½" holes per pup 9,543.0 9,548.0 5,846.8 5,847.0 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 10,011.0 10,016.0 5,868.5 5,868.5 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 10,171.0 10,177.0 5,864.6 5,864.4 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 10,363.0 10,368.0 5,862.7 5,862.6 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 10,524.0 10,528.0 5,861.9 5,861.9 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 10,715.0 10,720.0 5,860.3 5,860.2 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup HORIZONTAL, 3S-08C, 9/30/2025 3:01:46 PM Vertical schematic (actual) LINER; 8,188.2-12,055.0 PERFP; 11,997.0-12,001.0 PERFP; 11,524.0-11,530.0 PERFP; 11,310.0-11,315.0 PERFP; 10,997.0-11,002.0 PERFP; 10,715.0-10,720.0 WHIPSTOCK; 10,700.0 LINER TOP; 10,689.0 PERFP; 10,524.0-10,528.0 PERFP; 10,363.0-10,368.0 PERFP; 10,171.0-10,177.0 Acid Wash; 9,322.0 PERFP; 10,011.0-10,016.0 PERFP; 9,543.0-9,548.0 PERFP; 9,322.0-9,328.0 INTERMEDIATE; 26.5-8,795.0 APERF; 8,750.0-8,790.0 TUBING PLUG; 8,186.0 GAS LIFT; 8,138.1 GAS LIFT; 7,360.4 GAS LIFT; 6,645.8 GAS LIFT; 5,773.9 GAS LIFT; 4,588.9 SURFACE; 28.7-4,263.0 NIPPLE; 502.1 CONDUCTOR; 33.0-108.0 KUP PROD KB-Grd (ft) 33.30 RR Date 1/21/2008 Other Elev 3S-08C ... TD Act Btm (ftKB) 12,055.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032045003 Wellbore Status PROD Max Angle & MD Incl (°) 93.43 MD (ftKB) 9,173.50 WELLNAME WELLBORE3S-08C Annotation Last WO: End DateH2S (ppm) 75 Date 5/7/2023 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 10,997.0 11,002.0 5,863.1 5,863.4 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 11,310.0 11,315.0 5,860.5 5,860.5 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 11,524.0 11,530.0 5,855.9 5,855.6 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup 11,997.0 12,001.0 5,869.6 5,869.8 C-4, 3S-08C 1/19/2008 1.0 PERFP Perf Pups w/six 1/2" holes per pup Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 9,322.0 11,000.0 1 Acid Wash 5/14/2009 0.0 0.00 0.00 HORIZONTAL, 3S-08C, 9/30/2025 3:01:47 PM Vertical schematic (actual) LINER; 8,188.2-12,055.0 PERFP; 11,997.0-12,001.0 PERFP; 11,524.0-11,530.0 PERFP; 11,310.0-11,315.0 PERFP; 10,997.0-11,002.0 PERFP; 10,715.0-10,720.0 WHIPSTOCK; 10,700.0 LINER TOP; 10,689.0 PERFP; 10,524.0-10,528.0 PERFP; 10,363.0-10,368.0 PERFP; 10,171.0-10,177.0 Acid Wash; 9,322.0 PERFP; 10,011.0-10,016.0 PERFP; 9,543.0-9,548.0 PERFP; 9,322.0-9,328.0 INTERMEDIATE; 26.5-8,795.0 APERF; 8,750.0-8,790.0 TUBING PLUG; 8,186.0 GAS LIFT; 8,138.1 GAS LIFT; 7,360.4 GAS LIFT; 6,645.8 GAS LIFT; 5,773.9 GAS LIFT; 4,588.9 SURFACE; 28.7-4,263.0 NIPPLE; 502.1 CONDUCTOR; 33.0-108.0 KUP PROD 3S-08C ... WELLNAME WELLBORE3S-08C Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By LAST TAG: 3S-08CL1 jennalt Notes: General & Safety Annotation End Date Last Mod By NOTE: Halliburton Swell Packer at 11,767'MD (min ID 1.686") 3/4/2019 jennalt NOTE: 1.781" RN Profile @ 11,732'MD - No-go is 1.640" 3/4/2019 jennalt Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CL1 LATERAL 2 3/8 1.99 10,689.0 12,918.0 5,874.3 4.60 L-80 STL Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 10,689.0 5,861.0 91.20 Shorty Deployment Sleeve 0.000 Shorty Deployment Sleeve 0.000 11,731.5 5,866.1 90.14 NIPPLE RN Nipple 11,764.4 5,866.0 90.32 XO 2.375 XO (2-3/8" STL Box x 2-1/16" HYD 511 Pin) 1.992 11,767.4 5,866.0 90.39 PACKER Halliburton Swell Packer & Pups 11,790.1 5,865.7 90.92 XO 2.375 XO (2-1/16" HYD 511 BOX x 2- 3/8" STL Pin ) 1.992 11,884.1 5,865.7 89.16 Shorty Deployment Sleeve 0.000 Shorty Deployment Sleeve 0.000 HORIZONTAL, 3S-08CL1, 9/30/2025 3:01:47 PM Vertical schematic (actual) CL1 LATERAL; 10,689.0- 12,918.0 LINER; 8,188.2-12,055.0 PERFP; 10,524.0-10,528.0 PERFP; 10,363.0-10,368.0 PERFP; 10,171.0-10,177.0 PERFP; 10,011.0-10,016.0 Acid Wash; 9,322.0 PERFP; 9,543.0-9,548.0 PERFP; 9,322.0-9,328.0 INTERMEDIATE; 26.5-8,795.0 APERF; 8,750.0-8,790.0 TUBING PLUG; 8,186.0 GAS LIFT; 8,138.1 GAS LIFT; 7,360.4 GAS LIFT; 6,645.8 GAS LIFT; 5,773.9 GAS LIFT; 4,588.9 SURFACE; 28.7-4,263.0 NIPPLE; 502.1 CONDUCTOR; 33.0-108.0 KUP PROD KB-Grd (ft) 33.30 RR Date 1/21/2008 Other Elev 3S-08CL1 ... TD Act Btm (ftKB) 12,958.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032045060 Wellbore Status PROD Max Angle & MD Incl (°) 93.43 MD (ftKB) 9,173.49 WELLNAME WELLBORE3S-08C Annotation Last WO: End DateH2S (ppm) 75 Date 5/7/2023 Comment 207-163 T16056 Originally recieved 3/24/2008 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.12 14:52:30 -08'00' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MAR ? 1 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Soap Well ❑ Other: CO261 B Whipstock❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development p Stretigraphic❑ Exploratory ❑ Service ❑ 207-163 3. Address: P. 0. Box 100360, Anchorage, 6. API Number: Alaska 99510 50-103-20450-03-00 7. Property Designation (Lease Number): a. Well Name and Number: KRU 3S -08C ADL 380107 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 12,055 feet Plugs measured None feet true vertical 5,872 feet Junk measured None feet Effective Depth measured 12,055 feet Packer measured 8,188 feet true vertical 5,872 feet true vertical 5,742 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 feet 16 108' MD 108' TVD SURFACE 4,234 feet 9 5/8 " 4,263' MD 2661' TVD INTERMEDIATE 8,769 feet 7 8,795' MD 5848' TVD LINER 3,867 feet 4 1/2 " 12,055' MD 5872' TVD Perforation depth: Measured depth: 8750-8790. oerf Duos 9322-12001 feet True Vertical depth: 5843-5847. 5843-5870 feet Tubing (size, grade, measured and true vertical depth) 3.5 " L-80 8,237' MD 5,761' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - HRD ZXP Packer 8,188' MD 5,742' TVD SSSV: -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): NIA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Dill GasMcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN - - - - Subsequent to operation: SHUT-IN 14. Attachments (required per 20 AAC 25.070, 25.071, 8 25.283) 15. Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development O Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil El Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-016 Contact Name: Keith Herring Authorized Name: Kai Starck Contact Email: Keith.E.Herring@cop.com Authorized Title: CTrector D Di Authorizetl Si nature: i - Date' 3 Contact Phone: (907) 263-4321 V77- 31/s/, y HI3UM 40/MAR 12 2019 9A18" 400 LA0 shoe @ 4283' MD 3S -08C Final CTD Schematic 3-112" Camra OS Nipple ® SOS RKB (2 BPS" ID) 3-112" 9.310 L40 EDE 8M Tubing fore surface la 823T RKB 3-1? Camra KBMG gas lift mandrels ® 4589'. 5774', fi846, 73613, & 8138' RKB }M- Camco DS Npple ® 8186' RKB (2.812• ID) A -M" 12.610 LA0 EDE BN Taking from 8180 to 12055' RKB 5" locator sub D9 8196' RKB Lines Baker 5"x T'Z la her tap packer@ 8188' RKB Baker 5" x T' Flax -Wolk liner hanger @ 8211' RKB Baker 8040 SBE ® 8221RKB %O Bushing ® 8241' RKB ]3-0BLL1 CTD Completion HepibWon Swell Packer at 11,76T MD (min ID 1.6851 - Base pipe 2.063", 3,25 left. HyBn1511 Connec0on 1.781"RN~ls at 11.732' MD - No-go is 1.840" r26.1# LBB ahee a 8785' MD KOP 107D2'MD 12"1260 1A0 vhoe PeM Pups W qM.8-112" hobs 12,056 RKB r35.OBCUPB1 TD=12,803'MD nchoreB Billet - 12,028' MD KUP PROD WELLNAME 3S -08C WELLBORE 3S_0$C COnOcO�Iillip5 Well Attributes Max Angle S MD TD f' 11 FreI4 Name We11Mre AP011W1 Well4ore aUWs ntl^h) MO'XXBI qc+Blm iflKBl /i85Ka. I1C. /KI IpARI K RIV FR UNIT ISntn'IOndcnni loonn nr �c ��ncc .1 WO XORaOMAL� ll 3Ia1A199:0.111 AM Last Tag V ul vJmnrc (ecoun Annotation republicEM- Wallace, last M. By ........................ X/,HpER: 2z9 _ .... Last Tag: CTU -RKB 12.055.0 4I27201B 35-0BC Ippurven Last Rev Reason Ann.M4on EM Dow wellbore LaslMml By Rev Reason: Replaced OV, CTD iATERAL 3/412019 3S-0eC Jill Casing Strings cOxWCTOR.33.6108.0 ea:mecelet ipnono ) mgr) roppose, set berm hare) Set Degn Ill. .1-p_ 6m4e rop TnrcM CONDUCTOR 16 15,06 33.0 1080 1080 62.50 H40 WELDED NMPLE:5021 balite postulation 00(Inj 107001 Top MR) set Depin IRKS) SN Oepin ffu[a.. WlKen b-jibrade Tap TM1wM SURFACE 990 8]0 287 4,2630 2,fifi1.1 4000 LA0 BTCM Cases Oeacnptlon 00(in) ID (in) Top. Sal oepm mnel Sal Dptn nVpl... wlM' 9._ apse rav rime INTERMEDIATE ] 6.28 26.5 8,]950 5,0477 2840 LA0 BTCM SURF M74.a Casln9 Dexnptien OD gnl Ip(n) TOPMB) sM Depm(i SN peep nVD)...MIL. V.eiedo iep TM1rck LINER 4112 396 8,1882 12055.0 1260 L80 ISTMOD 006 LIFT: e3M.a Liner Details No Rina ID Top(-) rop0W)HBKB) Top loci 17 Ran pit Can al 8,188.2 574 2 6523 PACKER Tx HRD ZXP Liner lop Pkr yen out, ext T L ==1 5250 GO.SUFT.s,TY.1.9 8,2088 5.7498 66.9] NIPPLE "R " PackoN seal rupp w DK couplings 5. 4250 OD) AAs uFr; 6aase 8,210.6 57512 6].32 HANGER 5'x7"Flex-Lack Liner Hi (596"ODx442' ID) 4420 8.220.5 5,7550 68.4 5RE 5'Seal Bore Ext. wrtKCCOuVlinpMax D 4000 5.60" x 4' IDI pAs uFr', Tama 8,240.6 5,762.1 69.93 XO BUSHING XO Bushing 5" BTC x 417"IBT(Max OD 56) 3.950 Tubing Strings OK3 uFT: &13L+ ToamO Description Strep pra 1olml Top mKill or Depen ln_ael Dwp(NDI 6..M pWnr craea TnP eonnedmn TUBING 312 2.99 22.8 8,2370 5,760.9 9.30 L-60 EUE Brtl-Mtatl NIPPLE:8.18R° Completion Details TopIND) Top Incl NADp rop (Itl(B) Inrcel P) I Item lies (lo.m to gay LO sube165.8 8 228 0.00 HANGER FMC 35"Gm V Tog Hanger EUE8rd 8pip(Hgr75'-Pup 3.65') 2.992 502.1 SODA 9.39 NIPPLE 3S"Came, ME" Nipple w2al NO-GO profile EUE Brd-M 2875 8186A 5,741.4 65. ] NIPPLE 3.5" Cii'DS' Nipple w2.81 ' NO-GO Profile EUE 8 m -M T812 EEALAS6Y:Asell 8,195.6 5,745.2 65.2 LOCATOR 5"Locator Suo 2.992 8225.5 5,756.8 68.70 SEALASSY 8040 Startled Seal assembly 3000 Other In Hale (Wireline retrievable plugs, valves, pumps, fish, Ste.) TOPM') Top Incl rop(nKSI (nrc8) pl pas coon Run pah ID lint 10,689.0 5,861. 1. LINER TOP 11 Liner tap. NOW: Uner lop V W slight, 2/10/2019 1995 Aparn' 6T900a790.0 deviation. 10.700.0 5,860.) 143 WHIPSTOCK eer en Delta whipstoc, ' AL. ruby CDR, 2)32019 0000 IMERMEONTE: 2859.]pS0 Perforations & Slots PERFP', 9=09,921,0� snot - - Top (MB) BM NMB) Too(TVD) fifti BrmMD) (,Be) Chose Zone pare Den (mo. 1 Type Com 8,7500 8,790.0 5,843.9 5,84].3 C -s OBC 9I3I1009 .0A PERF .5"HE Mt emum Aun, ding 0 PERFP/S."fra8.0- 1 9822.0 9,328.0 6.843.5 5,843.3 C4,3S-08C 1I19I2008 10 PERFP Pe Pups six1 hors per Pup 9,5430 9,548. 5846.8 5,84].0 C4, 35-0BC TIT2= 10 PERFP P ups W sM Obfi pspup - 10,011.0 1601. 5.868.5 5,868.5 C4, 3S-0OX 11192 10 PERFP Pe ups wslx Tholes PERFP', 10011610.0160 per pup 10.1710 10,1770 5,864.6 5,864.4 C4,3S-08C 11/92008 1.0 PERFP Pertup eslx 'holes Aca1 wenn; ssa.o per pup plafil 10,171 0,+0,17rm _ 10,3630 10,368.0 5862.7 5,862.6 C4,35-0BC 11192008 10 PERFP Pelf Pupswsx "notes per Pup 10,524.0 10,528.0 5.8619 5,861.9 C4, 35-08C 1/1912008 10 PERFP Pert ups w/six tl 'holes PERFP: TOM p. levo perpup 10,7150 10,]20.0 5,860.3 5,8602 C4, 3S-0BC 1119/0108 10 PERFP ProfPups wince"hales PERFP: 104.0+0829.0- 1- or Pup 169970 11,002.0 5,8631 5,863.4 C4,3 -08C 1H9I2008 10 PERFP Pe upswsx 1 "holes perpup .'p.T.K'oyoR.O r l WXIPaiOCK: +e.]M.O 11,3100 11,3150 5860.5 5,8605 0438-08C 111912000 1.0 PERFP Pert upswsx 'tales Per pup PERFP: +0.T150+a.7mo- 11,5240 11,530.0 511SER 5,855.6 C4, 3S -08C 1/192(108 1.0 PERFP Pe Pups wlsix Des - perpup 11,9970 12,001.0 5,8696 5,8698 C4, 35-08C 11192008 10 PERFP Pe Pups w/six holes perpup pERFP. t0...11.0%, 0-' ;_ Frac Summary Slat pM Proppant basis. pill PrappanlM FOlmNgn 1p) 5/14120W 11 PERFP, 11,310611,3+501 SWO Purolator TOpN M(M(B)ess MR)lln4b FluiE Byxpm VOICWnlaap Vol slmryl09p 914INNi9 9,322.0 11,000,9 Mandrel Inserts - SI all PERFv',nsza 6nsno-_ _ H Top m'D) Valve lapn Peters TRIP Run Top(NI(B) M R) Map Model Op(In) Sam ryq ryas fin) IPR Run pMe Cem Or 1)022 450.9 28164 CAMCO MMG 112 Gas Li DMY RK 0.000 42un 2 577).9 3701.8 CAMCO MM112 Gas Li GLV RK 0AM 1,7500 11172019 3 6,645.8 45053 CAMCO MMG 112 GasU DMY RK 0. 0.0 12002006 4 7,360.4 5,1468 CAMCO MM lll2 Gas Lift V RK 0.250 0.0 3142019 PERFP;n s9].wZW10.-1 _ 5 B,t36.1 571. CAMCO MMG 112 Gas LS DMV RK 0000 0.0 9122018 gee notes UNER:S,tasslZesso Operations Summary (with Timelog Depths) 3S-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stag lime EM lane Dur (hr) Phase Op Cod. Acovity Code Time P -T -X Operation start Depth (MR) End Depth(WB) 1/31/2019 1131/2019 3.00 MIRU MOVE MOB P Continue RDMO from 1B 0.0 0.0 16:00 19:00 1/31/2019 2/1/2019 5.00 MIRU MOVE MOB P Hold PJSM with dg / NES team. Start 0.0 0.0 19:00 00:00 loading shop. Pull off well. Install Jeeps. Rig down cellar area 2/1/2019 2/1/2019 12.00 MIRU MOVE MOB P Leave 1 B pad enroute to 3S. 19.7 mile 0.0 0.0 00:00 12:00 move 2/1/2019 2/1/2019 6.00 MIRU MOVE MOB P Arrive at 3S, lots of flowback activity 0.0 0.0 12:00 18:00 on pad. Relocate equipment on pad. Remove jeeps and spot rig on well. 2/1/2019 2/1/2019 5.00 MIRU WHDBOP RURD P Work rig up checklist. Safe out rig, 0.0 0.0 18:00 23:00 R/U putz, Nipple up stack, Rig up MP Line, Change out riser. Get RKB's 2/1/2019 2/2/2019 1.00 MIRU WHDBOP NUND P . Rig Accept 23:00, Fluid pack stack, 0.0 0.0 23:00 00:00 PJSM for BOPE test 2/2/2019 2/2/2019 0.50 MIRU WHDBOP RURD P Stack fluid packed, Start shell test. 0.0 0.0 00:00 00:30 Low held good test, Come up to high pressure 2/2/2019 2/2/2019 2.00 MIRU WHDBOP BOPE T BOP high pressure shell test failed. 0.0 0.0 00:30 02:30 Leaking door seal on ODS lower shear seal. Bleed off, drain stack. Remove door and replace seal 2/2/2019 2/2/2019 0.50 MIRU WHDBOP BOPE P Reflood stack for shell test. Shell test 0.0 0.0 02:30 03:00 good 212/2019 2/2/2019 7.00 MIRU WHDBOP BOPE P Test one good, Test two Lower shear 0.0 0.0 03:00 10:00 seals not sealing. Bleed off and retest. No good. Continue with test 2/2/2019 2/2/2019 0.50 MIRU WHDBOP BOPE P Retest Lower Blind Shear Rams (good 0.0 0.0 10:00 10:30 1 test), BOP test complete 2/2/2019 2/2/2019 0.30 MIRU WHDBOP PRTS P Slide cart forward, install nozzle, slab 0.0 0.0 10:30 10:48 onto stump, fluid pack surface lines. 2/2/2019 2/2/2019 0.50 MIRU WHDBOP PRTS P Test and chart Inner reel iron and pac- 0.0 0.0 10:48 11:18 off. 2/2/2019 2/2/2019 1.00 MIRU WHDBOP PRTS P PU PDL stab onto stump, line up to 0.0 0.0 11:18 12:18 tiger tank line, P!r and chart lest. 212/2019 2/2/2019 0.90 MIRU WHDBOP PRTS P Slide can forward, swap out Upper 0.0 0.0 12:18 13:12 Quick, 67.2 megphm, and >2000 (good -test), PIT Upper Quick, 4,500 psi (good -test) 2/2/2019 2/2/2019 1.75 PROD1 RPEQPT PULD P PJSM, PU/MU Gen II Deka Whipstock 0.0 0.0 13:12 14:57 1 4 1/2", 12.60#, OD 2.625" (BOT) 222019 2/2/2019 0.30 PROD1 RPEQPT PULD P PU/MU CoilTrak tools, function open 0.0 0.0 14:57 15:15 SSV, unable to open, call DSO to assist in cellar. 2/2/2019 222019 0.75 PROD1 RPEQPT PULD T Function open SSV, unable to function 0.0 75.0 15:15 16:00 SSV open fully, replace stainless plumbing ,function open SSV 2/2/2019 2/2/2019 1.20 PRODi RPEQPT PULD P Continue PD WS setting assembly 75.0 75.0 16:00 -19 17:12 TM 2/22019 1.90 PRODt RPEQPT TRIP P RIH, w/WS setting assemby, 75.0 8,295.0 17:12 19:06 1 IA=1,300, OA=421 2/2/2019 2/2/2019 0.20 PROD1 RPEQPT DLOG P Log the Kt marker correction of+6', 8,295.0 8,337.0 19:06 19:18 PUW=40K 222019 22/2019 0.60 PRODt RPEQPT TRIP P Continue in with wipstock 8,337.0 10,815.0 19:18 19:54 2/2/2019 2/2/2019 0.40 PROD1 RPEQPT TRIP P Clean trip to 10815, PUH for CCL 10,815.0 8,139.0 19:54 20:18 pass 222019 2/2/2019 2.90 PROD1 RPEQPT DLOG P 8139', Log CCL to 10815 8,139.0 10,815.0 20:18 23:12 2/2/2019 2/212019 0.40 ODi PRPEQPT R TRIP P Some depth abnormalities during CCL 10,815.0 8,300.0 2312 23:36 log. PUH to tie into K1 Page 1/9 Report Printed; 3/812019 Operations Summary (with Timelog Depths) 3S -O8 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Sten Turre End Time du (hr) Phase Op Catle Activit' Code Time P -T-% Operation Start Depth (WS) End Depth (MS) 2/2/2019 2/2/2019 0.30 PROD1 RPEQPT DLOG P Log K1 for +11', Check counter wheel 8,300.0 8,333.1 23:36 23:54 assembly - Good. 2/2/2019 2/3/2019 0.10 PROD1 RPEOPT TRIP P PUH to relog K1 8,333.1 8,290.0 23:54 00:00 2/3/2019 2/3/2019 0.10 PROD1 RPEQPT DLOG P Log K1 for no correcion 8,290.0 8,329.0 00:00 00:06 2/312019 2/3/2019 0.80 PROD1 RPEQPT TRIP P Trip in hole, Slow down to looging 8,329.0 10,725.0 00:06 00:54 speed 9640 - 9677. geo calls on depth, continue in 2/3/2019 2/3/2019 0.10 PROD1 RPEQPT DLOG P Log CCL to see pert Pup, Pert pup @ 10,725.0 10,805.0 00:54 01:00 10,715 2/3/2019 2/32019 0.30 PROD1 RPEQPT TRIP P PUH to 10625'. RBIH to set depth @ 10,805.0 10,713.0 01:00 01:18 10712.98', Orient to 180°ROHS. Close EDC. Bring on pumps. See tool shift @ 3800 PSI. Shut down pumps. Set 2.9K down on tray. 2/3/2019 2/3/2019 0.40 PROD1 RPEQPT TRIP P PUH to 10679', Open EDC. Bleed 10,713.0 10,679.0 01:18 01:42 down WHIP 2/3/2019 2/32019 0.70 PRODt RPEQPT CIRC P Pump 40 BBLs water/Displace well 10,679.0 10,679.0 01:42 02:24 to used PwrPro for window milling 2/3/2019 2/3/2019 1.50 PROD1 RPEQPT TRIP P Trip out of hole, PUW=40K, 10,679.0 8,200.0 02:24 03:54 2/3/2019 213/2019 0.30 7R551 RPEQPT TRIP P Communication with tool impeded. 8,200.0 58.0 03:54 04:12 ontinue out of well 2/3/2019 2/3/2019 1.75 PROD1 RPEQPT PULD P Tag up and space out, PJSM, PUD 58.0 0.0 04:12 05:57 BHA#1 2/3/2019 2/32019 0.50 PROD1 RPEQPT PULD P PJSM, preform valve checklist 0.0 0.0 05:57 06:27 2/3/2019 2/3/2019 0.50 PROD1 RPEQPT PULD P Flush & LD setting assembly 0.0 0.0 06:27 06:57 2/32019 2/3/2019 1.00 PROD1 WHPST SVRG P Continue Troubleshooting a -line 0.0 0.0 06:57 07:57 issues. Perform INJH inspection maintenance. 2/3/2019 2/32019 3.00 PROD1 WHPST RGRP T Repair bulkhead electrical connection, 0.0 0.0 07:57 10:57 test aline, 671>550, PT aline service break 4,000 psi 2/3/2019 2/3/2019 1.50 PRODi WHPST PULD P PD, milling assembly 0.0 63.7 10:57 12:27 2/32019 2/3/2019 1.70 PROW WHPST TRIP P RIH, w/BHA#2 window milling 63.7 8,290.0 12:27 14:09 1 lassembly 213/2019 2/3/2019 0.20 PROD1 WHPST DLOG P Log the K1 marker correction minus 8,290.0 8,321.0 14:09 14:21 8.5' 2/3/2019 2/3/2019 0.45 PROD1 WHPST TRIP P Continue IH, close EDC, PUW 41 k, 8,290.0 10,702.6 14:21 14:48 dry tag TOWS @ 10,700.5' 2/3/2019 2/3/2019 0.70 PRODi WHPST TRIP P PUH, perform static pressure survey 10,702.6 10,702.6 14:48 15:30 @ 10,693.25' CTMD, Sensor Depth 5,861.48' (TVD) 55 - ECD=11.31 ppg, AP=3,444, 00 - ECD=11.297 ppg, AP=3440 05 - ECD=11.294 ppg, AP=3439 10 - ECD=11.29, ppg, AP=3438 15 - ECD 11.287 ppg, AP=3437 20 - ECD 11.284 ppg, AP=3436 25 - ECD 11.280 ppg, AP=3,435 2/3/2019 2/3/2019 8.30 PRODi WHRPST WPST P PUH, obtain milling parameters, 1.9 10,702.6 10,708.0 15:30 23:48 bpm at 3,901 psi, Diff --321, WHP=19, IA=622, OA=482. Mill window per procedure 2/3/2019 2/4/2019 0.20 PROD1 WHPST WPST P 10708.0 Call BOW. Continue time 10,708.0 10,709.0 .23:48 00:00 milling to gel string reamer out Page 219 ReportPrinted: 3/8/2019 Operations Summary (with Timelog Depths) 3S-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start Time End Time Dur h ( r) phase 0 Cotle P Adiv Cotle aY Time P-T- X Operation Start Depth (Id(B) End Depth (flKB) 2/412019 2/4/2019 1.90 PROD1 WHPST WPST P Continue time milling to get stag 10,709.0 10,720.0 00:00 01:54 reamer out. 1.9 BPM @ 3900 PSI, BHP=3487 214/2019 2/412019 1.10 PROD1 WHPST WPST P TD Rathole. Geo reports formation in 10,720.0 10,680.0 01:54 03:00 sample. Perform 3 reaming passes. Motor work in first pass cleared up by third. 2/4/2019 2/4/2019 0.30 PROD1 WHPST WPST P Perform dry drift, Looks good. Tag TO 10,680.0 10,680.0 03:00 03:18 -Good. ream upon way out. 2/4/2019 2!4/2019 1.70 PROD1 WHPST TRIP P Window Complete, Open EDC and trip 10,680.0 63.7 03:18 05:00 out 2/4/2019 2/4/2019 1.30 PRODt WHPST PULD P At surface, PUD milling assembly, 63.7 0.0 05:00 06:18 mills gauged 2.79 no-go 2/4!2019 2/4/2019 1.50 PROD1 DRILL PULD P PD, Lateral drilling assembly 0.0 78.3 06:18 07:48 2/4/2019 2/412019 1.75 PROD1 DRILL TRIP P RIH, w/lateral drilling assembly BHA 78.3 8,270.0 07:48 09:33 #3, performing agitator surface test @ 443' 2/4/2019 2/4/2019 0.30 PROD1 DRILL DLOG P Log the K1 marker Correction of minus 8,270.0 8,337.6 09:33 09:51 10.5' 2/4/2019 2/4/2019 0.60 PROD1 DRILL TRIP P Continue IH, PUW 39 k 8,337.6 10,720.0 09:51 10:27 2/4/2019 2/4/2019 0.20 PROD1 DRILL DRLG P Tag bottom, PUH PUW 38 k, bring 10,720.0 10,724.0 10:27 10:39 pump up 1.88 bpm at 5,241 psi, Diff--1,784 psi, WHP=193, BHP=3,480, IA=676, OA=613 2/4/2019 2!4/2019 0.40 PR0D1 DRILL DRLG P PUW 39 k, restart 1.86 bpm at 4,530 10,724.0 10,775.0 10:39 11:03 psi, Diff=1,045, WHP=189, BHP=3,480, IA=692, OA=693 2/4/2019 2/4/2019 4.75 PROD1 DRILL DRLG P Stall motor, PUW 42 k, OBD 1.5 bpm 10,775.0 10,853.0 11:03 15:48 at 3,970 psi, Diff-11,350, WHP=187, BHP=3,495, IA=693, OA=694 "' Note: New mud at the bit 10,777' 2/4/2019 2/4/2019 2.35 PROD1 DRILL DRLG P OBD, 1.78 bpm at 4,745 psi, 10,853.0 10,928.0 15:48 18:09 Diff--1,580, WHP=175, BHP=3,497, IA=693, OA=695 2/4/2019 2/4/2019 0.15 PROD1 DRILL WPRT P Geo wiper up hole, PUW 38 k 10,928.0 10,860.0 18:09 18:18 2/4/2019 2!4/2019 0.10 PRODi DRILL WPRT P RBIH to drill ahead 10,860.0 10,928.0 18:18 18:24 2/4/2019 2/4/2019 0.30 PRODt DRILL DRLG P BOBD, 1.82 bpm at 4,775 psi, 10,928.0 10,952.0 18:24 18:42 Diff=1,555 psi, WHP=168, BHP=3,505, IA=704, OA=724 2/4/2019 2/4/2019 1.50 PROD1 DRILL DRLG P Stall Motor, PUW 49 k, BOBD, 1.78 10,952.0 10,992.0 18:42 20:12 bpm at 4,745 psi, Diff- 1,580, WHP=175, BHP=3,497, IA=693, OA=695 2/4/2019 04/2019 0.80 PROD1 DRILL DRLG P Stall Motor, PUW 49 It, 1.8 bpm at 10,992.0 11,012.0 20:12 21:00 4,956 psi, Diff=1,580 psi, WHP=138, BHP=3,500, IA=709, OA=733 2!4/2019 2/4/2019 1.50 TR-OD1115RILL DRLG P PUH, lower pump rate ( attempt to 11,012.0 11,051.0 21:00 22:30 drop in section) 1,5bpm at 3,880 psi, Diff=1,250 psi, WHP=224, BHP=3,504, IA=709, OA=733 2/4/2019 2/4/2019 0.60 PROD? DRILL WPRT P Plugged off returns, PUH, PUW 41 k, 11,051.0 11,000.0 22:30 23:06 line up to choke A, still plugged off, by- pass MM, able to get returns, line up to clean MM. 2/4/2019 2/4/2019 0.20 PROD1 DRILL WPRT P Blowdown of choke! micro motion 11,000.0 10,550.0 23:06 23:18ineffective. Pull up into cased hole 2/4/2019 2/5/2019 0.70 PROD1 DRILL WPRT P Work on micro motion, Pull out and 10,550.0 10,550.0 23:18 00:00 1 snake it. Full of metal shavings Page 319 Report Printed: 3/8/2019 Operations Summary (with Timelog Depths) 3S -O8 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log start De th Start Time End Time Our Phe % Op Catle Activity CoOe Time P -T-% Operation (WB) B) EM Depth (WB) 2/5/2019 215/2019 0.40 PROD1 DRILL WPRT P Pull up hole to log K1 10,550.0 8,300.0 00:00 00:24 2/5/2019 215/2019 0.20 PROM DRILL DLOG P Log KI for +5.5' 8,300.0 8,330.5 00:24 00:36 2/512019 2/5/2019 0.50 PROM DRILL WPRT P RBIH to tie in RA marker 8,330.5 10,720.0 00:36 01:06 2/5/2019 2/5/2019 0.10 PROM DRILL DLOG P Log RA@ 10709, TOWS=10702, 10,720.0 10,740.0 01:06 01:12 1 1 ITOW 10704', BOW=10708 2/5/2019 2/5/2019 0.30 PROD1 DRILL WPRT P Continue in hole, Seldown @ 10,850. 10,740.0 11,055.0 01:12 01:30 Pick up and go right in 2/5/2019 2/5/2019 1.20 PRODi DRILL DRLG P 11055', Drill, 1.8 BPM @ 4854 PSI FS, 11,055.0 11,140.0 01:30 02:42 BHP=3539, returns=1.74 BPM, RIW=10.1 K, DHWOB=3K 2/5/2019 21512019 0.10 PROD? DRILL WPRT P 11140', BHA wiper, PUW=41K 11,140.0 11,140.0 02:42 02:48 2/5/2019 21512019 0.50 PROD? DRILL DRLG P 11140', Drill 1.8 BPM @ 4776 PSI FS, 11,140.0 11,193.0 02:48 03:18 BHP=3512, RIW=10.8K, DHWOB=.5K. Hard to keep WOB at reduced ROP. 300LBS WOB @ 160 Ft/Hr 2/5/2019 215/2019 2.40 PROD1 DRILL DRLG P P/U lower flow rate to 1.65 for 100 11,193.0 11,460.0 03:18 05:42 Ft/Hr speed limit, 1.65 BPM @ 4192 PSI FS, BHP=3512, DHWOB 100 to 350LBS @ 115 FPH 2/5/2019 2/5/2019 0.70 PROD1 DRILL WPRT P 11,460', Wiper to window @ 1.9 BPM, 11,460.0 11,460.0 05:42 06:24 PUW=43K 2/5/2019 2/5/2019 1.60 PROM DRILL DRLG P 11460', Drill, 1.67 BPM @ 4200 PSI 11,460.0 11,629.0 06:24 08:00 FS, BHP=3530, ROP=100 FPH, DHW0B=100 to 400 Lbs 2/5/2019 2/5/2019 1.20 PROM DRILL DRLG P 11629', Unable to get build with no 11,629.0 11,731.0 08:00 09:12 WOB. Increase ROP to get WOB. DHWOB=400 LBS @ 180 FPH. Reduce rate further to 1.5 BPM to get needed build 215/2019 2/5/2019 2.60 PRODi DRILL DRLG P Increase rate back to 1.8 BPM @ 11,731.0 11,796.0 09:12 11:48 4520 PSI FS, BHP=3565 2/5/2019 215/2019 0.10 PROM DRILL WPRT P Pull BHA Wiper, PUW=44K 11,796.0 11,796.0 11:48 11:54 2/5/2019 2/5/2019 2.70 PROD1 DRILL DRLG P 11796', Drill, 1.8 BPM @ 4930 PSI FS, 11,796.0 11,860.0 11:54 14:36 BHP=3565, RIW=10.5K, DHWOB=.2K 2/5/2019 2/5/2019 0.90 PRODt DRILL WPRT P 11860', Wiper to window with tie in for 11,860.0 11,860.0 14:36 15:30 +3' 2/5/2019 2/512019 2.50 PROM DRILL DRLG P 11660', Drill, 1.82 BPM @ 4950 PSI 11,860.0 12,017.0 15:30 18:00 FS, BHP=3570, RIW=9.7K, DHWOB=2.7K, ROP= -30 FPH 21512019 2/5/2019 2.30 PROM DRILL DRLG P Drilling, 1.8 bpm, CWT= 11 K, WOB 12,017.0 12,260.0 18:00 2018 = AK (reduced WOB to maintain 100 fph), annular = 3599 psi, WHIP = 101 psi, circ = 4948 psi 2/512019 2/5/2019 0.30 PROD1 DRILL WPRT P Wiper up -hole, PUW = 43K 12,260.0 11,410.0 20:18 2036 215/2019 2/5/2019 0.40 PROD1 DRILL WPRT P Wiper in-hole, RM = 11.31K 11,410.0 12,260.0 20:36 21:00 2/5/2019 2/6/2019 3.00 PROD1 DRILL DRLG P Drilling, 1.8 bpm, CWT = 12,71K, WOB 12,260.0 12,443.0 21:00 00:00 = .81K, annular = 3608 psi, WHIP = 64 psi, dm = 5159 psi, pressure swings (possibly agitator, apparently since BHA went in-hole), transducer indicates agitator is working, elevated gamma (up to 172 API), though continued significant gloconite over shakers. Page 419 Report Printed: 3/8/2019 Operations Summary (with Timelog Depths) 3S-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time our inn Phase Op Code Activity Coe Time P-T-X Operation (MB) End Depth (UB) 2/6/2019 2/6/2019 2.00 PRODi DRILL DRLG P Drilling, 1.73 bpm, CWT = 8.81K, WOB 12,443.0 12,539.0 00:00 02:00 = 2.81K, annular = 3620 psi, WHIP = 110 psi, circ = 4749 psi, PU's to work through lower ROP intervals (one PUW @ 54K), no issues RIH 2/6/2019 2/6/2019 0.80 PROM DRILL DRLG P Drilling, 1.72 bpm, CWT = 1 OK, WOB 12,539.0 12,586.0 02:00 02:48 = .7K, annular= 3669 psi, WHIP = 99 psi 2/612019 2/6/2019 1.70 PRODt DRILL WPRT P Early wiper to allow geo's time to 12,586.0 8,282.0 02:48 04:30 evaluate, PUW = 44K, pump 5x5 sweeps, geo's believe low in section, complete wiper to tubing tail 2/6/2019 216/2019 0.20 PROD1 DRILL DLOG P Log K1 for+5' correction 8,282.0 8,335.0 04:30 04:42 2/6/2019 2/6/2019 1.40 PROD? DRILL WPRT P Wiper in-hole, Set down @ 11116 & 8,335.0 12,590.0 04:42 06:06 11123, Continue in 2/6/2019 2/6/2019 0.80 PROD? DRILL DRLG P 12590', Drill, 1.5BPM @ 4170 PSI FS, 12,590.0 12,708.0 06:06 06:54 BHP=3640. drilling low rate high ROP Ito get build 2/6/2019 2/6/2019 0.10 PRODi DRILL WPRT P PUH to get survey, PUW=42K 12,708.0 12,708.0 06:54 07:00 2/6/2019 2/612019 2.20 PROM DRILL DRLG P 12,708', Drill, 1.52 BPM @ 4265 PSI 12,708.0 12,816.0 07:00 09:12 FS, BHP=3715 2/6/2019 2/6/2019 0.70 PROD1 DRILL DRLG P 12816, Drop WHP 30 PSI from 150 to 12,816.0 12,849.0 09:12 09:54 120 PSI. Increase rate to 1,8 BPM. BHP=3710 2/612019 216/2019 0.90 PROD1 DRILL DRLG P 12849, Drop WHIP to 90 PSI, 12,849.0 12,877.0 09:54 10:48 BHP=3630, 1.79 BPM @ 5280 PSI FS 2/8/2019 2/6/2019 0.10 PROD1 DRILL WPRT P BHA wiper, PUW=47K 12,877.0 12,877.0 10:48 10:54 2/6/2019 2/6/2019 0.50 PROD1 DRILL DRLG P 12877', Drill, 1.8 BPM @ 5195 PSI 12,877.0 12,903.0 10:54 11:24 FS, BHP=3685 2/6/2019 2/6/2019 2.10 PRODi DRILL WPRT P 12903, Pull early wiper to sort out 12,903.0 10,689.0 11:24 13:30 hole, PUW=46K. Pull into 4 1/2 and jog / jet 2/6/2019 2/6/2019 0.60 PROM DRILL PRTS P Stop and obtain 30 min static, 10,689.0 10,689.0 13:30 14:06 BHP=3378 @ 5861 TVD sensor for 11.09 EMW, PUW=40K, 2/6/2019 2/612019 0.70 PROD1 DRILL WPRT P Run back in hole. Log RA for+6' 10,689.0 12,861.0 14:06 14:48 correction. clean trip down to 12861 2/6/2019 2/6/2019 1.30 PROD1 DRILL WPRT P Continue trying to get to bottom and 12,861.0 12,861.0 14:48 16:06 drill, Pick ups getting heavy with packing off. Unable to get past 12896' 2/6/2019 2/6/2019 1.40 PROD1 DRILL WPRT T Pump 5 X 5 sweeps go up and jog 4 12,861.0 8,290.0 16:06 17:30 1/2 to tubing tail 2/6/2019 216/2019 1.40 PROD1 DRILL WPRT T RBIH, pump 5x5 sweeps 8,290.0 12,500.0 17:30 18:54 2/6/2019 2/6/2019 2.80 PROD1 DRILL TRIP T POOH, pulled heavy (61 K) @ 11,162', 12,500.0 78.0 18:54 21:42 run back though area up & down, clean, open EDC, PJSM **Pre-load PDL w/ BHA #4 2/6/2019 2/6/2019 1.30 PROD1 STK PULD T PUD BHA#3 (new Floor hand), bit 78.0 0.0 21:42 23:00 came out a 5-5 (tracking down model number as not legible on bit) 2/6/2019 2/7/2019 1.00 PRODt STK PULD T Begin PD BHA #4 Anchored Billet 0.0 0.0 23:00 00:00 1 1 1 Assembly 2/7/2019 2/7/2019 0.60 PRODt STK PULD T Complete PD BHA 94 Anchored Billet, 0.0 73.0 00:00 00:36 slide in cart, UT coil (thinnest check pack-offs, MU to coil, tag up, set counters, EDC open Page 519 Report Printed: 3/812019 Operations Summary (with Timelog Depths) 3S-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Tune End Time Dur (hr) Phase Op CWe Actively Cade Time P -T -X Operation (WB) End Depth (W) 2/7/2019 2/7/2019 1.70 PROD1 STK TRIP T RIH w/ BHA #4, EDC open 73.0 8,300.0 00:36 02:18 2/7/2019 2/7/2019 0.10 PRODt STK DLOG T Log Kt for -7.5' correction 8,300.0 8,337.0 02:18 02:24 2/7/2019 2/7/2019 1.20 PROD1 STK TRIP T Close EDC, PUW = 39K, continue 8,337.0 12,041.8 0224 03:36 RIH, arrive at setting depth, bring up pumps, shear off at 4700 psi, set down 3.71K WOB, TOB = -12,0301, oriented 150' ROHS 2/7/2019 2/7/2019 2.60 FROM STK TRIP T POOH, took -15 bbl lower denstiy 12,041.8 61.0 03:36 06:12 mud to tiger tank "PDL pre -loaded 2/72019 2/7/2019 1.30 FROM STK PULD T Tag up and space out. PJSM PUD 61.0 0.0 06:12 07:30 BHA #4 Billet setting BHA 2/7/2019 2/7/2019 0.90 PROM STK PULD T PD BHA#5 with 1.2'AKO motor to 0.0 78.3 07:30 08:24 kick off billet and drill turn section 2/7/2019 2/7/2019 1.30 PROM STK TRIP T RIH, BHA #5, Test agitator @ 445', 78.3 8,300.0 08:24 09:42 Continue in 2/7/2019 2/7/2019 0.10 PROM STK DLOG T Log K1 for -7.5', 8,300.0 8,333.0 09:42 09:48 2/7/2019 2/72019 1.10 PROD1 STK TRIP T Continue in well. Pull wt check @ 8,333.0 12,028.5 09:48 10:54 10650 38K, Continue in. Dry tag billet @ 12029.5 2172019 2/7/2019 1.50 PRODi STK KOST T 12028.5 start milling, 1.81 BPM @ 12,028.5 12,030.4 10:54 12:24 4720 PSi FS, BHP=3670. Time mill 1 FPH 2/7/2019 2/7/2019 1.20 PROD1 STK KOST T 12030.4. Start pushing, Drill ahead 12,030.4 12,084.0 12:24 13:36 11.81 BPM @ 4720 PSI FS, BHP=3590 217/2019 2/7/2019 0.20 PRODt DRILL WPRT T Wiper trip to 12,000'. Drift billet area - 12,084.0 12,084.0 13:36 13:48 Good 2/7/2019 2/7/2019 0.30 PROD1 DRILL DRLG T 12084', Drill, 1.56 BPM @ 3945 PSI 12,084.0 12,130.0 13:48 14:06 FS 2/72019 2/72019 0.10 PROD1 DRILL WPRT T 12130 Pull DO wiper. PUW=42K 12,130.0 12,130.0 14:06 14:12 2r72019 2!72019 0.90 PROM DRILL DRLG T 12130', Drill 1.51 BPM @ 3910 PSI 12,130.0 12,205.0 14:12 15:06 FS, BHP=3635 2/72019 2/7/2019 0.10 FROM DRILL WPRT T 12205', BHA Wiper, PUW=41K 12,205.0 12,205.0 15:06 15:12 2/7/2019 2/7/2019 1.80 PROM DRILL DRLG T 12205', Drill, 1.5 BPM @ 3900 PSI 12,205.0 12,255.0 15:12 17:00 FS, BHP=3625 Found ankorite 2/7/2019 2/7/2019 3.60 PROM DRILL TRIP T 12255, Call end of turn. Trip for lateral 12,255.0 78.0 17:00 20:36 BHA, PUW=42K, jog 4-1/2" 2/7/2019 2/7/2019 0.90 PRODt DRILL PULD T PJSM, PUD BHA #5, bit came out 5-3 78.0 0.0 20:36 21:30 2/7/2019 2/7/2019 1.20 PROM DRILL PULD T PD BHA#6 Lateral Assembly (NOV 0.0 78.0 21:30 22:42 Agitator, 0.5° AKO motor, RB HCC P104 bit), slide in cart, check pack - offs, MU to coil, tag up, set counters Crew change, PJSM 2/7/2019 2/8/2019 1.30 PROM DRILL TRIP T Begin RIH w/ BHA #6 78.0 5,935.0 22:42 00:00 2/8/2019 2/8/2019 0.50 PROM DRILL TRIP T Continue RIH w/ BHA #6 5,935.0 8,300.0 00:00 00:30 2/8/2019 2/8/2019 0.10 PROM DRILL DLOG T Log K1 for -8.5' correction 8,300.0 8,344.0 00:30 00:36 2/8/2019 2/8/2019 1.30 FROM DRILL TRIP T Continue RIH, window PUW = 39K, 8,344.0 12,255.0 00:36 01:54 stack 4.51K at 10,863', PUW = 39K, get by on 3rd attempt (reduced rate & adjust TF 10°, bring rale back up once through) Page 6/9 Report Printed: 3/812019 Operations Summary (with Timelog Depths) 3S-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stent Depth Start Time End Time Dw inn Phase Op Cade Activay Coce Time P -T -X Operation (W8) End Depth (IIKa) 2/8/2019 2/8/2019 2.10 PROD1 DRILL DRLG T Drilling, FS = 1020 psi @ 1.85 bpm, 12,255.0 12,475.0 01:54 04:00 CWT =11 K, WOB=0.2K, annular= 3704 psi, WH = 61 psi, circ = 4572 psi, new mud at bit 12,265', control drilling 100 fph "Man -down drill 2/8/2019 2/8/2019 2.10 PROD1 DRILL DRLG T Drilling, CWT =10K, WOB=0.3K, 12,475.0 12,660.0 04:00 06:06 annular = 3647 psi, WHIP = 153 psi, circ = 4327 psi 2/8/2019 2/8/2019 0.30 PROD1 DRILL WPRT T 12660', Wiper to 12,050, PUW=42K 12,660.0 12,660.0 06:06 06:24 2/8/2019 2/8/2019 1.40 PROD1 DRILL DRLG T 12660', Drill 1.82 BPM @ 4352 PSI 12,660.0 12,797.0 06:24 07:48 FS, BHP=3660 2/8/2019 218/2019 0.10 PROD1 DRILL WPRT T 12797, PUH losing returns, Consult 12,797.0 12,797.0 07:48 07:54 with town. Now we are going 1 for 1 218/2019 2/8/2019 1.20 PROD1 DRILL DRLG T 12797', Drill, 1.6 BPM @ 3610 PSI 12,797.0 12,858.0 07:54 09:06 FS, BHP=3615 2/8/2019 2/8/2019 0.15 PROD1 DRILL WPRT T BHA wiper up hole, PUW 43 k 12,858.0 12,858.0 09:06 09:15 2/8/2019 2/8/2019 1.50 PROD1 DRILL DRLG T BOBD 1.62 bpm at 3,850 psi, Diff --950 12,858.0 12,903.0 09:15 10:45 psi, WHP=73, BHP=3,650, IA=720, OA=658 2/8/2019 2/8/2019 0.85 PROD1 DRILL DRLG P BOBD 1.62 bpm at 3,850 psi, Diff=950 12,903.0 12,919.0 10:45 11:36 psi, WHP=73, BHP=3,650, IA=720, OA=658 2/8/2019 2/812019 0.15 PROD1 DRILL WPRT P BHA, wiper up hole, PUW 43 k 12,919.0 12,919.0 11:36 11:45 2/8/2019 2/812019 3.75 PROD1 DRILL DRLG P BOBO, 1.8 bpm at 4,530 psi, 12,919.0 12,958.0 11:45 15:30 Diff --1,050, WHP=78, BHP=3,650, IA=729, OA=656 2/812019 2/8/2019 0.30 PROD1 DRILL CIRC P PUH, launch 5x5 sweep, 12,958.0 12,958.0 15:30 15:48 218/2019 2/8/2019 1.50 PROD1 DRILL WPRT P Wiper to the tubing tail, PUW 41, 12,958.0 8,300.0 15:48 17:18 circulate bottoms up 21812019 2/8/2019 0.80 PROD1 DRILL DLOG P Log Kt for+5' correction, RBIH to 8,300.0 10,651.0 17:18 18:06 window 2/8/2019 2/8/2019 0.60 PRODi DRILL DLOG P Obtain SBHP, shut-in choke, shut 10,651.0 10,651.0 18:06 18:42 down pumps SBHP: MD_bit= 10651.9', TVD -Sensor = 5861.8', annular = 3368 psi, EMW = 11.06 ppg 2/8/2019 2/8/2019 0.80 PROD1 DRILL TRIP P RBIH to TD, pump sweeps, begin 10,651.0 12,958.0 18:42 19:30 stacking weight at -12,900' pushing to bottom, unable to work past 12,948', call official TD 12,958' w/correction. 2/8/2019 2/8/2019 2.60 PROD1 DRILL WPRT P Wiper to swab valve, partial pack -off 12,958.0 78.0 19:30 22:06 waiting for sweeps to exit bit, clears up 2/8/2019 2/8/2019 1.70 PROD1 DRILL TRIP P RBIH 78.0 8,300.0 22:06 23:48 21812019 2/9/2019 0.20 PRODi DRILL DLOG P Log K1 for -3.5' Correction 8,300.0 8,337.0 23:48 00:00 2/9/2019 2/9/2019 0.30 PROD1 DRILL TRIP P RIH to window 8,337.0 10,650.0 00:00 00:18 219/2019 219/2019 2.00 PROD1 DRILL WAIT P Wait on KWF to rig (phase 2 10,650.0 10,650.0 00:18 02:18 conditions), KWF arrives 2/92019 219/2019 2.90 PROD1 DRILL OTHR P Off-load fluid, build LRP, RIH to 10,650.0 12,887.0 02:18 05:12 j j 12,900', stack weight at 12,887'. PUH w/ significant motor -work Page 719 Report Printed: 31812019 Operations Summary (with Timelog Depths) 3S-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log star) Time EM Time our (hr) Phase Op Co's Actively CMe Time P-T-X Operation Start Depth (ftKa) End Depth (RKe) 2/9/2019 2/912019 3.50 FROM DRILL DISP P Lay in LRP (from 12,850) & KWF to 12,887.0 78.0 05:12 08:42 surface, beads up to 9,500', continue POOH 2/9/2019 2/9/2019 0.50 PROD1 DRILL FUULD P At surface check well for flow, PJSM 78.0 78.0 08:42 09:12 for laying down tools 219/2019 2/9/2019 0.25 PRODi DRILL PULD P LD drilling BHA on a dead well, 78.0 0.0 09:12 09:27 inspect CT above CTC, (4.0' up from tree end 0.118") 2/9/2019 21912019 0.40 COMPZ1 CASING PUTB P Prep RF for Liner Ops, PJSM 0.0 0.0 09:27 09:51 2/9/2019 2/9/2019 2.90 COMPZI CASING PUTS P PU/MU Liner segment#1 0.0 1,034.0 09:51 12:45 2/9/2019 2/9/2019 0.70 COMPZ1 CASING PULD P PU/MU BHI CoilTrak tools 1,034.0 1,078.1 12:45 13:27 2/9/2019 2/9/2019 1.75 COMPZI CASING RUNL P RIH, Liner BHA#7 w/36 iris of slotted 1,078.1 9,300.0 13:27 15:12 liner, shorty deployment sleeve, and non-ported bullnose. 2/9/2019 2/9/2019 0.20 COMPZI CASING RUNL P Log the K1 marker correction of minus 9,300.0 9,340.0 15:12 15:24 9.0', 2/9/2019 219/2019 1.00 COMPZI CASING RUNL P Continue RIH, PUW 38 k, 9,340.0 12,918.0 15:24 16:24 DHWOB=3.2 k, set down 12,918', PUW 48 k, RBIH, set down 3.0 k, 2/9/2019 2/912019 0.50 C0MPZ1 CASING RUNL P Bring pump online 1.5 bpm, Diff--1,113 12,918.0 11,866.5 16:24 16:54 psi, PUW 38 k, remove liner length from BHA 2/9/2019 2/9/2019 2.10 COMPZI CASING TRIP P PUH to log the RA marker for no 11,866.5 43.0 16:54 19:00 correction, continue POOH, PJSM, check well for flow 2/9/2019 2/9/2019 0.70 C0MPZ1 CASING PULD P PUD BHA#7 43.0 0.0 19:00 19:42 2/9/2019 219/2019 0.50 COMPZI CASING BOPS P Suck out stack, perform function test 0.0 0.0 19:42 20:12 1 2/912019 2/9/2019 3.00 COMPZ1 CASING PUTB P Clear floor, PJSM, PU Liner Run #2 0.0 1,200.0 20:12 23:12 (ported BN, slotted, swell packer, nipple, slotted, & shorty) 2/9/2019 2/10/2019 0.80 COMPZI CASING PULD P PU BHA #8 liner running tools 1,200.0 1,240.0 23:12 00:00 1 2/10/2019 2/10/2019 1.50 COMPZI CASING RUNL P RIH w/ BHA #8 Liner Run #8 1,240.0 9,475.0 00:00 01:30 211012019 2/10!2019 0.10 comP21 CASING DLOG P Log K1 for-9.5' 9,475.0 9,502.0 01:30 01:36 2/10/2019 2110/2019 1.00 COMPZI CASING RUNL P Continue RIH, 0' correction to window 9,502.0 10,689.0 01:36 02:36 flag, PUW = 39K, continue RIH to set depth, PUW = 41 K, release off liner, PUW = 37K, TOL - 10,689' 2/10/2019 2/1012019 2.50 DEMOB WHDBOP DISP P Displace well to seawater 10,689.0 4,065.0 02:36 05:06 2/10/2019 2/10/2019 2.00 DEMOB WHDBOP FRZP P Freeze protect from 2500' to surface 4,065.0 45.0 05:06 07:06 2/10/2019 2/10/2019 1.22 DEMOB WHDBOP PULD P PJSM, PUD/LD setting tools 45.0 0.0 07:06 08:19 "• Note: FTP 1,000 psi SBHP: MD_bit = 10651.9'. TVD sensor = 5861.8', annular= 3368 psi, EMW = 11.06 ppg Page 8/9 Report Printed: 3/8/2019 Operations Summary (with Timelog Depths) 3S-08 Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Stan Time End Time Dur(hn Phase Op Cede Activity Code Time P-T-X Operation Stan Depth ntKB) End Depth(nKB) 2/10/2019 2/10/2019 2.18 DEMOB WHDBOP CIRC P Displace coil to Drilling fluid for testing 0.0 0.0 08:19 10:30 NS release tool, obtain baseline parameters, unstab INJH, MU release tool, obtain parameters, test tool (good -test), unstab INJH, dogs had retracted, tool functioned properly. 2 bpm/30min/4,700 psi/Diff=1,630 psi 2 bpm/5 min/1,250 psi choke/5,400 psi/Diff=1,850 psi 2.25 bpm/5 min/1,250 psi choke/5,350 psi/Diff=1,900 psi 2.5 bpm/5 min/1,250 psi choke/5,520 psi/Diff=2,200 psi 2/10/2019 2/10/2019 0.30 DEMOB WHDBOP DISP P Displace coil to SW @ 2.5 bpm at 0.0 0.0 10:30 1048 4,443 psi 2/10/2019 2/10/2019 1.00 DEMOB WHDBOP RURD P MU Nozzle, stab INJH, jet stack and 0.0 0.0 10:48 11:48 surface lines, unstab remove nozzle, remove BHI UQ Float Valves, install coil clamp, slide cart back and secure for Rig move. 2/10/2019 2/10/2019 4.70 DEMOB WHDBOP RURD P Work on RD checklist, notify DTH 0.0 0.0 11:48 1630 release tiger tank and hard line, remove and clean pits, 2/10/2019 2/10/2019 0.50 DEMOB WHDBOP RURD P Freeze protect well head, Nipple down 0.0 0.0 16:30 17:00 stack Note: Rig Release @ 17:00......... Page 9/9 Report Printed: 3/8/2019 THE STATE °fALASKA GOVERNOR MIKE. DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3S -08C Permit to Drill Number: 207-163 Sundry Number: 319-016 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a ogc c. a to s ka.gov Enclosed is the approved application for the 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, Daniel T. S ount, Jr. Commissioner ,9 DATED this g day f January, 2019. RBprpS 'aN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED JAN 16 2019 ; ,QQQ�, 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: CO261 B Whipstock ❑� . 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development Q Stratigraphic Service El❑ 207-163 3. Address: 6. API Number: PO Box 100360, Anchorage, AK 99510 50-103-20450-03-00 0` 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 3S -08C Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10, Field/Pool(s): ADL 380107 Ku aruk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12055' 5872' 12055' 5872' 3870 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 75' 16" 108' 108' Surface 4234' 9-5/8" 4263' 2661' Intermediate 8768' 7" 18795' 5848' Liner 3867' 4-1/2" 1 12055' 5872' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8750'- 8790' 5843'- 5847' 11 pert pups 9322' - 12001' 5843'- 5870' 3-1/2" L-80 8237' Packers and SSSV Type: HRD ZXP Packer Packers and SSSV MD (ft) and TVD (ft): 8188'/ 5742' Carrico "DS" Nipple 502'/ 500' 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: 28 -Jan -19 OIL WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger Contact Name: Keith Herring Authorized Title: Staff TD Engineer Contact Email: Keith. E. Herrin COP. com ///-// Contact Phone: 907-263-4321 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: /✓` U II.FP'f Plug Integrity ❑ BOP Test D Mechanical Integrity Test ❑ Location Clearance ❑ Other: 270P ft,$ y -t-0dz 00P,51 z. YY%il�tvr-�il2r orf✓fv7 �r� �r5�� fa Post Initial Injection MIT Req'd? Yes ❑ No P�'IAN 2 2 2019 RBDMS Spacing Exception Required? Yes [:]No [jrSubsequent Form Required: Approved b COMMISSIONER THE COMMISSION ez��L APPROVED BY f �/ Date: V`/ 6 y1/d// y /� n /�� AA'' (b If. 10-403 Revised 4/2017 Approved VII \it Giir1lpl� nths from the date of approval. � � I ` l� I IID ��11111 lli��lll Submit Form and AA,�f as hmems in Duplicate CAS �•�.BAt�rs'r9 !1a ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 14, 2018 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits sundry application to set a whipstock and applications for permits to drill one lateral out of the KRU 3S -08C (PTD# 207-163) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in late January 2019. The objective will be to drill one lateral KRU 3S- 08CL1 targeting the Kuparuk C -sand interval. Attached to the sundry application are the following documents: - 10403 Sundry Application for KRU 3S -08C - Operations Summary in support of the 10403 sundry application - Proposed CTD Schematic - Current Wellbore Schematic Attached to permit to drill applications are the following documents: - Permit to Drill Application Forms (10401) for 3S-08CL1 - Detailed Summary of Operations - Directional Plans for 3S-08CL1 - Proposed CTD schematic - Current Wellbore Schematic If you have any questions or require additional information, please contact me at 907-263-4321. Sincer�ely� Keith Herring Coiled Tubing Drilling Engineer ConocoPhillips Alaska KRU 3S -08C (PTD #207-163) CTD Summary for Sundry Summary of Operations: KRU well 3S -08C is a Kuparuk C sand producer equipped with 3-1/2" tubing, 7" intermediate casing, and 4- 1/2" production liner. The CTD sidetrack will utilize a single lateral to target the C -sands to the northwest of 3S -08C. The lateral will increase C -sand resource recovery on sand trend edge. Prior to CTD operations slickline will change out the gas lift valves and service coil will conduct a dummy whipstock drift. Nabors CDR3-AC will run and set a whipstock at 10,700' MD. The whipstock will be utilized to cut a window in the 4-1/2" liner and drill a single lateral. CTD Drill and Complete 3S-08CL1 Lateral• Pre -CTD Work 1. RU Slickline: Change out GLV's. 2. RU Service Coil: Conduct dummy whipstock drift. 3. Prep site for Nabors CDR3-AC. Rig Work I. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 3S-08CL1 Lateral a. Set top of whipstock at 10700' MD. b. Mill 2.80" window at 10700' MD r c. Drill 3" bi-center lateral to TD of 13525' MD. d. Run 2-3/8" blank and slotted liner with a swell packer back into the 3-1/2" tubing. 3. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. Post -Rig Work 1. Return to production Page 1 of 1 1/14/2019 KUP PROD 3S-08C r- DL Well Attributes Wn«Or'r IIIIIFiS - M'. Arg.I K MD TD wellwre AP6uGI Flea rvame walbera s.lua nal r) Mpinxe) Ad eMm lnKe) Naska, Inc. SIN GIAA5003 KUPARUK RIVFR 11Nrt Donn ... .-. .. ._ _. Pop QONi/LL-38{BC.5I13/d11985a:L5gM -- Last Tag l/LIILUUtl arpca emeun ac ...... Ng6G5R Sae pnnoWlon Last Tag: CTU- DeWh MK61 l4.i spy, By 9 RKB 12055.0 d12J2010 ppmven Last Rev Reason Mngl&thin Fine pale Ladory Rev Reason'.Installed New Gas Lin Design S Pulled CSV 5/1212010 ze5 do Casing Strings CONDUCTOR: Aro-1..0 NIPPLE, 502.1 Cain g peacnplion OR (In) I0 pn) Top INKBI Sel Oepin I.,Rf &el peplF IN0... WOLen (I .'.'eTop TM1reaa CONDUCTOR 16 15062 330 1080 108.0 62.50 H-40 WELDED Caging peutlpllon ODpn) ID pin) Top(flKa) SN qPM IXKB) 9N peplM1 lrvpl... Wtllm p.., GrNe TopLDED SURFACThnsed E 9518 869] 28.] 4,263.0 2.661.1 4000 L40 BTCM Caging peggriplion of fico TO (7d) TOP,_ Bel-----lXl{eI &M INTERMEDIATE DePIM1 ITvp)... W!Lm 11... Grgea Top Tnraee 7 6.2]6 25.5 8,)950 584]] 26.40 L-80 Casing Nn-plion Whin) ff(uO TUp (XKO) SN Ded 10KOj $el 0901E (Npf... WII L¢n p... Grade iop Thread! Pp LINER 41/2 3.958 3,1663 12055.0 1260 L80 IBTMOD SURFACE: 2674.26110 Liner Details OgsuFi:4,5ass Top lnx8) TOP (rvp)InKa) Top mol l°) Item Da Com 0,188.2 5.742.2 65.23 PACKER 5"x7"'HRO'2XPLinP,Cp P"/t0.MCAM NOMFna'ID TOL==- 5.250 8,2088 5.748.0 66,97 NIPPLE "RS'PackoRseal nipplep w?KCcouplin8s(557" 4,250 Gqs uFT; s.>n.e OD) 8,2108 5,]512 87.32 HANGER 5"x]"Fex-LockLine,Hgl(598'ODxd.d2'ID) 0420 8,220,5 5,7550 88.24 SBE 80-40 5' Seal Bore Ext, w)]KC coupling (Max OD 4.000 560" x 4" ID) 1 GAB LIFi:6.ea8a 8,240.6 5,762.1 6993 XODUSHING XOBvelPOK5"BTC x41/2"IBT (M1Nx Op 5.6) 3950 Tubing Strings GASLRT:7am1 TUBING acriplbn Ming Ma,,.Ic inl Top INK.) SH OepIM1 IN., Bel Depth (iVD)I.. WI IG/X) Grape iop ConnMion TUBING 312 2.992 22.0 8,2316 5,)60.9 9.30 L00 EUE BrbMod Completion Details OASLI"R MA Top (Np) Top Incl Toppers) initB) P) Ibm On Com 228 228 0.00 HANGER FMC 3.5"Gen VTbg Hanger EUE BNBpup (Hgf Ngminal ID llnl JS'-Pup865) 1 2.992 502.1 SOOA 9.39 NWPLE 3.5"Gemco"DS"Nipple w2.e)5"NOGG praIe EUE BN -M 2.8]5 NmpLE e.ma.a 8,1364 5,7414 65.0] NIPPLE 3.5"Cameo"OS"Nipple wl2812'NOGG P.N. EUE 8 NAM 2.612 8,195.6 5745.2 6592 LOCATOR 5"LOcator-.ub 2592 LOCATOR; x1555 0.225.5 5,)56.8 6070 SEAL ASSY 00-0O Bontletl Sealassembly 3060 Perforations &Slob sM1ot aEPLgSSI; B.Y6,5 opotil Tsl`WK) al0.79DB) Top (Oft Box -) p1I(B) ZOng ONe D ng IgM1OWX ) Type Co. 8,]50.0 8]800 5,84 5,8439 5,847.3 Gd, 35 -OBC 9132009 6.0 APERF 2.5"HES Mlearlem gun, 00 deg ph 9,3220 9,328.0 5,843,5 5.8433 C -0,3S -OBC 11192008 1.0 PERFP PeR Pups al 1oles perpup 9.543,0 9,548.0 5.846.8 5.847.0 04,3S -GSC 111WOOp8 1.0 PERFP Ped Pups w/six V2'leas perpup APa1P: 9.750.ae.7900� 10,011.0 10,018.0 5,868.5 5,868.5 Gd, 35408C 1/19/2008 10 PERFP Pert PUpswlalx l2"bales perpup INTERMEDNTE: M 58,7850 10,171,0 10,1770 5,8646 5,864A C-0, 3S -OBC trial 10 PERFP Pell Pupaw/six 12"holes perpup - - PERFP;93ZL0.9.320.0 . jIII 10.363.0 10.368.0 5.862.7 5.862.8 G4,3S08C 111912606 10 PERFP Pell Pups w/six 12'noles per pup - 10,624.0 10,528.0 5,0819 5,861,9 G4, M -08C 1/19,2000 10 PERFP PeR Pups we"l2"holes _ parpup PERFP:S.Sad.a5.5w.0� - 10,]15.0 10,]20.D 5.860.3 5.8502 C-0, 3S -GBG Vial 1.0 PERFP Pall Pupsw/six 12'noles i- pefpup 10.887.0 1,0020 5.863.1 5,863.6 C -4,3S -08C 11192000 10 PERFP Pelf Pupa w/sM12"holes perpup PERFP; 100110g00160� - 11,3ID.0 11,315.0 7,BB0.5 5,880.5 Gd, 3S-0BC 1/192008 10 PERFP Pe POPswlalxl2 holes perpup atiaw.O.R.3220 _ �- 11,5240 11,530.0 5,855.9 5.8558 C-0. 3S-OBG 1/192008 1.0 PERFP PeR Pups al 12"holes PERFPaO.IT rvlp.tn.6- perpup 119970 12.001.0 5.869.6 5.869.81C -4.3S -08C 111912000 10 PERFP PeRPupaw/six 12" holes perpup StimuNJ he& teatmellb PERFP;l03M0-IOWO- Proppanl DegignN ilio/ Prop1un11n Formallon ilio/ pate 5/142009 Sbinuiations & Treatments _ PERFP.105246105280� Stp% Top INKBIOIm INKa) 9,322.0 11.000.0 pa@ 51412609 VOI Blim/Trpn[Fluitl Clean Pump (I Vol Blurry 1666 - - Mandrel Inserts PERFBIO..715a10.Nrl_ 81 an PFRFP;10,,397011,0]2.Y� _ - - 1 N iOp,TUp) Valve lath PoR&iss TRO Top IXKB) IXKa) Make MotlH OD pin) &ery Type Type (Inl Run (pgB Run Dat Co. 4568.9 2.811 CAMCG MG 1112 Gas lin DMY RK 0.000 0.0 41MCQR I-2 5.7739 3,)01.8 GAMCO MMG 11/2 Gas Lin G V RK 11250 1,553.0 /122018 PERFF:11amYA1,3150 3 6,6456 4505.3 CAMCG MMG 112 IS UR End RK 1 0.0001 On I 1202008 - I- 4 7360.4 5,1468 CALICO MMG 1112 Gas LiR OV RK 0.250 0.0 51121201 5 8.138.1 5,7193 CAMCO MMG 1112 Gas Lifl OV 0.000 0.0 5/122010 See NOTE PERFP11524.0-11.5300- $ - - Notes: General As Safety End to Annoannn 1212008 NOTE: WELL SIDETRACKED 121/2008 PERFP: It she 012.01 �- 112212008 NOTE ^'WARNING^'LINER TOP PgCKER IN IA -DO NOT EXCEED 3000 psi 101d20OB NOTE: VIEW SCHEMATIC wIAlaska SchertMlic8.0 UNER:8 Roar -12.055.0 16" 62# H-40 shoe @106'MID 9-5/8" 40# L-80 shoe @ 4263' MD 3S -08C Proposed CTD Schematic 3-1/2" Camco DS Nipple @ 502' RKB (2.875" ID) 3-1/2" 9.3# L-80 EUE 8rd Tubing from surface to 8237' RKB 3-1/2" Camco KBMG gas lift mandrels @ 4589', 5774', 6646', 7360', & 8138' RKB 3-1/2" Camco DS Nipple @ 8186' RKB (2.612" ID) 4-1/2" 12.6# L-80 EUE 8rd Tubing from 8188 to 12055' RKB 5" locator sub @ 8196' RKB Liner top Baker 5" z 7" ZXP liner top packer @ 8188' RKB Baker 5" x 7" Flex -Lock liner hanger @ 8211' RKB Baker 80-00 SBE @ 8221' RKB XO Bushing @ 8241' RKB 7" 26.4# L-80 shoe @ 8795' MD KOP 0 10 700' MD I 4-1 /2" 12.6# L-80 shoe Perf Pups w/ qty. 6 - 1/2" holes @ 12,055' RKB Solid Liner- Ni le Profile -Solid Liner -Swell Packer 3S-08CL1 wp01 TD @ 13,525' MD Page 1 of 3 Maunder, Thomas E (DOA) From: NSK Prod Engr Specialist [n1139 @conocophillips.com] Sent: Thursday, January 27, 2011 9:09 AM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); Colombie, Jody J (DOA); NSK Prod Engr & Optimization Supv; NSK Fieldwide Operations Supt; Bradley, Stephen D Subject: FW: RE: Request for Approval a (T Attachments: Kuparuk Gas Injector Flow back Volumes.xls Tom, Attached you will find the Kuparuk Gas Injector Flowback information per your request. Bob Christensen / Darrell Humphrey NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. y�,�� Kuparuk Office: 907.659.7535 t . '? F = FEB 8 all Kuparuk Pager: 659.7000; #924 CPAI Internal Mail: NSK -69 This email may contain confidential information. If you receive this e-mail in error @lease notify the sender and delete this email immediately. From: Maunder, Thomas E (DOA) [ mailto :tom.maunder(aalaska.gov1 Sent: Tuesday, January 25, 2011 9:09 AM To: NSK Prod Engr & Optimization Supv Subject: RE: Request for Approval Gary/Denise, Following up on my brief conversation with Gary the other day, could one of you provide some information with regard to the flowback of these WAG injectors while TAPS was unavailable. Please copy everyoned as before with your response. Thanks in advance, Tom Maunder, PE AOGCC t From: Maunder, Thomas E (DOA) Sent: Tuesday, January 11, 2011 9:59 AM To: 'NSK Prod Engr & Optimization Supv' Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist; Colombie, Jody J (DOA) Subject: RE: Request for Approval Gary, et al, I have spoken with Commissioner Foerster and she has given her approval to proceed with the planned flowback of the listed wells as described. Volumes should be tracked /recorded as planned. At this time it is not necessary to submit Form 10 -403 for the wells. Form 10 -404 will likely need to be submitted for each well following the conclusion of this extraordinary situation. Gas disposition will also need to be reported. I will place a copy of this message in the well files. Please keep us advised of the situation. Call or message with any questions. 1/27/2011 Page 2 of 3 Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [mailto :n2046 ©conoc phillips.com] Sent: Monday, January 10, 2011 4:44 PM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist Subject: RE: Request for Approval Tom, my estimate is that we could need this as early as tomorrow morning /afternoon. Pilots will be calibrated to meet the 25% flowing tubing pressure rule. Thanks for the timely response. Gary Gar Tar Y ac 9 NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 From: Maunder, Thomas E (DOA) [mailto_tom.maunder @alaska.go j Sent: Monday, January 10, 2011 4:38 PM To: NSK Prod Engr & Optimization Supv Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA) Subject: RE: Request for Approval Gary, I acknowledge your request. Do you have any best estimate of when this could be needed? Will there be any modification of the pilot settings on the "new producers "? Sundries will not be necessary. Having to ability to test is appropriate for allocation purposes. I have copied this to my colleagues so they may make necessary assessments. I do not have the authority for this approval, but based on responses to others, the AOGCC will work with you to make the appropriate decisions. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [ mailto_n2046 ©conocophillps.coml Sent: Monday, January 10, 2011 4:29 PM To: Maunder, Thomas E (DOA) Cc: NSK Prod Engr Specialist; CPF2 Prod Engrs; CPF3 Prod Engrs; NSK Fieldwide Operations Supt; CPF1 &2 Ops Supt; CPF3 Ops & DOT Pipelines Supt; Bradley, Stephen D 1/27/2011 Page 3 of 3 Subject: Request for Approval Importance: High Tom, GKA is requesting AOGCC approval to initiate WAG injector flowbacks at Kuparuk if needed to maintain an adequate fuel gas for our turbo - machinery due to the current TAPS proration. Doing so should help ensure that we maintain life support and safety systems at each facility. At this time, it is unclear if this will become necessary as the repair status at Pump Station #1 is still evolving. As part of our planning contingency, GKA is currently configuring the 5 WAG injectors (listed below) for flowback to production via adjacent shut -in producers. The duration of the flowbacks would be directly tied to the length of the TAPS proration. This will be accomplished by hard -line connections between the Gas Injector to an adjacent shut -in producer via tree cap connections. Each well will be equipped with functional SVS which will be capable to shut -in the gas production in the event of a failure and we are in the process of completing a PHA for each of these installations. All injectors will have well testing capabilities for allocation purposes. ■lowback Adjacent Estimated Prod - ;as Injector PTD# SI Producer PTD# (Mscfd) X-420 201 -182 2P -422A 202 -067 4,500 a;P -447 203 -154 2P -448A 202 -005 2,000 2,U -03 185 -006 2U -02 185 -005 3,500 `5S -09 202 -205 3S -08C 207 -163 7,500 3S -26 201 -040 3S -24A 204 -061 6,500 24,000 Please let me know if the AOGCC approves of this plan in the event we have to implement it during non -office hours. Regards, Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 1/27/2011 • • Page 2 of Gary, I acknowledge your request. Do you have any best estimate of when this could be needed? Will there be any modification of the pilot settings on the "new producers "? Sundries will not be necessary. Having to ability to test is appropriate for allocation purposes. I have copied this to my colleagues so they may make necessary assessments. I do not have the authority for this approval, but based on responses to others, the AOGCC will work with you to make the appropriate decisions. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [ mailto :n2046 @conocophillips.com] Sent: Monday, January 10, 2011 4:29 PM To: Maunder, Thomas E (DOA) Cc: NSK Prod Engr Specialist; CPF2 Prod Engrs; CPF3 Prod Engrs; NSK Fieldwide Operations Supt; CPF1&2 Ops Supt; CPF3 Ops & DOT Pipelines Supt; Bradley, Stephen D Subject: Request for Approval Fy Importance: High 4 0 4 1t4ED IAN Tom, GKA is requesting AOGCC approval to initiate WAG injector flowbacks at Kuparuk if needed to maintain an adequate fuel gas for our turbo - machinery due to the current TAPS proration. Doing so should help ensure that we maintain life support and safety systems at each facility. At this time, it is unclear if this will become necessary as the repair status at Pump Station #1 is still evolving. As part of our planning contingency, GKA is currently configuring the 5 WAG injectors (listed below) for flowback to production via adjacent shut -in producers. The duration of the flowbacks would be directly tied to the length of the TAPS proration. This will be accomplished by hard -line connections between the Gas Injector to an adjacent shut -in producer via tree cap connections. Each well will be equipped with functional SVS which will be capable to shut -in the gas production in the event of a failure and we are in the process of completing a PHA for each of these installations. All injectors will have well testing capabilities for allocation purposes. ■lowback Adjacent Estimated Prod ;as Injector PTD# SI Producer PTD# (Mscfd) ;P -420 201 -182 2P -422A 202 -067 4,500 ;P -447 203 -154 2P -448A 202 -005 2,000 ;U -03 185 -006 - 3,500 IS -09 202 -205 -08 207 -163 7,50 IS -26 201 -040 3S -24A 204 -061 6,500 24,000 Please let me know if the AOGCC approves of this plan in the event we have to implement it during non -office hours. Regards, Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 1/11/2011 • Page 1 of Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, January 11, 2011 9:59 AM To: 'NSK Prod Engr & Optimization Supv' Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist; Colombie, Jody J (DOA) Subject: RE: Request for Approval Gary, et al, I have spoken with Commissioner Foerster and she has given her approval to proceed with the planned flowback of the listed wells as described. Volumes should be tracked /recorded as planned. At this time it is not necessary to submit Form 10 -403 for the wells. Form 10 -404 will likely need to be submitted for each well following the conclusion of this extraordinary situation. Gas disposition will also need to be reported. I will place a copy of this message in the well files. Please keep us advised of the situation. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK Prod Engr & Optimization Supv [mailto:n2046©conocophillips.com] Sent: Monday, January 10, 2011 4:44 PM To: Maunder, Thomas E (DOA) Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA); NSK Prod Engr Specialist Subject: RE: Request for Approval Tom, my estimate is that we could need this as early as tomorrow morning /afternoon. Pilots will be calibrated to meet the 25% flowing tubing pressure rule. Thanks for the timely response. Gary Gary Targac NSK Prod Engr & Optimization Supv ConocoPhillips Alaska, Inc. Kuparuk Office: 907.659.7411 Kuparuk Pager: 907.659.7000; #226 CPAI Internal Mail: NSK -47 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, January 10, 2011 4:38 PM To: NSK Prod Engr & Optimization Supv Cc: Foerster, Catherine P (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Roby, David S (DOA) Subject: RE: Request for Approval 1/11/2011 .~ ~"° ;~- `.' ,~~ ~ ~x t a ~. ~ ~ ~ ~~ •~ ~ ' MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc RECEIVEQ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 2 4 2Q09 REPORT OF SUNDRY WELL OPERATIO~a 0~ & Ges Cons. Commission 1. Operatio~s Pertormed: Abandon ^ Repair Well ^ Plug Pertorations ~ Stimulate ^ OtherAQChO 8~8 Alter Casing ^ Pull Tubing ^ Pertorate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. oeve~opment ^~ F~cploratory ^ , 207-163 /~° 3. Address: Stratigraphic ^ seN~~ ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20450-03 ~ 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 3S-08C / 8. Property Designation: 10. Field/Pool(s): ADL 380107 / Kuparuk River Field / Kuparuk River Oil Pool / 11. Present Well Condition Summary: Total Depth measured 12055' i feet true vertical 5872' / feet . Plugs (measured) Effective Depth measured 8795' feet Junk (measured) true vertical 5847' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 16" 108' 108' SURFACE 4234' 9-5/8" 4263' 2662' INTERMEDIATE 8767' 7" 8795' S847' LINER 3867' 4.5" 12055' S872' ___ _ ~ Perforation depth: Measured depth: 8750'-8790', 11 perf pups from 9322'-12001' true vertical depth: 5844'-5847', 5844'-5870' ~ - ~ ~l ~: ~- e ~~;~. , ~'.' ~ ,~ c ~.~, ~ Tubing (size, grade, and measured depth) 3.5", L-80, 8237' MD. Packers & SSSV (type & measured depth) HRD ZXP pkr @ s18a', seal bore ext @ a221' Camco'DS' nipple @ 502' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 120 541 0 -- 241 Subsequent to operation 668 1054 0 -- 183 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: none contact John Peirce @ 26 5-6471 Printed Name John Peirce Title Wells Engineer Signature y,~ ~ ~ Phone: 265-6471 Date ~^z3^Q9 ~ Pre a b Sharon All -Dr k 263-4612 Form 10-404 Revised 04/2006 ~~~~~ ~~~..~~,~ ~~ ; ' ~ : [Q0~ Submit Original ONy 3S-08C Well Events Summary DATE SUMMARY 8/1/09 DRIFT TBG W/ 5' 2.5" BAILER TO 8424' SLM, TOOLS STOPPED DUE TO DEVIATION/POSSIBLY HVY FLUIDS. DRIFT TBG W/20' 2.7" TO 8424' W/ PUMP ASSIST UP TO 3 BPM, UNABLE TO GET DEEPER, JOB COMPLETE. 9/2/09 RIH TO 9140' CTMD. LOG 4.5" LINER FROM 9100' CTMD TO 7400' CTMD W/ SLB MEMORY TOOLS GAMMA RAY FOR TIE IN. FLAG PIPE @ 8850' CTMD. ATTEMPT TO RU 20' PERF GUN BUT CONNECTION WAS TOO HIGH TO SAFELY MAKE UP TO BHA. ORDER MAN LIFT FOR THE A.M. IN PROGRESS. 9/3/09 SHOT 40' OF PERFS FROM 8750' TO 8790' RKB W/ HES 2.5" MILLENNIUM GUNS AT 6 SPF, 60 DEG PH. A 70 PSI TBG INCREASED WHEN UPPER GUN WAS FIRED (8750' TO 8770' RKB) BUT PRESSURE FELL BACK OFF TO 0 PSI, JOB COMPLETE. ~. CQtldl~'O~'1t~El~ - eIQ! I~g; ~~~I~.'an;~, i;Y,; 3$- HO zONTA4: __ . . _. HANGER.23~ _ _ _, . SGIe_m5t5:.AF - ~ -- CONDUCTOR, ~ 33 t08 NIPPLE.SOP SURFACE. 29i263 GAS LIFT. l.589 GAS LIFT. 5.7]6 GAS LIFT. 6.646 GAS LIFT. 7,360 GAS LIFf, 8.138 NIPPLE,8,~86 LOCATOR. ~ ' 6.156 L. : ScAL ASSY. - 8.215 APERF, i 8.750.8.]90 PERFP, ^ I ' ~ -~ 9.3229.3P8 '- ' I ~ PERFP, `!` ° 9.543-9,568 ~ PERFP, ~I I~~ 10,011-10,016 ~ ~ ~ naewesn. I ~ 9.372 _ PERFP, - 10,171-10.177 I PERFP, ~ I ~~ ~ 10.3fi3-10.368 !~ ' ~ PERFP, +W ~ ~ ~ 10,5Y4-10,528 m~ ~'~ PERFP. 10.t15-10.]20 ~I ~~ ~ ~ ~ PERFP, " ° 10.997~11.004 - PERFP. _. . _.. ~~ I 11.310-11,315 ~ _ PERFP. . - . __ __ -I i ~ - ` ii,s2a-iisso - ~ - I I PERFP, f i - 11.99]-12.001 _~°~""_~ 1'_: LINER, 8.183-12,055 ~ TD(3S-OBC). _~ 11A55 KUP 3S-08C Well Attributes _~_ ~Max Angle 8 MD ITD I WalLbo;eAPVUWIn IFie`dNam'vo~~i~oiini~~ I olnsr~a,rini~ Incl(°) IMD(ftK6) 4n IActBtrn(kKB) ~ n ~n ~ i~n Sn I ~ Annolation EndDate KB-Grd(N) .Comment H25(ppm) Date RigReleaseDate I I I I i SSSV~ NIPPLE 20 Z20l2008 Last WO~ 33.30 7I212008 I End Date Mnotation I'1as~ Mod By Annotation IDepth (fiKB) I End Data I Last Tao: ~ 12,OS5.0 10/9/'2008 Rev Reason: PERFORAfIONS ~ Imosbor I 9/52009 , Casi~ Strin s Casing Description :String 0... String ID ... Top (NKB) Sa~ Dapth (f... Sat Depth (ND) ... I,String WI... String ... String Top Thrd CONDUCTOR ~ 16 15.062 33.0 108.0 1080 I 62.50 H~0 WELDED ~Gasing Dascnption 'String 0... String ID ._ Top (fG(B) Set Depth (f... Set Depth (ND) ... IString Wt._ String ... String Top ThN SURFACE 95/8 8.697 28.7 4,263A 2,661.1 ~ 40.00 L-80 BTCM I Casing Descnplion ,String 0... String ID ._ Top (NKB) Sat Depth (f... Sat Depth (ND) ... ~ String Wt._ String .. Stnng Top ThN INTERMEDIATE : 7 6276 2fi5 8,795A 5.847] ~ 26.40 L-80 BTCM Casing0escr' tion Strin 0... P Strin ID... Top(HKB) SetDe th f... ~ ~Stringwt... 5bin9... SetDe th(ND~... StringTopThrd ~LINER 41/2 3.958 8,182.5 12A550 1260 L80 IBTMOD Liner Details .TopDepth, ~ '' Top Incl I . c«nmem (9 I I ~ I ~~s~'Ptwn iD(in~ 4" XO lih Sub 4" XT39 ~ X 3.5' IF p 8.1825 5.739.8 XO I I 3.500 'PACKER 5" x T' "HRD" ZXP Linertop Pkrw/70.60 ext & 525" ID TOL =_> 4.970 5,7422 6523 8t8$ 2 I ~ NIPPLE "RS" Packoff seal nipple jt w1TKC couplings (5.57" OD z 425" ID) ~ 4.875 I 5,74 .4 97 I _ _ ~ 8,210.6f ~ 5,750.9I 6732IHANGER 5" x 7" Flex-Lock Liner Hgr (5.96" OD z 4.42" ID) 4.853 8220 5~ 5,754.9'~ 6824ISBE 80-00 5" Seal Bore Ezt. w/TKC coupling ( Max OD 5.60" x 4" ID) 4]50 R,240.f ~ 5Jfi1 S. /QSOIXO 6USHING XO Bushing S" B I C x 4 1/2" IBT (Max OD S.6 x 3.95' ID) 3.830 I Tubing Strings Tubing Dascription IString O._ String ID... Top (HKB~ Se~ Depth (f... Set Depth (ND) ... String VJ~... String ... String TopThrd I UBING ~~ 3 12 ! 2.992 1 22.8 I 8,237.0 I 5.7602 . I 9_30 .. I.L-80 I EUE SrA-Mod ~ i Completion Details ~ Top Dapth I (ND) Top Incl I ~ ID (in) Top (ftK6) (HKB) (% Item Description Comment 22.8 22.8 -OA2 HANGER FMC 3.5' Gen V T6g Hanger EUE Srtl & pup ( Hgr JS' - Pup 3.65') 2.992 502.1 500.3 9.43 NIPPLE 3.5' Camco "DS" Nippie w/2.875" NO-GO profile EUE Srd-M 2875 8,186A 5,741.4 65.07 NIPPLE 35' Camco "DS" Nipple w/2.812" NO-GO profile EUE 8 rd-M 2.812 $195.6 5,7452 65.92 LOCATOR 5" Locator Sub 2.952 $225.5 5,756.8 68J0 SEALASSV 80-40 Bonded Seal assembly 3.875 Perforations & Slots _ _ _- _ _ _ Shot I Top (TVD) Btm (TVD) Dens I Top (ftK6) Btrn (flK6) (ftK8) (flKB) 7,p~e ~ Date (sh~- Type Commeril 8,750~, 8.790 5,844A 5,8473 C-0, 3S-OSC ~9/3/2009 6.0 APERF 25" HES Millenium guns, 60 Aeg I P~se ~ 9,322~~~ 9,328 5,844.0 5 843J Cd, 3S-OSC ~~ V79/2008 LO PERFP Perf Pups w/six 1/7' holes per pup ~ 9,543' 9,548 5,846.9 5,&17A C~,3S-08C ~7/19/2008I 1.O~~ PERFPIPerfPupsw/sixl/2"holesperpup 10,011 1Q016 5,869J 5,869.6 C4, 3S-OSC ' 7119/2008 1.OI PERFP IIPerf Pups w/six 1/2" holes per pup I 10,171 10,177~, 5864.6 5,864.4 C-0,3S-08C ~~7/19/2008 ~ 7.O~ PERFPIPerfPupsw/sizl/2"holesperpup 70,363~~ 10,368 5,862.6 5,862B~ Cd,3S-08C jl/19/2005 7.O pERFP ~PerfPUpsw/sixl/2"holesperpup 10,524 ~ 1q528 5,861.9 5,861.9 C-0, 3S-OSC 7119/2008 1.0 PERFP ' Perf Pups w/six 1/7' Fales per pup 10,775 10,720 S,S6Q2 5,860.1 Cd, 3S-OSC 1119/2008 1 0'~. PERFP Perf Pups w/six 1/7' Froles per pup 10,997 11,002 5,861.8 5,862.3 C~, 3S-08C 1l192008 , 1.O, PERFP Perf Pups w/six 1/7' holes per pup 11,310 11,315 5,860.5 5,860.Si C~4, 3S-08C i 7 /1 9120 05 '. 1.OIpERFP Perf Pups wrsiz 1/2" holes per pup 11,524 11,530 S 855.9 5,855.6 C-0, 3S-08C I 1l19/2008 ~ IA~~PERFP Perf Pups wlsix V2" hoies per pup I 11,997 12,001 5,869.6 5,869.8 Cd,3S-08C !~ 1/19/2008 I ~iPERFP PerfPupsw/sixV2"holesperpup 1.O Stimula tions 8 Treatme nts . ... . . . .. _ . . . ~ ~ Min ToP ~~ Max Btrn Top Depth ~ P~h ~ ~ Depth I Dapih (ND) (TV~) I (ftKB) ~ (RKB) (itKB) (ftKB) TYPe Date Comment 9,322.0 71,OOOA 5,844A 5,862.1 Acid Wash S/14/2009 FORMIC ACID TREATMENT. PUMPED 160 BBLS OF INHIBITED 10% FORMIC ACID IN 10 STAGES LAUNCHING 8 BIOBALLS BETWEEN EACH STAGE STAGES CONSISTED OF 16 BBLS OF ACID AND 10 BBLS OF SEAWATER PUMPING 2 BPM AT AN AVERAGED PUMP PRESSURE OF 500#. FLUSHED WELL WITH 100 BBLS OF SEAWATER AND FREEZE PROTECTED WITH 20 ~ ~ I ~~ BBLS OF DIESEI._ . No e General & Safety I I . : tlD E Anno~ - uo~ _. _ 1,'21i2008 NOlE~ WELLSIUETRACKEDI/21/2008 7;22/2008 NOI E' "'WAHNING"' LINER TOP PACKER IN IA - DO NOT EXCEED 3000 psi ~ 10/42008 ~~NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 _ . ...__._. . .. . . . Mandrel Details . . ~TOP Dept~ T p ~ I, Port . . - . .- - (TVD~ I I I OD V I Latc~ Size TRO Run Stn Top (ftKB) I (hKel () Maka Motlel (in) Sm ~. TYP ~ TYVe ('n) ~ (75 I Run D t Cam... ~ DMY ~RK 0000. 0.0 4/22008 1 4,588.9 2 A76.S 58.04 CAMCO MMG 7 12 Gas LIN 2 5,~739I 3,702.1 23.34 CAMCO MMG 1 V2 GasLifl IGW !RK 0_788 1,975A 5/16/2009 3 6,645.8~ 4,505.4 23.96 CAMCO MMG 1 V2 Gas Lifl DMY RK 0_000 0.0 V20/2008 ~ 4~ ~7,3604i~ 5,146.8 29.82 CAMCO~MMG 1 7/2 GasLiR OV RK I~~2`.A 0.0 5/762009 5 8,138.1 j 5,717J 60.57 CAMCO MMG 1 1/2 Gas LiH DMY RK 0.000 0.0 5/202008 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimutate Q` Other ~ Alter Casing ^ Pull Tubing ^ Pertorate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate [] Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnoCOPhillips Alaska, InC. Development ^~ ' Exploratory ^ 207-163 /~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20450-03 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 3S-08C ' 8. Property Designation: 10. Field/Pool(s): ADL 380107 " Kuparuk River Field / Kuparuk River Oil Pool . 11. Present Well Condition Summary: Total Depth measured 12055' ' feet true vertical 5872' , feet Plugs (measured) Effective Depth measured 8795' feet Junk (measured) true vertical 5847' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 108' 108' SURFACE 4234' 9-5/8" 4263' 2662' INTERMEDIATE 8767' 7" 8795' 5847' LINER 3867' 4.5" 12055' S872' ~~CG~VGD PerForation depth: Measured depth: 11 perf pups from 9322'-12001' ,, ~°~~~;f~ ~ 0 ~~ ~U, ~ ' ' ~ ~ JUN 20D9 true vertical depth: 5844 -5870 x~~~~~ Alaska Oil & Gas Cons. Commission Tubing {size, grade, and measured depth) 3.5", L-80, 8237' MD. AflCF10t'8~£ Packers & SSSV (type & measured depth) HRD'ZXP' liner top pkr, seal bore extension ~ 8188', a221' Camco'DS' nipple @ 502' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 9322'-11000' 160 bbls formic acid Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 108 594 2 -- 247 Subsequent to operation 517 ~ 704 29 - 237 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ ` Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: none contact John Peirce @ 26 5-6471 Printed Name John Peirce Title Wells Engineer Signature ~l r~ _ Phone: 265-6471 ~~4~~~ Date / ~"~~ "~ Pre a b Sh ron Allsu -Drak 263-4612 ~I ~ - •~. r`3 Form 10-404 Revised 04/2006 ' ~ `` Submit Origi nl . ~~ ,rt)i. ~ ~ 7~~~ ~/~~~j~~/ ~l 3S-08C Well Events Summary DATE SUMMARY 5/12/09 REPLACED OV @ 7360' RKB ~LV @ 5773' RKB W/ DV's. IN PROGRES . 5/13/09 BRUSH & FLUSHED TBG TO DS NIPPLE @ 8186' RKB. SET 2.81" CA2 PLUG @ 8186' RKB. TESTED TBG TO 2500 PSI. PULLED PLUG. READY FOR ACID JOB IN AM. ~. 5/14/09 COMPLETED FORMIC ACID TREATMENT. PUMPED 160 BBLS OF INHIBITED 10% FORMIC ACID IN 10 STAGES LAUNCHING 8 BIOBALLS BETWEEN EACH STAGE. ~TAGES CONSISTED OF 16 BBLS OF ACID AND 10 BBLS OF SEAWATER PUMPING 2 BPM AT AN AVERAGED PUMP PRESSURE OF 500#. FLUSHED WELL WITH 100 BBLS OF SEAWATER AND FREEZE PROTECTED WITH 20 BBLS OF DIESEL. 5/16/09 REPLACED DMY VLV @ 7360' RKB W/ OV.(.25" PORT) REPLACED DMY VLV @ 5774' RKB W/ GLV (TRO= 1975/ PORT= 3/16"). JOB COMPLETE. KUP ell Attributes ..__- _ . ....--. I~oreAPl/UWI ~FieldName I S(ltil"3~(ldSfl(1'l IKI IP4RI IK f~l\/FR I INIT ~ 3s-osc ;MaxMgIeB.MD I~TD lus Incl (°) IMD lryKB) Aci Btrn (ftK6) I(`INf: Q'1 d"i Q 1 ~'1 Sfl i~ nss n Comment IH2S (ppm) I Mnotation End Date ~ KB-Grd (ft) Rig Ralease Date Date ~ I ISSSV: NIPPLE ~ 20 i I 2/20/2G08 ILastvVO: 33.30 1/2V2008 ~.Annotation IDepth(kKB) ~EndDate Annotrtion ~Las~ModBy ~~EndDate ~~. Last Tag: 12,055.0 10/9/2008 I Rev Reason~ Acid Job, GLV GO Imosbor 5/15/2009 ' Casin Strin s Casing Description String 0.., iString ID._ Top (flKB) Set Dapih (t... Set Depth (ND) ... String Wt._ String ... String Top ThN CONDUCTOR 76 75.062 33.0 108.0 708.0 6250 H-00 WELDED Casing Description String 0... String ID ... Top (flKB) Set Depth (7... Set Dapth (ND) ... String Wt._ String ... String Top ThM SURhACE I 95/8 I 8.697 28.7 4,263D 2661.1 40.00 L-80 BTCM 'Casing Description String 0... IString ID... Top (HKB) Set Depih (f... Set Depth (ND) ... String Wt...I String _. String Top ThN INIERMtDIA(E 7 ~ 6276 26.5 $795.0 5,847J ' 26_40 L-80 ~, BTCM ICasing Descrip~ion I Sbing 0... String ID ... ~ Top (HKe) Set Depih (f... Set Depth (7YD) ... String NM... String ... Stting Top Thrd LINER 41/2 3.958 8,782.5 12,055.0 12.60 L80 IBTMOD Liner Details ~ ~ Top Dep~h' ' (ND) ~I ToP Incl Top(kKJ _~HKe~ I(°) HemDascription CommeM _ ID(in) 8,1825 5,739.8~ 64J7IXO ~ 4"XOUftSu6 4"XT39bX3.5"IFp 3.500 8,1882 5,7422 6523~ PACKER S' x 7" "HRD" ZXP Liner top Pkr wl10.60 eM & 525" ID TOL =__> 4.970 . ._ _ _ ... _ _ . _ .. - ._. __ _ 8,206.9 5,749.4 66.9~ NIPPLE "RS" Packoff seal nipplejt w/TKC couplings (5.57" OD x 4 25" ID) 4.875 8,210.6. 5,750.9 67.32 HANGER 5" x 7" Flez-Lcek Liner Hgr (5.96" 00 x 4.42' ID) ~~~~ ~~~ ~~~ 4.853 ~ , i ~ ~. __. ____. 8220.5 5]54.9 6824 ~SBE 80-40 S' Seal Bore Ext. w/fKC mupling ( Max OD 5.60" z 4" ID) ~ 4J50 8,24G.6 5, /fi1.S 70.50 XO BUSI IING XO Bushing 5" BiC x 4 1/2" Ik3I (Maz OD S.5 x 3.95" ID) 3.830 Tubing Strings 'i,TubingDescription IStringO... I54ingID_..~TOp(itK6~ ISetDepth(f...ISetDepth(ND)...ISUingWt...IString...IStringTopThrtl GAS LIFT, _ 7,360 GAS LIFf, _ . 8,138 NIPPLE, 8,18fi- LOCATOR, _ 8,~96 SEAL ASSY, 8,225 PERFP, - 9,322-9.328 PERFP.__ _ _._ ^ I ... 9,503-9.546 ~ PERFP, ~ 10.011-10.016 -- Adtl Wasli. I 9,322 PERFP, . 10.1'/1-10.i1] ` PERFP. ~ I 10,363-~0,368 -i PERFP, ~H~ 10.524-10,528 ~ t PERFP, '~~ 10.715-10.720 ~ ~ y ~ PERFP, 10.997-11.002 - PERFP, -. ~ .-- 11.310-11.315 - PERFP, ...--"~ - I ~ 11.521-11.530 I PERFP._. ._ ~.~1 11.997-12.001 ~~ LINER, 8,183-12.055-\ ~ TO(3S-OBC), 12U55 DATA SUBMITTAL COMPLIANCE REPORT 12/18/2008 Permit to Drill 2071630 Well Name/No. KUPARUK RIV UNIT 3S-08C Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20450-03-00 MD 12055 TVD 5872 Completion Date 1/20/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional S DATA INFORMATION Types Electric or Other Logs Run: GR / RES Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name og Induction/Resistivity '~C Lis 16034~duction/Resistivity ~g Induction/Resistivity og InductionlResistivity C Pdf 16045 ~nduction/Resistivity II ' pt LIS Verification , ', Rpt i 16056 hrrdtiCTCim7lta?5F istivity i ' Q , ED D Asc Directional Survey '~ Directional Survey Log Production (~ D C Pds 17073" Production i (data taken from Logs Portion of Master Well Data Maint Interval Log Log Run OH / Scale Media No Start Stop CH Received Comments 25 Blu 8800 11989 Open 3/13/2008 MD Vision Service 17-Jan- 2008 8750 12014 Open 3/13/2008 LIS Veri, GR, ROP, FET, RPX, RPS, RPM, RPD, DRHO, NPHI, TRPM 25 Col 4263 8825 Open 3/24/2008 MD ROP, DGR, EWR 17- Dec-2007 25 Col 2661 5850 Open 3/24/2008 TVD ROP, DGR, EWR 17- Dec-2007 0 0 Open 3/24/2008 Graphics ONLY MD and TVD in CGF, EMF and PDF for EWR, DGR and ROP logs 4209 8825 Open 3/24/2008 LIS Veri, RPX, RPS, RPM, RPD, FET, GR, ROP 4209 8825 Open 3/24/2008 LIS Veri, RPX, RPS, RPM, RPD, FET, GR, ROP w/CGM, EMF and PDF graphics 27 12055 Open 3/28/2008 27 12055 Open 3/28/2008 5 Blu 9300 12020 Case 11/7/2008 Mem PPL, GR, CCL, Pres, Temp, Dev, Spin 14-Oct- 2008 9300 12020 Case 11/7/2008 Mem PPL, GR, CCL, Pres, Temp, Dev, Spin 14-Oct- 2008 DATA SUBMITTAL COMPLIANCE REPORT 12/18/2008 Permit to Drill 2071630 Well Name/No. KUPARUK RIV UNIT 3S-08C Operator CONO COPHILLIPS ALASKA INC MD 12055 TVD 5872 Completion Date 1/20/2008 Completion Status 1-OIL Current Status 1-OIL Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORI~gTION / ~/ N Well Cored? Y N Daily History Received ? Chips Received? Y /1~ Formation Tops ~ N Analysis ~~ Y / N Received? Comments: Compliance Reviewed By: Date: API No. 50-103-20450-03-00 UIC N NO.4947 ~i tip Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description (;~~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnkein 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/29/08 3S-08C 1C-26 1C-119 3H-15 1C-121 3H-18 1J-159 1 F-10 12066554 11978487 11978488 12080445 11978490 12080446 12097431 12080453 MEM PRODUCTION PROFILE (j - '~' SBHP SURVEY I _(~ ~ j INJECTION PROFILE ~ INJECTION PROFILE - -3 C,/ INJECTION PROFILE INJECTION PROFILE ~ ~ - PRODUCTION PROFILE ~ ~^' INJECTION PROFILE 10/14/08 10/15/08 10/16/08 10/16/08 10/17/08 10/17/08 10/13/08 10/27/08 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1C-121 11978490 INJECTION PROFILE (- 10/17/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • r 26-Mar-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3S-08C Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 4,207.98' MD Window /Kickoff Survey: 4,263.00' MD (if applicable) Projected Survey: 8,825.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 ./~ / , , ,, Date o~.d /~~+~.. ~vt~`~ iS Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~7- Ito3 :7 WELL LOG TRANSMITTAL ~i To: State of Alaska March 10, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7t" Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 3S-08C AK-MW-547705 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20450-03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~~'.~~ ; . ~: ~' } ,~ - Date: ~`~;~~ ~ ~~E~?~3 V Signed: C~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 3S-08C March 10, 2008 AK-MW-5477055 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3S-08C 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20450-03 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20450-03 Digital Log Images 50-103-20450-03 1 Color Log 1 Color Log 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. ,_~i~r~.g~a~l~ 99518 Dom;; : :,, ~ ''~' r ,:: ~0~-~~~ Signed: ~ ~ /(00(5 .I !_ , 03!12/08 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4624 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1 A-12 11964583 LDL q~ :C(_ (~ (~-~ 02/28/08 1 1 E-1128 SAND LATERAL 11978443 MEM INJECTION PROFILE 03/03/08 1 iR-04 11964585 USIT ~. - 03/02/08 1 2L-330 11837544 OH EDIT (SONIC SCANNER) "~-- ~ 11/27/07 1 1 31-01 11994626 LDL 03/06/08 1 2N-327 11994628 PRODUCTION PROFILE ~~--. 03/08/08 1 1 Y-28 11994629 PRODUCTION PROFILE 03/10/08 1 3S-08C 40016310 OH MWD EDIT VISION SERVICE ~' ~/ 01/17/08 1 1 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. r ConocoPhillips February 25, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 3S-08C Dear Commissioner: Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~~~ ~ ~p Ale~ka~ ail ~ I~a~ Cnn~~ Cnmmisxinr~ Anchored ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 3S-08C. If you have any questions regarding this matter, please contact me at 265-6830 or Jason Brink at 265-6419. Sincerely, 1 ~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad Jv~-r~3 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~E~~~ FHB ~ 6 2 WELL COMPLETION OR RECOMPLETION REP~c~~iA~l'~~c~1~~a~~~h 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned Suspended ^ 20AAC 25.105 20AAC 25.110 C~ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: ~ JG~ 1b.:VVCIas~nG~(ji>~~~ Development ^/ ~ Exploratory ^ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: January 20, 2008 12• Permit to Drilt Number: 207-163 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: December 14, 2007 13. API Number: S0-103-20450-03 4a. Location of Well (Governmental Section): Surface: 2492' FNL, 954' FEL, Sec. 18, T12N, R8E, UM 7. Date TD Reached: January 16, 2008 ~ 14. Well Name and Number: 3S-08C Top of Productive Horizon: 344' FNL, 1706' FWL, Sec. 20, T12N, R8E, UM 8. KB (ft above MSL): ~ 28' RKB ~ Ground (ft MSL): 55' AMSL i ZZ ~ 15. Field/Pool(s): Kuparuk River Field Total Depth: 2182' FNL, 1029' FEL, Sec. 19, T12N, R8E, UM 9. Plug Back Depth (MD + ND): 8795' MD / 5847' TVD Kuparuk Oil Pool ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 476305 y- 5993923 Zone- 4 10. Total Depth (MD + ND): 12055' MD / 5872' ND 16. Properly Designation: ADL 380107 • TPI: x- 478966 y- 5990783 Zone- 4 Total Depth: x- 476233 ~ - 5988955 - Zone- 4 11. SSSV Depth (MD + ND): landing nipple @ 502' MD / 501' ND 17. Land Use Permit: 4624 18. Directional Survey: Yes ^/ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): not available 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE O AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING REC RD PULLED 30" x 16" 62.5# B Surf. 108' Surf. 108' 42" 75 sx ArcticCRETE 9.625" 40# L-80 Surf. 4263' Surf. 2662' 12.25" 664 sx AS Lite, 391 sx LiteCRETE 7" 26# L-80 Surf. 8795' Surf. 5847' 8.5" 181 sx Class G w/ GasBLOK 4.5" 12.6# L-80 8188' 12055' 5741' 5872' 6.125" pre-perted liner 23. Open to production or injection? Yes / - No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 8237' 8188', 8398' 11 pert pups @ 11996', 11524', 11310', 10997', 10715', 10523', 10363', 10171', 10011', 9543', 9322' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ~~p~~ none ~~ 26. PRODUCTION TEST Date First Production February 12, 2008 Method of Operation (Flowing, gas lift, etc.) gas lift oil Date of Test 2/12/2008 Hours Tested 5-3/4 hours Production for Test Period -> OIL-BBL 312 GAS-MCF 119 WATER-BBL 10 CHOKE SIZE 28% GAS-OIL RATIO 498 Flow Tubing press. 259 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 1216 GAS-MCF 605 WATER-BBL 41 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No / Sidewall Cores Acquired? Yes No / If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. SC;;Vtr~.~ t'SU4 NONE ` ~~~~ ~@ED~ f Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ~~ ~ a, zr. og ~~~1~~ 28. GEOLOGIC MARKERS (List all formations and m rs encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost -Top surface surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom not available not available needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C 8752' 5844' Kuparuk D 8752' 5844' N/A Formation at total depth: Kuparuk 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Brink @ 265-6419 Printed Nam Rand Thomas Title: Drillino Team Leader ~Z S l° D S - ignature - ne ate L6S 6 ~ 3 ~ INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level.. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 Steve - Here is the additional data for CD3-316A, permit #208-011 Alterna ' /slotted liner from: 11661'-11740' MD '- 729' e 11940'-11980' -6722 8 spf .25 wide - 382' MD 6717'-6714' TVD 8 so ide Below is the additic 9322'-9328' MD 9543'-9548' MD 10011'-10016' MD 10171'-10177' MD 10363'-10368' MD 10524'-10528' MD 10715'-10720' MD 10997'-11002' MD 11310'-11315' MD 11524'-11530' MD 11997'-12001' MD >nal data for 3S-08C, permit #207-163 5844'-5844' TVD 1 spf .5" hole 5847'-5847' TVD 1 spf .5" hole 5868'-5868' TVD 1 spf .5" hole 5865'-5864' TVD 1 spf .5" hole 5863'-5863' TVD 1 spf .5" hole 5862'-5862' TVD 1 spf .5" hole 5860'-5860' TVD 1 spf .5" hole 5863'-5863' TVD 1 spf .5" hole 5861'-5861' TVD 1 spf .5" hole 5856'-5856' TVD 1 spf .5" hole 5870'-5870' TVD 1 spf .5" hole ~~ ~onocoPhi[ips Time Log Summary We/fv7ew Web Reporting i Well Name: 3S-08 Job Type: DRILLING SIDETRACK Time Logs Date From To Dur S. De th E. De th Phase Code:-- Subcode T _ __ GQM 12/06/2007 08:00 - - - 12:00 - - 4.00 0 0 MIRU MOVE DMOB P --- Rig released at 0800 HRS from 2W-17. Demob rig breaking down complexes and sub base. Blow down all air, steam, water & hydraulic lines. Prep rig camp for move, blowing down all lines, & securin electrical lines. 12:00 19:00 7.00 0 0 MIRU MOVE MOB P Move rig camp, sewer plant & truck shop to 3s -08. Lay matting boards, spot and rig up same. Load camp water, attach all lines, and electrical. Rig up communications.Total mileage one wa - 27 miles. 19:00 00:00 5.00 0 0 MIRU MOVE MOB P Transport trucks back to 2W-17. Load pipe sheds, motor and boiler complexes. Move complexes to 3s-08. Spot on pad out of the way of ongoing work to 3S - 08. Crew Chan e 12/07/2007 00:00 07:00 7.00 0 0 MIRU MOVE MOB P Continue move sub base, pits, pump room, and rockwasher complexes to 3S-08. All modules on location @ 0700 HRS. Continue Pre well work as er wells rou . 07:00 14:45 7.75 0 0 MIRU MOVE WOEL NP Rig on standby waiting for Slickline unit to complete dump baling of cement on top of reatiner. Rig down and remove scaffolding, and SSSV control box. Install BPV as per FMC re .Grade and re location. 14:45 17:00 2.25 0 0 MIRU MOVE OTHR P Lay matting baords utilizing a crane to hold up Flow line behind sub, for matting board installation behind sub base. Continue rade & level location. 17:00 18:30 1.50 0 0 MIRU MOVE PSIT P Move & spot sub base over well ensuring ceneterd over well and level. Drill site operator on location for witness move over well. 18:30 20:30 2.00 0 0 MIRU MOVE PSIT P Move & spot mud pits, pump room, motor room and boiler com lexes. 20:30 21:00 0.50 0 0 MIRU MOVE PSIT P Move & spot rockwasher complex. 21:00 23:00 2.00 0 0 MIRU MOVE PSIT P Move & spot both pipe shed modules. 23:00 00:00 1.00 0 0 MIRU MOVE RURD P Continue work on rig for acceptance as per Checklist. Attach all steam, water, Hydraulic, and air lines. Set stairs & handrails, landings. Trim all Herculite. Install plugs all pumps, and check lines. Crew Chan e ~<aga 1 csf 4d ~~ i Time Logs _ _ _ __~ Date From To Dur e th S D E. De th Pha e Code Subcod e T COM _ _ 12/08/2007 22:15 23:15 1.00 __ 0 0 MIRU RPC06 _ PULD P Make up 3 1/2"joint in tbg hanger. BOLDS. Attempt to pull tbg free observing hanger free and movement of 8'. Pull to 150K, observing that the elevators being used were limited to only 150K. we expected to pull to max of 200K. Set down hanger. Change out handlin a ui ment. 23:15 23:45 0.50 0 0 MIRU RPCO OTHR NP Observed hand dropped a sledge hammer in the hole on top of the tubing hanger with handle lookiing up. Ri u and fish out hammer. 23:45 00:00 0.25 0 0 MIRU RPCO PULD P Continue change out handling e i ment. Crew Chan e 12/09/2007 00:00 01:00 1.00 0 0 SURFA RPCOh PULD P Attempt to pull 3 1/2" tbg free, staging to 200K straight pull. Work string numerous time. Continue work string, callin out SWS wireliners for'et cut. 01:00 01:30 0.50 0 0 SURFA RPCO RURD P Land tbg hanger. run in 4 LDS. Rig down, back out & lay down landing joint. Decision to pick up and rack back 4" DP, as SWS wireliners could not travel until 0500 HRS as per their travel restrictions of No travel between 2300 hRS - 0500 HRS. 01:30 01:45 0.25 0 0 SURFA RPCO SFTY P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to pick up 4" DP from pipe shed and rack back same in derrick. Close Blind rams. 01:45 06:45 5.00 0 0 SURFA RPCO OTHR P Pick up 4" drill pipe from shed and rack back stands in derrick. 06:45 07:30 0.75 0 0 SURFA RPCOh OTHR P Clean & clear rig floor. 07:30 10:00 2.50 0 0 SURFA EVAL RURD P Held PJSM with crew &SWS wireline crew. Discuss safety & hazard recognition issues. Discuss procedure to rig up. Spot & rig up SWS with sheaves. MU Tools and 'et Cutter. 10:00 12:00 2.00 0 0 SURFA EVALVb DLOG P Wireline in hole with 2.5" Cutter to 2310' WLM. Observed wireline stop as not enough weight to fall. POOH to surface. Add weight bars. Crew Chan e 12:00 12:30 0.50 0 0 SURFA EVALVb DLOG P Continue MU weight bar assembly on 'et cutter. 12:30 14:45 2.25 8,310 8,310 SURFA EVALVI~ OTHR P WLIH with 2 1/2" Jet cutter to locate & fire cutter 8310' WL . WLOH. Lay down sheaves and tools. 14:45 15:15 0.50 8,310 8,310 SURFA RPCOh RCST P Make up landing joint to hanger. Pull on tbg to observe free at 105K pulled. P II h ri floo . 15:15 15:45 0.50 8,310 8,310 SURFA RPCO CIRC P Circulate bottoms up at 330 GPM - 1250 PSI. 15:45 16:30 0.75 8,310 8,310 SURFA RPCOh RCST P Breakout & lay down tbg hanger & landin 'oint. Page 3 of 44 ~~ C J Time Logs __ _ Date From To Dur S De th E. De th Phase Code Subcode T COM 12/09/2007 16:30 17:30 1.00 8,310 8,310 SURFA RPCOh RCST P POOH with 3 1/2" tbg, standing back 11 stands as er well Ian. 1026' 17:30 00:00 6.50 8,310 8,310 SURFA RPCOh RCST P Continue POOH, laying down 210 joints of 3 1/2" tubing & GLM's.. Strap & number each joint layed down. Inspect for corrosion as per CPAI corrosion reps. Observed proper dis lacement. Crew Chan e 12/10/2007 00:00 00:30 0.50 8,310 8,310 SURFA RPCOh RCST P Continue POOH, laying down 33 joints of 3 1/2" tubing & GLM's.. Strap & number each joint layed down. Inspect for corrosion as per CPAI corrosion re s. Observed ro er dis lacement. 00:30 04:15 3.75 8,310 8,310 SURFA RIGMN RGRP T Observed loss of power on pipe machine. trouble shoot and repair pipe machine. 04:15 05:15 1.00 840 0 SURFA RPCOA RCST P Continue POOH, laying down 23 joints of 3 1/2" tubing & GLM's.. Strap & number each joint layed down. Observed proper displacement. layed down a total of 264 'nts & cut off 'nt. 05:15 06:45 1.50 0 0 SURFA RPCO OTHR P Clean & clear rig floor. lay down tbg runnin a ui ment. 06:45 08:45 2.00 0 0 SURFA WELC NUND P Held PJSM. change out lower rams installing 7" rams. Attempt to test rams installin test'oint. O test ~oint needed to be modified. Install. wear bushin . RILDS. 08:45 09:45 1.00 0 16 SURFA RPCOh PULD P Make up 6 1/8" bit & scraper assembly with 2 boot baskets. Total BHA = 16.32' 09:45 12:00 2.25 16 4,797 SURFA RPCO TRIP P Trip in hole with BHA #1 to 4797' DPM. Pump 30 BBLS Hi vsc sweep at 8.5 BPM - 100 PSI. UP WT = 85K, SO WT= 60K. Crew Chan e 12:00 12:15 0.25 4,797 4,797 SURFA RPCOti OWFF P Monitor well -static. Drop a 2" drift on wireline. Blow down to drive & lines. 12:15 14:15 2.00 4,797 0 SURFA RPCO TRIP P POOH from 4797' -surface. Breakout & la down Bit & scra er assembl . 14:15 14:30 0.25 0 0 SURFA RPCO PULD P Clean & clear rig floor area. Send tools out. 14:30 16:45 2.25 0 4,663 SURFA RPCO TRIP P Make up 7" CIBP & running tool as per BOT rep. TIH to locate @ 4663' DPM. UP WT = 85K, SO WT = 61 K 16:45 17:45 1.00 4,663 4,663 SURFA RPCOti OTHR P Drop 1 3/4" ball, pump ball down @ 2.5 BPM =250 PSI, observe ball seated with 305 strokes. Pressure to 1000 PSI to set CIBP. Pull to 120K up, and observe release of plug. Pull u above lu . 17:45 18:15 0.50 4,663 4,663 SURFA RPCOh DHEO P Rig up and test CIBP to 3000 PSI, for 30 minutes, record on chart. Bleed ressure. 18:15 19:00 0.75 4,663 4,663 SURFA RPCOti CIRC P Displace well with 9.0 PPG LSND mud 380 GPM's - 500 PSI. 19:00 19:15 0.25 4,663 4,663 SURFA RPCO OWFF P Monitor well- static. Blow down Top drive & lines. Pale 4 of 44 Time Logs _ _ _ Date From To D r S. De th E. D_ e th Phase Code Subco de T COM u 12/10/2007 19:15 21:00 _ _ 1.75 4,663 _ 0 SURFA RPCOh _ TRIP P POOH from 4663 to surface. Breakout, inspect and lay down runnin tool. 21:00 21:30 0.50 0 0 SURFA RPCOh OTHR P Clean & clear rig floor area. Send tools out. 21:30 23:00 1.50 0 0 SURFA WELCT BOPE P Pull wear bushing. Set test plug with 7" test'oint. Rig up and test 7" lower 250 /5000 PSI. Record on chart. Ri down test a ui ment. 23:00 00:00 1.00 0 0 SURFA FISH PULD P Pull BOT tools to rig floor. Check strap on tools. Make up 5 1/2" Multi-string cutter assembly with 6 1/8" stabilizer. Check sweep on cutter to 8.75" OD. Crew Chan e 12/11/2007 00:00 01:45 1.75 0 4,400 SURFA FISH TRIP P Trip in hole with 5 1/2" multi-string cutter to 4400'. 01:45 02:00 0.25 4,400 4,400 SURFA FISH SFTY P Held PJSM with crew & BOT rep. Discuss safety & hazard recognition issues. Discuss procedure to cut 7" csg, and take returns should the well U-tube. 02:00 03:00 1.00 4,400 4,463 SURFA FISH CPBO P Establish parameters. locate top collar @ 4440' DPM and the lower collar @ 4481' DPM. Position Knives at 4463' DPM. Establish circulation to 2 BPM - 300 PSI. Increase in stages to 6 BPM - 1300 PSI. RPM's = 60 with 4K FUlbs of torque. Rotate to cut & observe prssure drop of 500 PSI, indicating cut. Continue to rotate allowing cutters to fully extend for a good cut. We did not see an fluid returns on the OA. 03:00 03:30 0.50 4,463 4,463 SURFA FISH CPBO P Pick up above cut. Close rams, and pressure down DP to 1000 PSI to attempt to obtain circulation. We could pump at 1 BPM - 950 PSI with fluid being pumped away, and no returns to the OA. Pumped away 5 BBLS. No returns to the OA.Repeat attempts to gain circulation. No fluid loss observed in pits. Note: previous EMW on the 9 5/8" shoe was 17.9 PPG. Bleed pressure and open rams. Close OA. 03:30 03:45 0.25 4,463 4,463 SURFA FISH CPBO P Establish circulation at 3 BPM - 500 PSI. Slack off to observe knives fully extending into the cut, with 300 PSI pressure drop and weight set down. Cut indicated to be o en at +/- 6". 03:45 04:00 0.25 4,463 4,463 SURFA FISH OTHR P Monitor well -static. Blow down top drive and lines. 04:00 06:00 2.00 4,463 0 SURFA FISH TRIP P POOH from 4663' -surface. Inspect cutter knives, indicating full sweep of 8.75". 06:00 07:30 1.50 0 0 SURFA RPCOh OTHR P Clean & clear rig floor. Rig up and pull 7" hanger pack-off as per FMC rep, for re-use. Page 5 e~f 44 Time Lo s 9---- Date From To Dur S. De th De th Phase Code Subcode T COM E. 12/11/2007 07:30 10:30 3.00 __ 0 _ 0 SURFA FISH FISH P _ Make up 7" casing spear assembly with pack-off as per BOT rep. grapple size = 6.220". RIH, engage 7" csg. , Pull to 50K, verify catch. Pull in sta es u to 350K to attem t to free casing. Casing not free. utilize 1000 PSI of pump pressure to aid in freeing pipe. No success. Release spear. POOH, la down same. 10:30 11:00 0.50 0 0 SURFA FISH OTHR P Rig up and install wear bushing. RILDS. Ran in 4 LDS on casing spool above 7" han er. 11:00 12:00 1.00 0 197 SURFA FISH PULD P Make up 5 1/2" Multi-string cutter assembly with 6 1/8" stabilizer. Change out cutter knives. Check sweep on cutter to 8.75" OD. Trip in hole to 197'. Crew than e 12:00 14:00 2.00 197 4,317 SURFA FISH TRIP P Continue trip in hole from 197' - 4317'. UP WT = 82K, SO WT = 60K. 14:00 15:30 1.50 4,365 4,365 SURFA FISH CPBO P Establish circulation to 2 BPM - 300 PSI. Locate 7" casing collars on depth at 4355' & 4397'. Pull up and locate to .cut at 4365' as planned. Increase pump rate in stages to 6 BPM - 1200 PSI. RPM's = 60 with 4K FUlbs of torque. Rotate to cut & observe prssure drop of 400 PSI, indicating cut. Continue to rotate allowing cutters to fully extend for a good cut. We did not see an fluid returns on the OA. Pick up and allow knives to open with 2 BPM, Slack off to locate and verify good cut with pressure drop observed when entering cut. Cut indicated to be 15:30 16:00 0.50 4,365 4,365 SURFA FISH OTHR P Monitor well -static. Pump 20 BBL d 'ob. Blow down to drive & lines. 16:00 18:00 2.00 4,365 0 SURFA FISH TRIP P POOH, breakout, inspect knives, and lay down assembly. Observed proper displacement. Knives indicated a good cut with 8.75" swee . 18:00 18:15 0.25 0 0 SURFA FISH OTHR P BOLDS. Pull wear bushing. Page 6 rsf 4& {~i S~G~~®~ Time Logs ___ Dade From To Dur S: De th E. De th Phase Code Subcode T COM I 12/11/2007 18:15 19:45 1.50 0 0 SURFA FISH FISH P Make up 7" casing spear assembly with pack-off as per BOT rep. grapple size = 6.220". RIH, engage 7" csg. P II to 50K veri catch. Pull i sta es up to 350K, workin strin for 1 1/2 HRS to free casing, utilizin 1000 PSI of pum ressure to aid in freeing i e. Pull casing hanger to rig floor. UP WT = 155K. Observed 7" casing hanger damaged on the flutes from lock down screws left run in when pulling free. Inspect casing spool, observing 2 Gland nuts split and broke. Suspect damaged LDS in spool _ as well 19:45 21:00 1.25 0 0 SURFA FISH CIRC P Circulate out freeze protect diesel and mud at 4 BPM - 300 PSI, until obtained good 9.0 PPG all around. SIMOPS: Rig up casing equipment to pull and lay down 7" casing. Monitor well -static. 21:00 21:30 0.50 0 0 SURFA FISH PULD P Release spear assembly, breakout & lay down same. Blow down Top drive & lines. Send tools out. 21:30 00:00 2.50 4,365 3,217 SURFA FISH PULL P Held PJSM with crew & casing hand. Discuss safety & hazard recognition issues. Discuss procedure to pull & lay down casing. POOH, breakout & lay down 7" casing. Install thread protectors. Observed proper hole 611. Layed down 28 joints, and 4 centralizers. Crew Chan e 12/12/2007 00:00 03:15 3.25 3,217 0 SURFA FISH PULL P Held PJSM with crew & casing hand. Discuss safety & hazard recognition issues. Discuss procedure to pull & lay down casing. POOH, breakout & lay down 7" casing. Install thread protectors. Observed proper hole 611. Layed down a total of 102 joints + cut off joint, and 9 centralizers. Observed ro er hole fill. 03:15 04:15 1.00 0 0 SURFA FISH OTHR P Clean & clear floor area. Rig down 7" cesin runnin a ui ment. 04:15 04:30 0.25 0 0 SURFA RPCOti OTHR P Install wear bushing. RILDS. Change out elevators. 04:30 06:30 2.00 0 0 SURFA RIGMN SVRG P Held PJSM with Crew. Service Top Drive & draw works. Slip & cut drilling line. Inspect brake linkage. Inspect Saver sub. 06:30 07:45 1.25 0 0 SURFA CEME~ RURD P Rig up Tbg equipment for run 3 1/2" tail i e. 07:45 11:00 3.25 0 4,663 SURFA CEME~ TRIP P Make up 3 1/2" stinger assembly with mule shoe (1068') & crossover to 4" DP. Trip in hole to 4213'. Rig up and circulate down with assembly to tag CIBP 4663'. Pull u to 4653'. P~c~~ 7 of 44 Time Lo s - ~- ---- Date From To Dur S De th E. Depth Phase Code Subcode T COM _ _ 12/12/2007 11:00 12:00 1.00 4,653 4,653 SURFA CEME CIRC P Circulate & condition 9.0 PPG mud at 4 BPM - 250 PSI. Crew Chan e 12:00 14:30 2.50 4,653 4,653 SURFA CEME CIRC P Continue circulate & condition 9.0 PPG mud in hole at 4 BPM - 250 PSI. Pu112 stands and circulate above 7" casing cut. Trip back to 4363', continue circulatin & condition mud. 14:30 17:30 3.00 4,653 4,653 SURFA CEME CIRC NP Wait on Dowell cementers as they were stuck behind a rig move on the spine road. Continue circulating & conditionin mud. 17:30 18:00 0.50 4,653 4,653 SURFA CEME RURD P Rig up Dowell cement crew. Start batch mixin . 18:00 18:30 0.50 4,653 4,653 SURFA CEME DISP P Held PJSM with crew & Dowell reps. Discuss safety & hazard recognition issues. Discuss procedure to pump balanced cement plug. Shut down pumps and turn over to Dowell. Pressure test lines to 3000 PSI. Pump 10 BBLS 8.5 water, followed with 51 BBLS of 17.0 PPG Cement, and 1.5 BBLS of water. 18:30 19:00 0.50 4,653 4,653 SURFA CEME DISP P Turn over to rig. Displace cement to balance pumping a total of 42 BBLS 80 PSI - 3 BPM. 19:00 19:30 0.50 4,463 3,835 SURFA CEME TRIP P POOH 10 stands from 4653' - 3835' 19:30 20:45 1.25 3,835 3,835 SURFA CEME CIRC P Circulate down DP at 5 BPM - 300 PSI observing approximately 10 BBLS contamintated cement. Rig up and reverse circulate hole volume to ensure no cement in drill strip . 20:45 22:15 1.50 3,835 1,026 SURFA CEME TRIP P POOH on elevators from 3835' - 1026', rackin back 4" DP. 22:15 23:15 1.00 1,026 1,026 SURFA CEME RURD P Rig up tbg tuning equipment. Change elevators and slips. Prep floor and pipe shed to la down tb . 23:15 00:00 0.75 1,026 620 SURFA CEME PULD P POOH, breakout & lay down 20 jnts of 3 1/2" tb stin er. Crew Chan e 12/13/2007 00:00 00:30 0.50 620 0 SURFA CEME PULD P Continue POOH lay down 3 1/2" tbg stin er and muleshoe. 00:30 01:15 0.75 0 0 SURFA CEME RURD P Rig down tbg running equipment. Clean & clear ri floor of tools. 01:15 01:30 0.25 0 0 SURFA WELCT EQRP P BOLDS. Pull wear bushing. f~~ge 8 of 4Al ~~t Time Logs Date____ From 7o Dur S. De th E__D~pth Phase Code. Subcode T COM _______ 12/14/2007 02:00 02:15 0.25 0 0 SURFA DRILL SFTY P Held PJSM with crew, DD &MWD reps. Discuss safety & hazard recognition issues. Discuss procedure to ick u 8 1/2" Drillin BHA. 02:15 03:30 1.25 0 60 SURFA DRILL PULD P Make up 8 1/2" Hughes bit & motor. Make u MWD assembl . 03:30 04:30 1.00 60 60 SURFA DRILL PULD P Plug in and upload MWD assembly. 04:30 09:00 4.50 265 3,555 SURFA DRILL PULD P Make up remaining BHA with HWDP and jars. Total BHA length = 631'. Perform shallow pulse test with pumps @ 500 GPM's - 750 PSI. Good test. Continue trip in hole picking up a total of 93 'nts of 5" DP. 09:00 09:30 0.50 3,555 3,826 SURFA DRILL TRIP P Continue trip in hole from derrick with BHA. T hard cement at 3826' DPM. 09:30 10:30 1.00 3,826 3,826 SURFA DRILL DHEQ P Rig up and perform casing test to s. Record on chart. 10:30 12:00 1.50 3,826 4,027 SURFA CEME DRLG P Drill cement from 3826' - 4027' DPM. UP WT = 115K, SO WT = 65K, ROT WT = 80K. Crew Chan e 12:00 13:30 1.50 4,027 4,263 SURFA CEME DRLG P Continue drill cement from 4027' - 4263' DPM. (shoe depth) UP WT = 115K, SO WT = 65K, ROT WT = 80K. CBU. 13:30 13:45 0.25 4,263 4,283 SURFA DRILL DDRL P Continue directional drill 20' of new hole from 4263' - 4283' MD. TVD = 2662' 13:45 15:30 1.75 4,283 4,283 SURFA DRILL LOT P Rig up and perform LOT to 14.0 PPG, with 9.0 PPG LSND mud. 15:30 18:00 2.50 4,283 4,307 INTRM1 DRILL DDRL P Directional drill 8 1/2" Intermediate hole from 4283' - 4307' MD. TVD = 2679'. ADT = .58 HRS. Bit Hrs = .58. ECD = 9.61 PPG. MAx gas = 740 Units. 18:00 00:00 6.00 4,307 4,868 INTRM1 DRILL DDRL P Directional drill 8 1/2" Intermediate hole from 4307' - 4868' MD. TVD = 2973'. ADT = 4.29 HRS. Total Bit Hrs = 4.87 ECD = 10.74 PPG. MAx gas = 87 Units. Crew Chan e 12/15/2007 00:00 06:00 6.00 4,868 5,433 INTRM1 DRILL DDRL P Directional drill 8 1/2" Intermediate hole from 4868' - 5433' MD. TVD = 3400'. ADT = 3.81 HRS. Total Bit Hrs = 8.68 ECD = 11.45 PPG. Max gas = 55 Units. 06:00 12:00 6.00 5,433 6,002 INTRM1 DRILL DDRL P Directional dri118 1/2" Intermediate hole from 5433' - 6002' MD. TVD = 3913'. ADT = 3.57 HRS. Total Bit Hrs = 12.25 ECD = 11.34 PPG. Max gas = 209 Units. Obtain SPR's. Crew Chan e 12:00 18:00 6.00 6,002 6,730 INTRM1 DRILL DDRL P Directional drill 8 1/2" Intermediate hole from 6002' - 6730' MD. TVD = 4582'. ADT = 4.20 HRS. Total Bit Hrs = 16.45 ECD = 11.38 PPG. Max gas = 538 Units. Wage 1i1 of 44 r C~ ~ Time Logs _ __ Date From To Dur S De th E. Depth Ph e Code Subcode T COM 12/15/2007 18:00 19:00 1.00 6,730 6,853 INTRM1 DRILL DDRL P Directional drill 8 1/2" Intermediate hole from 6730' - 6853' MD. TVD = 4694'. ADT = .73 HRS. Total Bit Hrs = 17.18 ECD = 11.38 PPG. Max gas = 538 Units. 19:00 19:30 0.50 6,853 6,853 INTRM1 DRILL OWFF P Obtain surveys. Monitor well -static. Blow down To Drive & lines. 19:30 21:15 1.75 6,853 4,216 INTRM1 DRILL TRIP P Short trip back to shoe at 4216' pulling on elevators with no hole issues. Observed ro er dis lacement. 21:15 21:45 0.50 4,216 4,216 INTRM1 DRILL CIRC P Circulate bottoms up at 500 GPM's - 1500 PSI. UP WT = 120K, SO WT = 70K. 21:45 22:00 0.25 4,216 4,216 INTRMI DRILL OWFF P Monitor well -static. Blow down Top drive & lines. 22:00 23:30 1.50 4,216 6,760 INTRMI DRILL TRIP P Trip back in hole to 6760' MD. No hole issues, and proper displacement. Clean hole. 23:30 00:00 0.50 6,760 6,853 INTRM1 DRILL REAM P Wash down last 93' to 6853' with pumps @ 630 GPM's - 2350 PSI. Mode switch MWD assembly. Crew Chan e 12/16/2007 00:00 06:00 6.00 6,853 7,419 INTRM1 DRILL DDRL P Directional drill 8 1/2" Intermediate hole from 6853' - 7419' MD. TVD = 5197'. ADT = 3.94 HRS. Total Bit Hrs = 21.12 ECD = 11.04 PPG. Max gas = 138 Units. 06:00 12:00 6.00 7,419 7,704 INTRM1 DRILL DDRL P Directional drill 8 1/2" Intermediate hole from 7419' - 7704' MD. TVD = 5432'. ADT = 3.51 HRS. Total Bit Hrs = 24.63 ECD = 10.97 PPG. Max gas = 331 Units. Crew Chan e 12:00 18:00 6.00 7,704 7,953 INTRM1 DRILL DDRL P Directional drill 8 1/2" Intermediate hole from 7704' - 7953' MD. TVD = 5610'. ADT = 4.15 HRS. Total Bit Hrs = 29.32 ECD = 11.14 PPG. Max gas = 236 Units. 18:00 00:00 6.00 7,953 8,102 INTRM1 DRILL DDRL P Directional drill 8 1/2" Intermediate hole from 7953' - 8102' MD. ND = 5689'. ADT = 2.47 HRS. Total Bit Hrs = 31.79 ECD = 11.14 PPG. Max gas = 334 Units. Observed increase in pump pressure @ 2200 HRS @ 8011' MD, suspecting plugged jet- Pump rate slowed to hold @ 550 GPM's - 3000 PSI off bottom. Crew Chan e 12/17/2007 00:00 06:00 6.00 8,102 8,401 INTRM1 DRILL DDRL P Directional drill 8 1/2" Intermediate hole from 8102' - 8401 MD. TVD = 5803'. ADT = 4.05 HRS. Total Bit Hrs = 35.84 ECD = 11.26 PPG. Max gas = 247 Units. 06:00 06:30 0.50 8,401 8,401 INTRM1 RIGMN RGRP T Trouble shoot Top Drive issue. Could not Rotate drill string. Reset PLC drive mode in control house. Function test same. Page 'i 1 t~f 44 • Time Logs - - - - --- Date From To Dur S Depth E. De th Phase Code Suhcode T COM 12/17/2007 06:30 12:00 5.50 8,401 8,564 INTRM1 DRILL DDRL P Directional drill 8 1/2" Intermediate hole from 8401' - 8564' MD. TVD = 5829'. ADT = 2.94 HRS. Total Bit Hrs = 38.78 ECD = 11.28 PPG. Max gas _ 305 Units. Crew Chan e 12:00 16:00 4.00 8,564 8,825 INTRMI DRILL DDRL P Directional drill 8 1/2" Intermediate hole from 8564' - 8825' MD. TVD = _ 5850'. ADT = 2.97 HRS-Total Bit Hrs = 41.75 ECD = 11.31 PPG. Max gas = 483 Units. section TD'd as per DD. 16:00 16:30 0.50 8,825 8,825 INTRM1 DRILL OWFF P Monitor well -static. Obtain Final surve son bottom. Obtain SPR's. 16:30 19:30 3.00 8,825 6,760 INTRM1 DRILL REAM P BROOH at drilling rates from 8825' - 6760' MD. Observed good hole conditions & proper displacement. UP WT = 165K, SO WT = 110K. 19:30 19:45 0.25 6,760 6,760 INTRM1 DRILL OWFF P Monitor well -static. 19:45 20:45 1.00 6,760 8,715 INTRM1 DRILL TRIP P Trip back in hole on elevators with no issues from 6760' - 8715'. Observed ti ht s of 8715'. 20:45 21:30 0.75 8,715 8,825 INTRMI DRILL REAM P Wash & ream down last 2 stands at drilling rates. Work through tight spot at 8715' MD until hole cleaned up, washing to tag bottom again @ 8825' MD. 21:30 00:00 2.50 8,825 8,825 INTRM1 DRILL CIRC P Circulate & condition mud pumping a total of 3 bottoms up to verify hole clean. reciprocate & rotate drill string with um sat 650 GPM's - 3500 PSI. 12/18/2007 00:00 00:15 0.25 8,825 8,825 INTRM1 DRILL OWFF P Monitor well -static. Blow down Top Drive & lines. 00:15 02:15 2.00 8,825 4,263 1NTRM1 DRILL TRIP P POOH on elevators from 8825' to the shoe @ 4263'. Observed no issues, and ro er dis lacement. 02:15 02:30 0.25 4,263 4,263 INTRM1 DRILL OWFF P Monitor well -static. 02:30 03:45 1.25 4,263 630 INTRM1 DRILL TRIP P Continue POOH on elevators from 4263' - to BHA. Observed proper dis lacement. 03:45 06:00 2.25 630 0 INTRM1 DRILL PULD P Breakout & lay down 5" HWDP, and Flex drill collars. Plug in and download MWD assembly. Lay down remainig BHA. Inspect Bit, and Grade to 1,1,HC,C,X,1,PN,TD 06:00 07:00 1.00 0 0 INTRM1 DRILL PULD P Clean and Clear all tools from rig floor 07:00 07:15 0.25 0 0 INTRM1 DRILL SFTY P PJSM -Changing out pipe rams - Discuss all know hazards and review rocedure. 07:15 07:45 0.50 0 0 INTRM1 WELC NUND P RU 4" Dp and pull wear bushing 07:45 08:00 0.25 0 0 INTRM1 WELCT NUND P Install test plug - PU 7" Test joint. 08:00 08:45 0.75 0 0 INTRM1 WELCT NUND P Install 7" casin rams in lower BOP bod . Pas~~ 12 of 4~ • • Time Logs Date From To Dur S De th_ E. Depth Phase Code Subcode T COM 12/18/2007 08:45 09:15 0.50 0 0 INTRM1 WELC BOPE P Test 7" Csg rams 250 psi low and 3500 si hi h on chart "All OK" 09:15 09:30 0.25 0 0 INTRM1 CASINC SFTY P PJSM -Discuss rigging up tools, hazards and each team members res onsibili 09:30 10:30 1.00 0 0 INTRM1 CASINC RURD P RU casing tools on rig floor 10:30 10:45 0.25 0 0 INTRM1 CASINC SFTY P PJSM -Running csg and all know hazards. Discuss running detail and each team members res onsibilit . 10:45 12:00 1.25 0 420 INTRM1 CASIN RNCS P Run csg installing centrilizers per detail. 10 'ts in Hole 12:00 12:15 0.25 420 420 INTRM1 CASIN CIRC P PJSM -Run Casing -All know Hazards 12:15 16:45 4.50 420 4,243 INTRM1 CASINC RNCS P Run 7" Csg from 420' to 4243' MD, Hole showing proper fill - No fluid loss - PU wt 100k, Dn wt 75k 16:45 17:30 0.75 4,243 4,243 INTRM1 CASINC CIRC P Circulate 1 csg volume @ 9 5/8" shoe ( 4263' MD) Stage pump up to 5 bpm, PP 500 si - No fluid loss. 17:30 00:00 6.50 4,243 8,079 INTRM1 CASIN RNCS P Run 7" 26# L80 BTC-M casing from 4263' to 8079' MD Up wt 206k, Dn 110k (@ Midnight had 195 jts out of 212 jts ran. Well bore giving proper displacement - Taking T & D data points every 10 joints. -Pumping down every 10th joint to introduce freash mud into s stem. 12/19/2007 00:00 12:00 12.00 8,079 8,734 INTRM1 CASINC RNCS T Con't running 7" 26# L80 BTC-M casing from 8079' to 8664' -Lost all slack off wei ht. Joint 210 out of 213. Worked and washed but unable to recover down weight. LD jt 210. Lost some fluid to well bore est 18 to 20 bbls. Working slowly were able to wash and work strin to 8734' ve slow ro ress ushin and off. Est Lost +/- 4 12:00 12:30 0.50 8,820 8,820 INTRM1 CASINC CIRC P LD Franks tool and PU Cmt Head w/ lu s 12:30 14:45 2.25 8,734 8,820 INTRM1 CASINC RUNL T Con't working casing down slowly from 8734' to 8820' MD (Csg point), packing off, sticking. No mud losses. U wt 235k, Dn wt 105k 14:45 15:30 0.75 8,820 8,820 INTRM1 CASINC CIRC P Circu and Condition mud for CMT PD 5 bpm, 600 psi. Recip 20' Up wt 235k, Dn wt105k C~~e 13 csf ~~ Time Logs ___ ____ ~ Date From To Dur S D th E. D~th Phase Code Subcode T COM _ I 12/19/2007 15:30 18:15 2.75 8,820 8,795 INTRM1 CEME CIRC P Cementing -Dowell pump 5 bbl Mud push, Test lines 3000 psi, Con't pump 25 bbls Mud push, drop bttm plug, pump 38 bbls 15.8 ppg slurry, drop top plug and washup with 10 bbls H2o. Turn over to rig. The rig displaced with 3231 stks and bumped plug. Held 5 min to 1800 psi. Ck floats "OK" " Note "While recipricating the string the last 20 bbls prior to bump the string stuck on the upstroke @ 8795.46' MD. We were unable to work back below this depth. Shoe depth is 8795' MD / 5848' TVD / 85.24 inclination 18:15 21:30 3.25 8,795 0 INTRM1 CEME RURD T String stuck @ 8795' -Will set Emergency slips -Drain stack -Set emergency slips -Set with 200k indicator weight (95k on slips) -FMC rep cut csg and LD same -FMC rep dressed and fitted for ackoff. 21:30 23:00 1.50 0 0 INTRM1 CASIN NUND P Install and Test Packoff -FMC test 3000 si /min "OK" 23:00 00:00 1.00 0 0 INTRM1 CASiN( NUND P RD casing tools -Secure stack - RU to flush annulus. 12/20/2007 00:00 00:15 0.25 0 0 INTRM1 RPCOh SFTY P PJSM -Discuss Freeze protect roceedure on 9 5/8" X 7" ann. 00:15 02:00 1.75 0 0 INTRMI RPCO FRZP P SIOPS -Install 4" pipe reams and test same 250 low and 3500 psi high on chart -Pump 9 5/8" X 7"annulus flush. Pump 130 bbls total sea water, PR 3 b m, ICP 800 si, Final 850 si 02:00 02:15 0.25 0 0 INTRM1 RIGMN SFTY P PJSM -Discuss known hazards - Review procedure - CO to 4" XT39 saver sub 02:15 04:00 1.75 0 0 INTRM1 DRILL RURD P Change out saver sub to XT 39 connection. 04:00 04:15 0.25 0 0 INTRM1 RIGMN SFTY P PJSM -Discuss all known hazards - Review procedure Slip and Cut drill line 04:15 05:30 1.25 0 0 INTRM1 RIGMN SVRG P Slip and Cut drill line (82' Cut} 05:30 06:00 0.50 0 0 INTRM1 RIGMN SVRG P Service Top Drive 06:00 06:15 0.25 0 0 INTRM1 RIGMN SFTY P PJSM -Discuss laying down 5"drill i e from derrick and known hazards. 06:15 12:00 5.75 0 0 INTRMI DRILL PULD P RU and LD 5" drill pipe from derrick - SIOPS -Little Red Hot oil pump 120 bbls diesel to freeze protect 9 5/8" X 7" OA. PR 2 - 3 bpm, ICP 700 psi, FCP 1450 si 12:00 12:30 0.50 0 0 INTRM1 DRILL PULD P Con't to LD 5"drill pipe from derrick. P~e~e 1A of ~4 n ~~ Time Lo s Date _ _ From To Dur S_Dgpth E. Depth Phase Code Subcode T COM __ 12/20/2007 12:30 13:30 1.00 0 0 INTRM1 DRILL SFTY P ~-leld safety stand down and discussed recent incidents and spills within the company and other places. Stressed the fact that "ALL" Spills and Incidents hurt the integrity of the perception of the oilfield by the common person. Gave the hands time to dwell on their art of these events. 13:30 14:30 1.00 0 0 INTRM1 DRILL PULD P LD remaining 5" DP from derrick. 14:30 15:30 1.00 0 0 INTRM1 DRILL PULD P Change out handling tools to 4" XT 39 -RU toPU4"DP 15:30 16:30 1.00 0 0 INTRM1 DRILL RURD P Finish removing all 5" DP from pipe shed -Roll in and strap NEW 4" XT 39 DP 16:30 19:00 2.50 0 0 INTRM1 DRILL PULD P PU 5 stds 4" DP and stand back in derrick -Service broken keeper pin in new 4" elevators. 19:00 22:30 3.50 0 403 INTRM1 DRILL PULD P PJSM - PU AnnaDril BHA #1 (#9 for well RA sources 22:30 00:00 1.50 403 717 INTRMI DRILL TRIP P Singles in hole w/ NEW Weatherford XT 39 Dp -Running pipe by Weatherford rocedure make and break twice. 12/21/2007 00:00 01:00 1.00 717 717 INTRM1 DRILL SFTY P Safety Stand Down. Discuss recent incidents and spills. Stress to crews to stay alert and focus on the task at hand. 01:00 01:30 0.50 717 1,337 INTRM1 DRILL PULD P Con't single in w/ New XT39 DP out of pipe shed (20 jts) Use make, break rocedure as above. 01:30 01:45 0.25 1,337 1,337 INTRM1 DRILL SRVY P Shallow test MWD"Pulse OK" 01:45 08:45 7.00 1,337 5,117 INTRM1 DRILL PULD P Con't single in w/ New XT39 DP out of pipe shed (120 jts) Use make, break rocedure as above. 08:45 10:15 1.50 5,117 8,615 INTRMI DRILL PULD P Con't single in XT39 DP (Old String) out of pipe shed (105 jts) (Total 141 stds) 90 STDS in hole & 51 STDS in derrick - Ta Cmt 8705' MD 10:15 10:30 0.25 8,615 8,705 INTRM1 DRILL PULD P Run DP out of derrick -Tag Cmt @ 8705' MD w/ 10k - On ro er de th - 10:30 11:00 0.50 8,705 8,705 INTRMI DRILL CIRC P Circu air from system one DP volume 11:00 12:00 1.00 8,705 8,705 INTRM1 DRILL DHEQ P RU and Preform Casing test to 3000__ si - **NOTE** 18 min into test a slight pressure loss was noted. Upon checking it wad noted that one glan nut on the LDS of the well head was leaking. The pressure was bleed off and the Ian nut was re-tor ued. 12:00 12:45 0.75 8,705 8,705 INTRM1 DRILL DHEQ P Casin was re-tested to 3000 psi f/ 30 min on chart. No pressure loss. - Bleed ressure - RD test a ui 12:45 18:30 5.75 8,705 8,825 INTRM1 CEMEf` COCF P Drlg out shoe track -Had trouble drillin rubber 2:45 min to 8825' MD laage 15 of 44 • Time Logs ---- -- - Date _ From To Du_r 5. Depth E Depth Phase Code_ Subcode T COM 12/22/2007 18:30 23:00 4.50 8,677 8,886 PROD1 DRILL REAM T Madd Pass -Hole packing off 8677' to 8830' MD (Packing off -Tight getting back into shoe) Ream and clean 8793 to 8886' several times. -Raise mud wei ht .2 to 9.2 23:00 00:00 1.00 8,886 8,900 PROD1 DRILL DRLG P Drlg 6 1/8" hole w/ Power Drive & Periscope f/ 8886' to 8900' MD, 5891' ND, ADT .25 hrs, Jar hrs 117.86 Sr# 1400-1358, Up wt 150k, Dn wt 92k, Rot wt 110k, Torq on bttm 11 k, off bttm 13k, ECDs 10.6 ,Max gas 1189 units. *'Note"* Mud weighted up to 9.2 for sand stabilit . 12/23/2007 00:00 07:45 7.75 8,900 8,976 PROD1 DRILL DRLG P Drlg 6 1/8" hole w/ Power Drive & Periscope from 8900' to 8976' MD / 5859' ND, ADT 6.57 hrs, Max gas 247, ECDs 10.84, Up wt 150k, Dn wt 87k, Rot wt 112k, Torq on bttm 13k, Off bttm 14k. Survey showing 22 deg do le , DD wants to run check shots. 07:45 08:45 1.00 8,895 8,955 PROD1 DRILL SRVY T MWD showed 22 deg dogleg @ 8935' MD. We will set back a stand of drill pipe and reshoot surveys. After re-shooting all surveys and matching them up it showed a 10.4 deg dogleg @ 8935' MD. We will work the area and reduce as much as ossible. 08:45 09:15 0.50 8,895 8,895 PROD1 DRILL DRLG T Top Drive Rotation shut down. Showed drive fault Over Tem 09:15 12:00 2.75 8,976 9,000 PROD1 DRILL DRLG P Con't Drlg 6 1/8" hole w/ Power Drive & Periscope from 8976' to 9000' MD / 5860' ND, ECDs 10.69, Max gas 320 units 12:00 00:00 12.00 9,000 9,190 PROD1 DRILL DRLG P PJSM - Con't Drig 6 1/8" hose w/ Power Drive & Periscope from 9000' to 9190' MD / 5849' ND, ADT 10.37 hrs, Up wt 170k, Dn wt 77k, Rot wt 112k, Torq off bttm 13k, on bttm 12k, ECDs 10.84, Mud wt 9.2 ppg, Max gas 103 units, Jars # 1400-1358 /hrs 136.78 12/24/2007 00:00 04:30 4.50 9,190 9,335 PROD1 DRILL DRLG P Drlg w/ Power Drive w/ Periscope f/ 9190' to 9335' MD / 5843' ND, ADT 4.29, Up wt 180k, Dn wt 75k, Rot wt 110k, Torq on bttm 13k, off bttm 14k, WOB 5-10, RPMs 130, ECDs 11.10, Max as 2300 units 04:30 12:00 7.50 9,335 9,335 PROD1 WELCT KLWL T Circu Gas influx from well. Increase mud wt from 9.2 ppg to 10.0, Max gas 3016 units. 12:00 18:00 6.00 9,335 9,335 PROD1 WELC KLWL T Con't Circu Gas influx from well. Increase mud wt from 10.0 ppg to 10.5 ppg .With 10.4 ppg mud in and out - Background gas 488 units. May need to oto10.7or10.8 F~~ge 17 gat ~4 • Time Logs__ _ _____ _ _ Date From To Dur S. De th E. Depth_ Phase Code Subcode_ T_ COM 12/26/2007 03:15 04:00 0.75 9,669 9,669 PROD1 DRILL CIRC T CBU with maxium gas of 2,247 units and no oil in mud. MW cut to 11.3+ ppg from 11.5 ppg on the pressured scale and 10.9 ppg on the non- ressured scale. 04:00 07:00 3.00 9,669 9,669 PROD1 DRILL CIRC T Circ hole increasing MW from 11.5 to 11.8 07:00 07:30 0.50 9,669 9,669 PROD1 DRILL OWFF T Performed 20 min breathing test with 11.8 ppg MW in the hole, 1st 5 min gained 3.5 bbls, flow slowed to 2.2 bbls last 5 min. Last 10 min ave .39 b m. Gained 10.5 bbls Burin test. 07:30 09:15 1.75 9,669 9,669 PROD1 DRILL CIRC T Circ btms up and had a max of 1,867 units at BU, 11.8 ppg in had 11.6 ppg out with pressure scale and 11.2 ppg out non pressured scale, circ an add. btms up at 180 gpm, 1,550 psi with 11.8 ppg MW in and out, ave BGG 180 units. cont. to ave 5-8 bpm losses while circ. 09:15 09:45 0.50 9,669 9,669 PROD1 DRILL OWFF T Performed 2nd - 20 min breathing test with 11.8 ppg MW in the hole, 1st 5 min gained 5 bbls, flow slowed to 1.7 bbls last 5 min. last 10 min of the test ave .44 bpm. Gained 12.4 bbls during test. 09:45 10:45 1.00 9,669 9,669 PROD1 DRILL CIRC T Circ btms up and had a max of 1,911 units at BU, 1st test had 1,867 units, gas usually stays above 500 to 1200 units for approx 20 min after btms up. With 11.8 mw was seeing 12.6 to 12.8 ECD at 198 m. 10:45 15:00 4.25 9,669 9,669 PROD1 DRILL CIRC T Circ hole increasing MW from 11.8 to 12.0 .Circulate at 179 gpm with 1,500 psi, increasing to 198 gpm with 1,800 psi and 12.0 ppg mud weight in and. out. ECD equal 13.0 ppg, slowed rate to 179 gpm to control ECD. As of 12:00 hrs had cummulative losses of approx 91 bbls during the last 12 hrs with the loss rate continuing at approx 5-8 b h. 15:00 15:30 0.50 9,669 9,669 PROD1 DRILL OWFF T Performed 30 min breathing test with 12.0 ppg MW, in the 1st 5 min gained 2 bbls and at the end of 30 min's the rate was at 1 bbl per 5 min, last 15 min rate slowed to an ave rate of .25 b m. 15:30 22:00 6.50 9,669 9,669 PROD1 DRILL CIRC T Circ btms up at 173 gpm, with 1,450 psi and had Max gas = 2,084 units. 12.0 ppg MW cut to 11.8 ppg on the pressured scale. Continue circulating and bring MW up to 12.3 ppg. Total losses during previous 10 hours = 42 bbl. I~ag~ 13 ~f ~X4 • Time Logs Date From To Dur S De th E. De th Phase Code Subcode T COM _ 12/26/2007 22:00 00:00 2.00 9,669 9,669 PROD1 DRILL OWFF T _ Perform 30 minute exhale test with flow of 1 bpm during the first 10 minutes and decreasing to 0.64, 0.34, 0.17, 0.08 bpm for each of the subsequent 5 minute intervals. Avg flow during the last 15 minutes was 0.19 bpm vs 0.25 bpm during the exhale test with 12.0 ppg mud in the hole. Total gain was 3.27 bbl. CBU with the max gas = 718 units and MW In/Out = 12.3 ppg on the pressured scale and 12.25 on the non-pressured scale. 12/27/2007 00:00 03:00 3.00 9,669 9,669 PROD1 DRILL CIRC T Fin circ and increasing the mud wt from 12.3 ppg to 12.5 ppg, circ hole at 160 mat 1,200 si. 03:00 03:30 0.50 9,669 9,669 PROD1 DRILL OWFF T Performed 30 min breathing test with 12.5 ppg MW. First 5 min gained 1.2 bbls and the final 5 min had no gain. The avg flowrate for the final 15 minutes was 0.03 b m. 03:30 04:45 1.25 9,669 9,669 PROD1 DRILL CIRC T Circ btms up after breathing test with max gas at btms up of 386 units. MW= 12.5 ppg on both pressure scale and non- ressured scale. 04:45 05:15 0.50 9,669 9,669 PROD1 DRILL OWFF T Performed 2nd 30 min breathing test with 12.5 ppg MW. During the 1st 5 min gained 2.38 bbls and the final 5 minute interval gained 0.09 bbl. The average flowrate was 0.05 bpm for the final 15 min. 05:15 06:30 1.25 9,669 9,669 PROD1 DRILL CIRC T Circ btms up after the 2nd breathing test with max gas at btms up of 625 units. Circulated at 160 gpm and 1,200 si. 06:30 07:30 1.00 9,669 9,669 PROD1 DRILL CIRC T Circ an add. btms up and with 12.5 ppg MW in and out. Average BGG was 64 units. 07:30 08:30 1.00 9,669 8,771 PROD1 DRILL TRIP T Pum ed out of hole from 9.669' to 771' Csq shoe at 8,795'). Pumped out at 2 bpm, 500 psi, and ave drag of 15-20K. No packing off problems. Drag at 9,382' was 70-75K, at 9,288 drag was 50-60K and from 9,147'-9,054', 50-60K. Worked thru spots w/no other problems. String. wt up 175K, do wt 75K at shoe. 08:30 09:45. 1.25 8,771 8,771 PROD1 DRILL CIRC T Circ 1 complete hole volume at 8,771', Circ at 160 gpm and 1,270 psi, with 50 rpm and 12-14K ft-Ibs torque. after btms up. Max gas was 216 units aftrer Btms up, dropping back to BGG of 68 units. Page 2t3 e~f 44 Tme Logs Date From To ------- Dur S_ Dgpth D~h E Phase Code Subcode - T ---- COM 12/27/2007 _ 09:45 10:30 0.75 _ 8,771 _ 8,771 PROD1 _ DRILL OWFF T _ _ _-___ Performed 30 min breathing test with 12.5 ppg MW. During 1st 5 min interval gained 1.36 bbls and gain dropped to 0.17 bbl during the final 5 min. Avg flowrate during final 15 min was 0.04 b m. 10:30 11:30 1.00 8,771 8,771 PROD1 DRILL CIRC T Circ btms up after monitoring well and max gas at btms up was 123 units, circ at 160 mat 1,250 si 11:30 12:00 0.50 8,771 8,771 PROD1 DRILL OWFF T Monitored well during crew change and well was static. Lost approx 86 bbls Burin last 12 hrs. 12:00 15:00 3.00 8,771 4,833 PROD1 DRILL TRIP T Pumped out of hole 10 stds to 7,830'. Blew down top drive and cont. to POOH wet, on elevators to 4,833'. Stringt wt up 95K, do wt 65K. Calculated fill on trip out was 24.9 bbls, actual fill was 25.7 bbls. 15:00 17:00 2.00 4,833 4,849 PROD1 DRILL OTHR T Held PJSM then MU 7" Baker Storm packer setting same at 39' rkb with bit at 4,849'. Tested packer to 500 psi for 5 min., then ulled wear bushin . .17:00 00:00 7.00 4,849 4,849 PROD1 WELCT ROPE P RU and tested BOPE. Tested rams, valves and choke manifold to 250 psi low and 3,500 psi high, including annular. Tested with 3 1/2", 4" and 4 1/2" test jts. Performed Koomey test, initial press. 3,000 psi, press. after functioning 1,700, psi, took 45 sec's for 200 psi recovery and 3 min, 14 sec for full recovery. NOTE: Jim Regg with AOGCC waived witnessin of the test. 12/28/2007 00:00 00:30 0.50 4,849 4,849 PROD1 WELCT BOPE P Fin. testing 4" lower pipe rams w/ 4" and 4-1/2"test Jts. Test Variable 3.5 x 6" pipe rams and annular with 3.5" test Jt. Test Blind rams to 250/3,500 si hi/low. RD test a ui . 00:30 01:00 0.50 4,849 4,849 PROD1 DRILL OTHR P Install wear bushing. 01:00 02:15 1.25 4,849 4,849 PROD1 RIGMN SVRG P PJSM. Slip and cut 65' of DL. 02:15 02:45 0.50 4,849 4,849 PROD1 RIGMN SVRG P Service TD 02:45 03:15 0.50 4,849 4,849 PROD1 WELCT OTHR T PJSM, PU pup jt + 1 Jt of DP +TIW valve. RIH and screw into Storm Pkr. Shear pin and opened plunger inside pkr to equalize. Cracked open TIW and checked for gas. Bled off estimated 1 al of as. Released kr. 03:15 03:30 0.25 4,849 4,849 PROD1 DRILL OWFF T Top off hole with mud and observe well. No gas bubbles seen. Lost 1.7 bbls while observin well for 15 min. 03:30 04:15 0.75 4,849 4,833 PROD1 DRILL PULD T Pull Storm Pkr to floor, service break and LD. PU Anadril Nuke box to floor to thaw out, for storin in-hole nukes. Page 21 of ~#d Time Logs _ date From To Dur S De th E. De th Phase Code $ubcode T COM 12/28/2007 04:15 06:00 1.75 4,833 2,474 PROD1 DRILL TRIP T POOH wet on elevators from 4,833' to 2,474', DP out of balance and running over. 06:00 07:45 1.75 2,474 2,474 PROD1 DRILL CIRC T Circ hole balancing MW in and out, had 11.7 ppg out initially, no gas, pumped dry job and blew down top drive. 07:45 08:45 1.00 2,474 494 PROD1 DRILL TRIP T POOH from 2,474' to 494', leaving 1 std of 4" DP and BHA in the hole. 08:45 09:45 1.00 494 494 PROD1 DRILL OWFF T Monitored well on the trip tank while Anadril was trouble shooting problems with the Periscope tool for the next BHA Hole took 1.75 bbls. Anadril technician from Deadhorse enroute to ri . 09:45 12:00 2.25 494 0 PROD1 DRILL PULD T POOH from 494' and stood back HWDP, jars and NMFDC's, held PJSM, then removed radioactive sources, then fin. LD BHA #10 and cleared rig floor. Calc fill on trip out was 16 bbls, actual fi1121 bbls. 12:00 12:45 0.75 0 211 PROD1 DRILL PULD T MU 6 1/8" bit #4 on Anadril 4-3/4", 1.5 deg bend motor and RIH with HWDP and jars to 211'. Sent Periscope tool that was LD to Deadhorse for parts on the new tool. 12:45 19:45 7.00 211 211 PROD1 DRILL OWFF T Monitored well on trip tank while waiting on new Periscope tool from Deadhorse. well taking on the ave. of 2 bph, lost a total of 9.75 bbls to the hole. 19:45 20:15 0.50 211 211 PROD1 DRILL TRIP T POOH and stand back HWDP and Jars. PU/MU new MWD/Periscope and orientate same. RIH w! Flex DCs and PU Circulatin sub 20:15 00:00 3.75 211 3,212 PROD1 DRILL TRIP T RIH and shallow test MWD at 850' and 1,320'. Blow down TD and continue RIH to 3,212' md. 12/29/2007 00:00 07:00 7.00 3,212 9,669 PROD1 DRILL TRIP T Cont. RIH from 3,212' to 8,750', (csg shoe @ 8,795') filled pipe, st wt up 180K, do 75K, then RIH from 8,750' and stacked out at 9,230', PU then ran thru spot w/no problems, cont. RIH saw add. drag thru shale then washed down std from 9,313' to 9,406' thru top of sand then RIH to 9,594' and washed down to btm at 9,669', washed down at 112 gpm, 1,000 psi, 20 rpm's with 13K ft-Ibs for ue. Page 22 of 44~ Time Logs _ _ _ _ _ Date From To Dur 5 De th E. De th Phase Code Subcode T COM 12/29/2007 07:00 10:30 3.50 9,669 9,669 PROD1 DRILL CIRC T Circ btms up at 9,669', max gas at . btms up 761 units, had 14.0 ppg MW out prior to btms up (barite ), circ hole at 112 gpm, 1,250 psi, 50 rpm's and 13K ft-Ibs torque. Circ hole till 12.5 ppg MW in and out then was able to increase the pump rate to 150 gpm, 1,350 psi with a 13.4 ppg ECD with no losses. 10:30 12:30 2.00 9,669 9,669 PROD1 DRILL CIRC T Displaced hole over from 12.5 ppg mud to new 10.9 ppg Flo-Pro, initial circ rate 140 gpm, 1,500 psi at 50 rpm's and had 13.7 ppg ECD for a short period then began to decrease below 13.0 ppg, slowly increased pump rate to 200 gpm 1,825 psi and 100 r ms with a 12.09 ECD. 12:30 15:45 3.25 9,669 9,669 PROD1 DRILL CIRC T Cont. to circ hole and shear new mud while finishing offloading mud into pits, circ hole at 200 gpm, 1,825 psi, 100 rpm's with 12.09 ECD, while shearing mud began to MADD pass section for geologist when MWD tool failed, took SPR's and cycled pumps twice for MWD then circ btms up, had 5,299 units of as at btms u with oil on the shakers. Mud wt out pressured. scale 10.8 , 9.4 non- ressured. 15:45 22:45 7.00 9,669 9,669 PROD1 DRILL CIRC T Circ and raised MW from 10.9 ppg to 11.3 ppg, varied pump rates (200 - 140 gpm) attempting to get MWD tool to work, cycled pumps 2x and brought pump rate up to 170 gpm wino success, Max gas at CBU= 2,406 units. Continue circ and weighting up to 11.3 ppg. Max gas at 2nd CBU= 2,117 units. Cycled pumps 2x more but no response from MWD at 140 gpm. Continue circ and wt up to 11.3 ppg with final Max gas at CBU= 346 units. Continue to circ 11.3 mud In/Out and transfer 12.5 ppg to pits for dis lacement. 22:45 00:00 1.25 9,669 9,669 PROD1 DRILL CIRC T Displace well back to 12.5 ppg mud at 170-180 gpm slowing to 125 gpm after mud exited the 7" casin . 12/30/2007 00:00 01:30 1.50 9,669 9,669 PROD1 DRILL CIRC T Fin. displacing hole over to 12.5 ppg mud, circ hole at 120 gpm at 1,000 si. 01:30 02:00 0.50 9,669 9,669 PROD1 DRILL OWFF T Performed breathing test, gained 2.5 bbls in 30 min, flow down to slight trickle. 02:00 03:45 1.75 9,669 9,669 PROD1 DRILL CIRC T Circ. btms up after test and max gas at btms up was 164 units, circ at 120 gpm at 1,000 psi and 70 rpm's with 12-13K ft-Ibs torque with 12.5 mw in and out. ~_ ~ac~e 2~ zaf ~4 Time Logs _ _ __ __ _ Date From To Dur S De th E. De th Phase Code Subcode T COM _ 12/30/2007 03:45 06:15 2.50 9,669 8,795 PROD1 DRILL TRIP _ T Pumped out of hole from 9,669' to csg shoe at 8,795', pumped out at 1.5 bpm at 650 psi, pu wt 210K, do wt 73K, saw 35K drag at 9,330', 9,220' and 9,090', BROOH from 9,186' to 9,126'. Calc fill 5 bbls, actual fill 10 bbls. 06:15 06:45 0.50 8,795 8,795 PROD1 DRILL OWFF T Performed breathing test at the shoe, only gained 1 bbl in 30 min's, down to sli ht trickle. 06:45 08:15 1.50 8,795 8,795 PROD1 DRILL CIRC T Circ btms up and no increase in gas from 76 units which was BGG, Circ at 120 gpm, 900 psi, pu wt 185K, do wt 75K. 08:15 14:00 5.75 8,795 381 PROD1 DRILL TRIP T Pumped out of hole 10 stds from 8,795' to 7,907' at 1.5 bpm at 450 psi, then POOH wet on elevators to 6,033', hole took calc fill, pumped dry job and blew down top drive, cont. to POOH to BHA at 381'. Calc fill 52 bbls, actual fill 58 bbls. 14:00 14:45 0.75 381 0 PROD1 DRILL PULD T POOH & stood back NMFDC's, HWDP and jars, LD Periscope & MWD tool., inspected bit and motor and ck'd ok, chan ed out float. 14:45 15:45 1.00 0 381 PROD1 DRILL PULD T MU BHA #12, re-ran bit and motor. MU new MWD tool to Periscope tool RIH with NMFDC's, Circ sub, HWDP and jars to 381', shallow tested MWD and ck'd ok. 15:45 22:15 6.50 381 9,592 PROD1 DRILL TRIP T RIH from 381' with BHA #12 to 9,070', filling DP every 20 stds. PU= 185K, S0= 70K, ROT= 100K with 11,000 ft-Ib TQ at 50 RPM. RIH to 9,100' with pipe stacking out to Blk wt. Ream in hole to 9,308'. Continue RIH to 9,592', then turn on pumps and wash and ream to 9,669' td, w/ 100 gpm, 900 psi and 50 r m. 22:15 00:00 1.75 9,592 9,669 PROD1 DRILL CIRC T CBU with 12.5 ppg mud at 110 gpm, 1,150 psi. Highest MW= 13.5 ppg, lowest 12.2 MW. Continue to circ and balance MW out. Pumped 168 bbl with 13.8 bbl of losses. Max gas 3550 units. 12/31/2007 00:00 02:45 2.75 9,669 9,669 PROD1 DRILL CIRC T Fin circ btms up (max gas 3553 units) and cont. to circ hole while offloading 12.5 ppg mud and taking on 11.3 ppg Flo-Pro mud into pits, circ hole at 120 mat 950 si. P:ac~~ 1A of 44 Time Logs _Date___ From To Dur S Depth E Depth Phase Code S_ubcode T COM__ _ 12/31/2007 02:45 05:30 2.75 9,669 9,669 PROD1 _ DRILL _ GIRC T _, Displaced hole over from 12.5 ppg mud to new 11.3 ppg Flo-Pro, staged pump rate up from 120 gpm to 185 gpm at 1,545 psi, rotated at 60 rpm's with13K ft-Ibs torque, ECD's at 185 gpm were 12.7 ppg, cont to circ hole and MADD pass from 9,584' to 9,669' while finishing taking on 11.3 ppg mud into its. 05:30 05:45 0.25 9,669 9,669 PROD1 DRILL CIRC P Took SPR's and survey. 05:45 12:00 6.25 9,669 9,705 PROD1 DRILL DDRL P Drilled 6 1/8" hole with Anadrils 1.5 deg motor and Periscope tool, drilled from 9,669' to 9,705' MD/5,851' TVD 36') ART 4.83 hrs, AST -0-, 10-17K wob, 50 rpm's, 44 spm, 185 gpm, 1,600 psi, off btm torque 12K ft-Ibs, on btm 13K, rot wt 105K, up wt 2110K, do wt 75K, 11.3 ppg MW, ave ECD 12.7 ppg, ave BGG 45 units, max gas from survey/conn.'s 5,200 units. MW with pressured scales 11.3 ppg in & out, non-pressured scales 11.2 ppg in and 10.9 out. 12:00 00:00 12.00 9,705 9,755 PROD1 DRILL DDRL P Drilled 6 1/8" hole from 9,705' to 9,755' and (5,858' tvd) with 1.5 deg motor + Periscope. ADT= 10.36 hr, ART= 7.23 hr, AST= 3.13 hr, PU= 200K, S0= 70K, ROT= 105K, TQ on/off= 11/12,000 ft-Ib. ECD= 12.4 w/ 11.3 ppg MW and 185 gpm. Max gas at CBU= 5,270 units. 01/01/2008 00:00 12:00 12.00 9,755 9,859 PROD1 DRILL DDRL P Drilled 6 1/8" hole with Anadrils 1.5 deg motor and Periscope tool, drilled from 9,755' to 9,859' MD/ 5,860' TVD 104') ART 5.16 hrs, AST 3.56 hrs, ADT 8.72 hrs, 10-18K wob, 50-80 rpm's, 44-52 spm, 185-220 gpm, 1,600 to 2,000 psi, off btm torque 12K ft-Ibs, on btm 11 K, rot wt 104K, up wt 170K, do wt 75K, 11.3 ppg MW, ave ECD 12.4 ppg, ave BGG 45 units, max gas from conn. 1,374 units. 12:00 00:00 12.00 9,859 10,066 PROD1 DRILL DDRL P Cont. to drill 6 1/8" hole from 9,859' to 10066' MD. (206') TVD = 5867'. ART 6.88 hrs, AST 2.60 hrs, ADT 9.48 hrs, 10-18K wob, 50-80 rpm's, 44-52 spm, 185-220 gpm, 1,600 to 2,000 psi, off btm torque 12K ft-Ibs, on btm 11 K, rot wt 105K, up wt 150K, do wt 70K, 11.3 ppg MW, ave ECD 12.5 ppg, ave BGG 20 units, max gas from conn. 3654 units. 01/02/2008 00:00 07:45 7.75 10,066 10,154 PROD1 DRILL DDRL P Cont. to drill 6 1/8" hole from 10,066' - 10,154' MD. (88') TVD = 5,813'. ART .49 hrs, AST 7.03 hrs, ADT 7.52 hrs, encountered drilling break at 10,110' MD/5,865' TVD. P~c~~ ~5 cif 44 Time Logs ___ Date From To Dur S Depth E. De th Phase Code Subcode T COM _~ 01/04/2008 00:00 02:30 2.50 10,771 10,771 PROD1 DRILL CIRC T Continue mix & pump 40 BBLS of 40 PPB Dyna Red LCM, continuing to add Dyna Red LCM to mud system. Observed losses slowing to 18 BBLS / HR. Rack back 1 stand after spotting LCM, observing up to 2700 units of gas atbottoms up. Decision to screen down to 50 mesh screens to keep LCM in system, and pump open the CCV Valve, considering plugging off of BHA. Reciprocate drill string entire time. Pum 40 BBL, 40 PPB LCM ill. 02:30 03:30 1.00 10,771 10,771 PROD1 DRILL CIRC T Drop 1.80" steel ball pumping down at 84 GPM's - 560 PSI, until ball seated at 580 strokes. Pressure to 2000 PSI, hold 1 minute. Continue pressure to 2500 PSI to observe valve open. Pump to verify with 165 GPM's - 800 PSI. Drop 1.70" Brass ball to shut off BHA. Reci rotate drill strin entire time. 03:30 06:00 2.50 10,771 10,771 PROD1 DRILL CIRC T Isolated well on pit 5 and continue pumping at 200 GPM's - 1,225 PSI. Note: ECD's before we started losing fluid at 12.6 PPG at 200 GPM's - 1850 PSI. Observed 3 BBL loss in first 45 minutes with units of gas at bottoms up to 2646. Continiue Reciprocate drill string entire time, with no rotation as per recommended procedure of CCV operation. Raised MW to 11.6 ppg while adding 18 ppb LCM to the mud s stem 06:00 06:15 0.25 10,771 10,771 PROD1 DRILL OWFF T Performed 15 min. breathing test, ained 2.5 bbls in 15 min. 06:15 09:15 3.00 10,771 10,771 PROD1 DRILL CIRC T Circ btms up after breathing test, max gas at btms up 513 units, cont. to circ hole raising MW to 11.8 ppg, circ at 198 gpm, 1,225 psi, losses ave 4-8 b h. 09:15 09:45 0.50 10,771 10,771 PROD1 DRILL OWFF T Performed 30 min breathing test, gained 3 bbls in 30 min., in the 1st 5 min gained .7 bbls or .14 bpm, final 5 min's ained .20 bbls or .04 b m. 09:45 12:30 2.75 10,771 10,771 PROD1 DRILL CIRC T Circ. btms up while increasing MW to 11.9 ppg, max gas at btms up 651 units, circ hole at 180 gpm, 1,200 psi, with 11.9 MW in and out, reciprocating pipe from 10,721' to 10,627' with the circ sub at 10,525' to 10,431', cont. to circ hole raising MW to 12.0 ppg, ave 3-4 bph losses. As of 12:00 hrs lost approx 42 bbls last 12 hrs. Built an add. 250 bbls of 12.1 ppg mud with 18 ppb LCM. Fluid loss for first 12 HRS = 42 BBLS. Pane 27 of 44 l I Time_Logs __ Date From To Dur S De th E. De th Phase Code Subcode T COM 01/04/2008 12:30 13:00 0.50 10,771 10,771 PROD1 __ DRILL _ OWFF T Performed 30 min breathing test, gained 3.5 bbls in 30 min., in the 1st 5 min gained 1.4 bbls or .28 bpm, final 10 min's had no measurable gain only sli ht flow. 13:00 15:45 2.75 10,771 10,771 PROD1 DRILL CIRC T Circ btms up after breathing test, max gas at btms up 97 units, cont. to circ hole and even MW in and out at 12.1 ppg, circ hole at 170 gpm at 1,050 psi, ave 6 bph losses w/circ hole, built 40 bbls of clean 12.1 ppg Flo-Pro mud in ill it. 15:45 17:00 1.25 10,771 10,771 PROD1 DRILL CIRC T Dropped 1.76" steel ball and pumped down at 80 spm, had to switch from #2 pump to #1 due to LCM plugging suction, fin pumping ball down to seat, pressured up to 2,000 psi for 1 minute, then pressured up to 2,500 psi and closed circ sub. Note: Pumped 40 bbls of clean 12.1 ppg mud to rig floor then dropped ball, chasing ball with same. 17:00 18:45 1.75 10,771 10,771 PROD1 DRILL CIRC T Est circ at 2 bpm, 750 psi, 20 rpm's and 9Kft-Ibs torque with 100K rot wt, staged to 3 bpm @ 1,100 psi, 4 bpm 1,600 si 18:45 21:00 2.25 10,771 10,771 PROD1 DRILL CIRC T Continue circulating to increase mud weight to 12.3 PPG, maintaining 18 PPB LCM ins stem. 21:00 21:30 0.50 10,771 10,771 PROD1 DRILL OWFF T Performed 30 min breathing test, gained 4 bbls in 30 min., in the 1st 5 min gained 2 bbls. Final 10 min's had no measurable gain only slight flow. Decision to increase mud weight to 12.5 PPG, for tri mar in. 21:30 00:00 2.50 10,771 10,771 PROD1 DRILL CIRC T Circulate at 185 GPM's - 1900 PSI, increasing mud weight to 12.5 PPG. Observed 3 BBL loss during circulation with only 120 units of gas observed at surface on bottoms up. Total losses for tour = 30 BBLS. Crew Chan e 01/05/2008 00:00 00:30 0.50 10,771 10,771 PROD1 DRILL OWFF T With mud weight at 12.5 PPG all around, perform 30 minute breathing test. Observed gain of 1.4 BBLS, in first 10 minutes, then no flow -static. 00:30 03:45 3.25 10,771 8,795 PROD1 DRILL TRIP T Begin pumping out of hole (no rotation) at 2 BPM, at string speed of 20-25 fUminute. Observed good hole conditions, and proper displacement. Pull from 10627'- shoe at 8795'. 03:45 04:15 0.50 8,795 8,795 PROD1 DRILL OWFF T Monitor we-I. Perform 30 minute breathing test.lnitial gain = 1.4 BBLS in 5 minnutes. No Gain for 25 minutes. Well -static. a"'ac~e 28 of 44 Time Los V _ - Date From To Dur S De th E. De th Phase Code Subcode T COM 01/06/2008 03:15 06:30 3.25 10,721 10,721 PROD1 _ DRILL CIRC T _ Circulate & condition mud to treat mud from 12.5 to 12.1 PPG with 18 PPB LCM as planned. Reciprocate & rotate drill string, with pumps at 102 GPM's - 1600 PSI, 60 RPM's. 06:30 07:45 1.25 10,750 10,771 PROD1 DRILL CIRC P Perform Mad Pass from 10750' - 10771' MD. Pumps at 170 GPM's - 1900 PSI. 07:45 09:15 1.50 10,771 10,771 PROD1 DRILL CIRC P Obtain SPR's. Pump to downlink and attempt to communicate with the powerdrive assembly. No Success. Continue troubleshoot for communicat5ion with no success. Discuss plan forward with town, decision to drill ahead. 09:15 11:15 2.00 10,771 10,807 PROD1 DRILL DDRL P Drill from 10771' - 10807' MD. TVD = 5861'. ADT = 1.9 HRS. 11:15 12:00 0.75 10,807 10,807 PROD1 DRILL CIRC P CBU @ 10807' MD at 170 GPM's 2000 PSI, with 13.4 ECD. Total losses for tour = 48 BBLS. Crew chan e 12:00 12:45 0.75 10,807 10,807 PROD1 DRILL CIRC P Continue CBU @ 10807' MD at 170 GPM's 2000 PSI, with 13.4 ECD. Observed 30 units of as at btms u . 12:45 16:15 3.50 10,807 10,821 PROD1 DRILL DRLG P Drill from 10807' - 10821' MD. TVD = 5857'. ECD = 13.4 PPG with 170 GPM's. Mud wt = 12.1 PPG. ADT = 4.9 HRS. Max as = 76 units. 16:15 18:00 1.75 10,821 10,821 PROD1 DRILL CIRC P CBU @ 10821' MD at 170 GPM's 1950 PSI, with 13.6 ECD. After drilling 50' of hole. Discuss plan forward with town. Decision to drill ahead as we may be able to control the powerdrive assembly with out real time communication. 18:00 00:00 6.00 10,821 10,850 PROD1 DRILL DDRL P Directional drill from 10821' - 10850' (29') MD. TVD = 5856'. ECD = 13.6 PPG with 170 GPM's. Mud wt = 12.1 PPG. ADT = 5.2 HRS. Max gas = 79 units. Observed ROP's of 5 - 40 ft/hr. Samples were not conclusive of percentage of shale or sand cuttings as the content of LCM in mud at 18 PPB as per Geologist. Total fluid losses for tour = 19 BBLS. Crew Chan e 01/07/2008 00:00 07:30 7.50 10,850 10,995 PROD1 DRILL DDRL P Directional drill from 10850' - 10995' (145') MD. TVD = 5860'. ECD = 13.7 PPG with 170 GPM's. Mud wt = 12.1 PPG. ADT = 7.1 HRS. Max gas = 88 units. Observed ROP's of 5 - 40 ft/hr. Samples taken every 10' were not conclusive of percentage of shale or sand cuttings as the content of LCM in mud at 18 PPB as er Geolo ist. 07:30 08:15 0.75 10,995 10,995 PROD1 DRILL CIRC P Downlink to Powerdrive. Trouble shoot, re eat downlinkin . ~'~ge 3~ of ~4 l J Time Logs __ Date From To bur S. De th E,_Depth Phase Code -Subcode T _ COM___ _ 01/07/2008 08:15 08:45 0.50 10,995 11,034 PROD1 DRILL DDRL P Directional drill from 10995' - 11034' MD (39'). TVD = 5865'. ECD = 13.7 PPG with 170 GPM's. Mud wt = 12.1 PPG. ADT = .5 HRS. Max gas = 591 units. Observed ROP's of 5 - 40 ft/hr. Samples taken every 10' were not conclusive of percentage of shale or sand cuttings as the content of LCM in mud at 15 PPB as er Geolo ist. 08:45 09:45 1.00 11,034 11,034 PROD1 DRILL CIRC T Observed Pericope shut down. Attempt to gain communication with no success. Decision to POOH. 09:45 12:00 2.25 11,034 11,034 PROD1 DRILL CIRC T Rack back one stand. Circulate to weight up mud system to 12.5 PPG with 15 PPB LCM. Reciprocate & rotate drill string. Total fluid loss for tour = 77 BBLS. Crew chan e 12:00 13:00 1.00 11,034 11,034 PROD1 DRILL CIRC T While circulating, observed Pericope assembly turned on. Continue cycle pumps to verify good communication at 160 GPM's - 1900 PSI. 80 Rpm's, 8-9 K TQ. ECD's at 13.9 PPG. 13:00 13:30 0.50 11,034 11,034 PROD1 DRILL TRIP T Pick up one stand. Run to bottom at 11034' MD. Observed Periscope assembly shut down once again as soon as bit on bottom. Failed to gain communication. 13:30 16:30 3.00 11,034 11,034 PROD1 DRILL CIRC T Rack back one stand. Resume weight up operations to 12.5 PPG for trip out of hole. FCP = 1600 PSI @ 135 GPM's. ECD's = 14 PPG. No fluid losses. 16:30 17:00 0.50 11,034 11,034 PROD1 DRILL OWFF T Pertorm breathing test as per Co. man. Observed 3.5 BBL gain in 30 minutes. 17:00 20:30 3.50 11,034 8,747 PROD1 DRILL REAM T Pump out of hole from 11035' - 8747' at string speeds of 30-35 ft/min, with pump at 1 BPM - 500 PSI. Observed ro er dis lacement. 20:30 21:00 0.50 8,747 8,747 PROD1 DRILL OWFF T While at the shoe, perform breathing test as per Co. man. Observed 0 BBL ain, and well static. 21:00 22:30 1.50 8,747 8,747 PROD1 DRILL CIRC T Circulate bottoms up at 170 GPM's - 1800 PSI observing max gas at 47 units. Reci rotate & rotate drill strin . 22:30 00:00 1.50 8,747 7,809 PROD1 DRILL TRIP T Continue pump out of hole 10 more stands at 1 BPM - 500 PSI. Observed ro er dives lacement. Crew chan e 01/08/2008 00:00 03:00 3.00 7,809 378 PROD1 DRILL TRIP T Continue pull 10 stands wet. Observed fluid fallin in stack. 03:00 04:15 1.25 378 0 PROD1 DRILL PULD T Continue POOH rack back HWDP & Flex drill collars. Breakout & lay down Pericope & powerdrive assemblies. Breakout & lay down bit. Grade bit to 1/1/CT/N/X/I/ER/DTF. Observed proper dis lacement. Page 31 of 44 i Time Logs _ __ __ ~ Date From To Dur S. De th E_Deeth__Phase Code Subcod__e T_ COM _ _ 01/08/2008 04:15 04:45 0.50 0 0 PROD1 DRILL PULD T Clean & clear rig floor area. Send tools out & pull test tools to floor. Pull wear bushin . 04:45 10:30 5.75 0 0 PROD1 WELC BOPE T Rig up. Held PJSM. Discuss safety & hzard recognition issues. Discuss procedure to test BOP's. Install test plug & test joint. Test BOP's. Test Ckoke maifold and all valves. Hcr's and mauals. Test all floor valves. Tested with 3 1/2", 4" and 4 1/2" test joints. All test 250 PSI low, 3500 PSI Hi and recorded on chart. Perform accumulator test with first 200 PSI in 28 seconds, and full 3000 PSI in 2 min, 37 secs. 5 nitrogen bottles with avg pressure @ 2100 PSI. Witness of test waived by AOGCC rep -John Cris . 10:30 11:00 0.50 0 0 PROD1 WELCT BOPE T Rig down test equipment. Install wear bushin .RILDS. 11:00 12:00 1.00 0 0 PROD1 RIGMN SVRG T Held PJSM. Discuss safety & hazard recognition issues. Discuss procwedure to Slip & cut drilling line. hang blocks, slip & cut 65' of drilling line. Crew Chan e 12:00 13:30 1.50 0 0 PROD1 RIGMN' SVRG T Continue slip & cut line. Service top drive & draw works. Inspect & adjust brakes. Clean & inspect Top drive saver sub and rabber dies. 13:30 15:30 2.00 0 384 PROD1 DRILL PULD T Held PJSM. Make up BHA # 14 as per DD & MWD reps. Makeup 6 1/8" HYC MX2011-A2 bit with TFA Of .464 sq. in. & mud motor assembly bent at 1.5 deg, with periscope, & VPWD. Total BHA len th = 384.08' 15:30 16:30 1.00 384 1,420 PROD1 DRILL TRIP T Trip in hole with assembly from 384' - 1420' MD. 16:30 17:00 0.50 1,420 1,420 PROD1 DRILL TRIP T perform shallow pulse test with pumps at 4 BPM - 1000 PSI. Good test. 17:00 22:30 5.50 1,420 8,753 PROD1 DRILL TRIP T Continue trip in hole from 1420' - 8753' (shoe depth). Control string speed to prevent surge on well bore. Fill drill string every 10 stands.Obsenred 7 BBL loss on TIH. 22:30 00:00 1.50 8,753 8,753 PROD1 DRILL CIRC T Circulate bottoms up staging pump to 3.5 BPM - 1475 PSI. Reciprocate drill string inside casing. Observed fluid losses at approximately 50 BBLS / HR. Slow pumps to 1.5 BPM - 725 PSI. Continue CBU to 2000 STKs, verify no gas issues. Total loss on btms u = 87 BBLS. Crew Chan e 01/09/2008 00:00 00:30 0.50 8,753 8,753 PROD1 DRILL CIRC T Finish circulate bottoms up with pumps at 1.5 BPM - 725 PSI, for 2000 STKs, verify no gas issues. Total loss on btms u = 87 BBLS. ~~g~ ~? of 44 ;~ Time Logs __ Date From To Dur S: De th E. De th Phase Code Subcode T COM _ 01/09/2008 00:30 02:30 2.00 8,753 111,000 PROD1 DRILL TRIP T Continue trip in hole from 8753' - 11000' MD. Observed no issues in open hole with correct displacement. Fill drill strip eve 10 stands. 02:30 12:00 9.50 11,000 11,000 PROD1 DRILL CIRC T Obtain circulation parameters, continuing displacing out 12.5 PPG mud in wellbore with 12.1 PPG mud, 10 PPB LCM. ICP at 60 GPM - 1000 PSI. Observe losses up to 70 plus BPH. Slow pumps to 1 BPM with losses slowing to 40-50 BPH, adding 30 PPB LCM. Observed mud weights out fluctuating from 11.8 PPG - 13.8 PPG, pumping 12.1 PPG in. Continue circulating to observe losses slowing to less than 18 BPH. Pumps at 130 GPM's - 1575 PSI. Continue circulatn with a total loss for the tour of 390 BBLS. Reciprocate & rotate drill strip .Crew Chan e 12:00 13:00 1.00 11,000 11,000 PROD1 DRILL CIRC T Continue circulating observing losses slowing to 3 BPH. Stage pumps to 150 GPM's - 1900 PSI with a ECD of 13.7 PPG. Ensure mud weights in out 12.1 PPG, with a 30 PPB LCM. 13:00 18:00 5.00 11,000 11,055 PROD1 DRILL DDRL P Slack off and tag bottom. Directional drill 6 1/8" hole from 11035' -11055' MD. ND = 5863'. ADT = 4.3 HRS. Sliding at high side to get back into sand as per GEO. Fluid losses maintaining at 3-10 BPH. Condition mud. ECD = 13.8 PPG. Begin rotating after slide. Observed fluid losses increase to 20 -40 BPH. Suspect bar sa in well bore. 18:00 20:30 2.50 11,055 11,055 PROD1 DRILL CIRC T Continue circulating slowing pumps to 90 GPM's to control ECD's and allow lighter mud at 11.8 ppg, and then heavier mud to 13.6 to be pumped out. We circulated to get a bottoms up and allow system to balance out at 12.1 PPG. Condition mud with Flozan to aid in bar sagging, increasing yield oint. 20:30 22:15 1.75 11,055 11,055 PROD1 DRILL CIRC T Perform Mad Pass as per MWD rep @ 80 - 100 ft/hr from 11004' - 11055' MD. with pumps at 150 GPM's - 1800 PSI. ECD's at 13.6 PPG. Rotate drill strip at 50 RPM's. 22:15 00:00 1.75 11,055 11,081 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11055' - 11081' MD. ND = 5863'. ADT = .7 HRS. Sliding at high side to get back into sand as per GEO. Fluid losses maintaining at 3-10 BPH. Condition mud. ECD = 13.7 PPG. Crew Chan e ~ar~e 33 of dd Time Logs ___ _ _ _ Date From To Dur S. Depth E. Depth Phase Code Subcode T COM ___ 01!10/2008 00:00 00:15 0.25 11,081 11,090 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11081' - 11090' MD. ND = 5864'. AST = .5 HRS. Sliding at high side to get back into sand as per GEO. Fluid losses maintaining at 3-10 BPH. Condition mud. ECD = 13.7 PPG. 00:15 00:45 0.50 11,090 11,090 PROD1 DRILL CIRC P Perform MAD PASS survey from 11075' - 11090' as er MWD & DD. 00:45 01:00 0.25 11,090 11,095 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11090' - 11095' MD. ND = 5864'. ART = .14 HRS. 01:00 01:45 0.75 11,095 11,095 PROD1 DRILL CIRC T Observed once again when rotating after slide, fluid losses increase to 20 -40 BPH. Circulate accordingly to allow mud weights to staiblize in well bore back to 12.1 and ECD dropping to 13.6 PPG. 01:45 03:45 2.00 11,095 11,118 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11095' - 11118' MD. ND = 5864'. ADT = .46 HRS. AST = .69 HRS. Sliding at high side. Fluid losses minimal. Condition mud. ECD = 13.1 PPG. while slidin 03:45 05:00 1.25 11,118 11,118 PROD1 DRILL CIRC T Circulate again after slide, to control bar sag with fluid losses increasing to 10 -30 BPH while rotating. Circulate accordingly to allow mud weights to staiblize in well bore at a 12.1 PPG. Observed ECD's climbing to 13.91 PPG with losses minimal. 05:00 06:30 1.50 11,118 11,136 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11118' - 11136' MD. ND = 5864'. AST = .82 HRS. Sliding at high side. Fluid losses minimal. Condition mud. ECD = 13.82 PPG. 06:30 07:45 1.25 11,136 11,136 PROD1 DRILL CIRC T Circulate again after slide, to control bar sag with fluid losses increasing to 10 -30 BPH while rotating. Circulate accordingly to allow mud weights to staiblize in well bore at a 12.1 PPG. Observed ECD's climbing to 13.82 PPG with losses minimal. Perform MAD PASS while circulating from 11108' - 11136'. 07:45 12:00 4.25 11,136 11,216 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11136' - 11216' MD. ND = 5861'. ART = 2.85 HRS. Fluid losses minimal. Condition mud. ECD = 13.82 PPG. Obtained SPR's. Crew Change Total fluid loss for tour = 48 BBLS 12:00 17:45 5.75 11,216 11,295 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11216' - 11295' MD. ND = 5857'. ART = 2.8 HRS. AST = 1.84 HRS. Fluid losses minimal. Condition mud. ECD = 13.78 PPG. 17:45 18:00 0.25 11,295 11,295 PROD1 DRILL CIRC P Perform MAD PASS for geology from 11216' - 11295' MD. Page ~ a# ~4 Time Logs __ Date From To Dur S. De th E' De th Phase Code Subcode __ T COM 01/10/2008 18:00 19:00 1.00 11,295 11,295 PROD1 DRILL CIRC T Circulate to control bar sag with fluid losses increasing to 5 -15 BPH while rotating. Circulate accordingly to allow mud weights to staiblize in well bore at a 12.1 PPG. Observed ECD's climbing to 13.85 PPG with losses minimal. 19:00 20:15 1.25 11,295 11,309 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11295' - 11309' MD. Fluid losses minimal. Condition mud. ECD = 13.78 PPG. Observed mud weight out down to 11.7 PPG. 20:15 21:45 1.50 11,309 11,309 PROD1 DRILL CIRC P Circulate to control bar sag with fluid losses increasing to 5 -10 BPH while rotating. Circulate accordingly to allow mud weights to staiblize in well bore at a 12.1 PPG. Observed ECD's climbing to 13.96 PPG with losses minimal. Perform MAD PASS for eolo from 11295' - 11309' MD. 21:45 00:00 2.25 11,309 11,350 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11309' - 11350' MD. Fluid losses minimal while drilling. Sliding at high side. Condition mud. ECD = 13.76 PPG. For tour- ADT = 1.63 HRS, AST = 3.17 HRS. Total ADT = 4.8 HRS. Max gas observed = 302 units. Obtained SPR's. Crew Chan e 01/11/2008 00:00 01:30 1.50 11,350 11,375 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11350' - 11375' MD. TVD = 5858'. Fluid losses minimal while drilling. Condition mud. ECD = 13.87 PPG. Max gas observed = 285 units 01:30 02:45 1.25 11,375 11,375 PROD1 DRILL CIRC T Circulate to control bar sag with fluid losses increasing to 5 -10 BPH while rotating. Circulate accordingly to allow mud weights to staiblize in well bore at a 12.1 PPG. Observed ECD's climbing to 13.82 PPG with losses minimal. Perform MAD PASS for eolo from 11350' - 11375' MD. 02:45 12:00 9.25 11,375 11,485 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11375' - 11485' MD. TVD = 5855'. Fluid losses minimal while drilling. Sliding at high side. Condition mud. ECD = 13.55 PPG. Max gas observed = 322 units. Circulate as needed to control ECD's and bar sa .Crew Chan e 12:00 18:00 6.00 11,485 11,580 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11485' - 11580' MD. TVD = 5850'. Fluid losses minimal while drilling. Sliding at high side. Condition mud. ECD = 13.79 PPG. Max gas observed =119 units. Circulate as needed to control ECD's and bar sa . Page 35 of 44 C~7 Time Logs Die From __ To _ _ Dur S. Depth E. De th Phase Code Subcode T__ _ _ _ _COM __ 01/11/2008 18:00 00:00 6.00 11,580 11,603 PROD1 DRILL DDRL P Directional drill 6 1!8" hole from 11580' - 11603' MD. TVD = 5851'. Fluid losses minimal while drilling. Sliding at 140 L. Condition mud. ECD = 13.74 PPG. Max gas observed = 432 units. Circulate as needed to control ECD's and bar sag. Total losses today = 33 BBLS. Crew chan e 01/12/2008 00:00 04:30 4.50 11,603 11,623 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11603' - 11623' MD. TVD = 5850'. Fluid losses minimal while drilling. Sliding at 150L. Condition mud. ECD = 13.8 PPG. Max gas observed = 40 units. Circulate as needed to control ECD's and bar sa . 04:30 05:15 0.75 11,623 11,623 PROD1 DRILL CIRC P Circulate & condition mud for bar sag & ECD's. Perform MAd Pass for Geol from 11620' - 11590' MD. 05:15 12:00 6.75 11,623 11,632 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11623' - 11632' MD. TVD = 5850'. Fluid losses minimal while drilling. Sliding at 150L. Condition mud. ECD = 13.38 PPG. Max gas observed = 40 units. Circulate as needed to control ECD's and bar sag. Total losses for this tour = 21 BBLS. Crew Chan e 12:00 18:00 6.00 11,632 11,652 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11632' - 11652' MD. TVD = 5845'. Fluid losses minimal while drilling. Sliding at 180. Condition mud. ECD = 13.78 PPG. Max gas observed = 28 units. Circulate as needed to control ECD's and bar sa . 18:00 00:00 6.00 11,652 11,663 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11652' - 11663' MD. TVD = 5849'. Fluid losses minimal while drilling. Sliding at 180. Condition mud. ECD = 13.88 PPG. Max gas observed = 28 units. Circulate as needed to control ECD's and bar sag. Total losses for this tour = 23 BBLS. Crew Chan e 01/13!2008 00:00 06:00 6.00 11,663 11,678 PROD1 DRILL DDRL P Directional drill 6 118" hole from 11663' - 11678' MD. TVD = 5849'. Fluid losses minimal while drilling. Sliding at 180. Condition mud. ECD = 13.94 PPG. Max gas observed = 30 units. Circulate as needed to control ECD's and bar sag. ADT = 4.54 HRS. AST = 3.14 HRS. F~~3e ~ti at ~~~ '; Time Logs _ _ Date From To Dur S, De_.~th _E_Depth Phase Code Subcod_e_ T COM _ _ 01/13/2008 06:00 12:00 6.00 11,678 11,692 PROD1 DRILL DDRL ~ P Directional drill 6 1/8" hole from 11678' - 11692' MD. ND = 5849'. Fluid losses minimal while drilling. Sliding at 180. Condition mud. ECD = 14.0 PPG. Max gas observed = 42 units. Circulate as needed to control ECD's and bar sag. ADT = 3.45 HRS. AST = 2:82 HRS. Total Fluid loss this tour - 44 BBLS. Crew Chan e 12:00 18:00 6.00 11,692 11,712 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11692' - 11712' MD. ND = 5848'. Fluid losses minimal while drilling. Sliding at HS. Condition mud. ECD = 13.88 PPG. Max gas observed = 28 units. Circulate as needed to control ECD's and bar sag. ADT = 6.26 HRS. AST = 5.52 HRS. 18:00 00:00 6.00 11,712 11,721 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11712' - 11721' MD. ND = 5848'. Fluid losses minimal while drilling. Sliding at 180. Condition mud. ECD = 14.17 PPG. Max gas observed = 175 units. Circulate as needed to control ECD's and bar sag. ADT = 3.20 HRS. AST = 2.43 HRS. Total Fluid loss this tour - 31 BBLS. Total Bit Hrs = 61.3. Crew Chan e 01/14/2008 00:00 12:00 12.00 11,721 11,786 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11721' - 11786' MD. ND = 5847'. Fluid losses minimal while drilling. Condition mud. ECD = 13.85 PPG. Max gas observed = 370 units. Circulate as needed to control ECD's and bar sag. ADT = 11.08 HRS. AST = 0 HRS. Total Fluid loss this tour - 70 BBLS. Total Bit Hrs = 72.38. Crew chan e 12:00 18:00 6.00 11,786 11,806 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11786' - 11806' MD. ND = 5847'. Fluid losses minimal while drilling. Condition mud. ECD = 13.85 PPG. Max gas observed = 23 units. Circulate as needed to control ECD's and bar sag. ADT = 5.79 HRS. AST = 5.79 HRS. Total Bit Hrs = 78.17 18:00 00:00 6.00 11,806 11,822 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11806' - 11822' MD. ND = 5848'. Fluid losses minimal while drilling. Condition mud. ECD = 14.32 PPG. Max gas observed = 23 units. Circulate as needed to control ECD's and bar sag. ADT = 4.94 HRS. AST = 4.94 HRS. Total Fluid loss this tour - 0 BBLS. Gained 21 BBLS. Total Bit Hrs = 83.11. Crew Chan e Pace 37 of 4d ~ Time Logs -- Dat_e_ From To Dur S_ Depth E De th Phase Code Subcode T COM _ T 01/15/2008 00:00 00:30 0.50 11,822 11,822 PROD1 DRILL CIRC P Circulate while reciprocate & rotate drill string to reduce ECD's and control bar sag. ECD's from 14.3 PPG to 13.98 PPG. Control pump speeds finally getting back to 170 GPM's - 2060 PSI. Rotate at 90 RPM's, with mud wei ht balanced at 12.1 PPG. 00:30 06:00 5.50 11,822 11,846 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11822' - 11846' MD. ND = 5855'. Fluid losses minimal while drilling. Condition mud. ECD = 14.3 PPG. Max gas observed = 1312 units, after a connection. Circulate as needed to control ECD's and bar sag. ADT = 4.96 HRS. AST = 0 HRS. 06:00 12:00 6.00 11,846 11,870 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11846' - 11870' MD. ND = 5857'. Fluid losses minimal while drilling. Condition mud. ECD = 13.31 PPG. Max gas observed = 38 units. Circulate as needed to control ECD's and bar sag. ADT = 4.64 HRS. AST = .97 HRS. Total Fluid loss this tour - 49 BBLS. Gained 0 BBLS. Total Bit Hrs = 92.71. Crew Chan e 12:00 18:00 6.00 11,870 11,884 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11870' - 11884' MD. ND = 5852'. Fluid losses minimal while drilling. Condition mud. ECD = 13.95 PPG. Max gas observed = 23 units. Circulate as needed to control ECD's and bar sag. ADT = 5.19 HRS. AST = 2.97 HRS. 18:00 00:00 6.00 11,884 11,914 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11884' - 11914' MD. ND = 5852'. Fluid losses minimal while drilling. Condition mud. ECD = 13.95 PPG. Max gas observed = 92 units. Circulate as needed to control ECD's and bar sag. ADT = 5.02 HRS. AST = 0 HRS. Total Fluid loss this tour - 0 BBLS. Gained 7 BBLS. Total Bit Hrs = 102.92. Crew Chan e 01/16/2008 00:00 06:00 6.00 11,914 11,957 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11914' - 11957' MD. ND = 5854'. Fluid losses minimal while drilling. Condition mud. ECD = 13.65 PPG. Max gas observed = 225 units. Circulate as needed to control ECD's and bar sag. ADT = 5.31 HRS. AST = 0 HRS. 06:00 10:15 4.25 11,957 12,002 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 11957' - 12002' MD. ND = 5857'. Fluid losses minimal while drilling. Condition mud. ECD = 13.65 PPG: Max gas observed = 28 units. Circulate as needed to control ECD's and bar sag. ADT = 3.08 HRS. AST = 1.7 HRS. Page ~~ cat 44 • Time Logs _ ___ Date From To Dur S C?e th E. De th Phase Code Subcode T COM 01/16/2008 10:15 10:30 0.25 12,002 12,002 PROD1 DRILL CIRC P Perform Mad Pass for geology from 11977' - 12002' MD. 10:30 12:00 1.50 12,002 12,009 PROD1 DRILL DDRL P Directional drill 6 118" hole from 12002' - 12009' MD.ND = 5870'. Fluid losses minimal while drilling. Condition mud. ECD = 13.65 PPG. Max gas observed = 32 units. ADT = .78 HRS. AST = .78 HRS. Total Bit HRS = 112.09. Total Fluid loss this tour = 40 BBLS. Crew Chan e 12:00 18:00 6.00 12,009 12,028 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 12009' - 12028' MD. ND = 5858'. Fluid losses minimal while drilling. Condition mud. ECD = 13.65 PPG. Max gas observed = 69 units. Circulate as needed to control ECD's and bar sag. ADT = 4.45 HRS. AST = 4.45 HRS. 18:00 00:00 6.00 12,028 12,055 PROD1 DRILL DDRL P Directional drill 6 1/8" hole from 12028' - 12055' MD.ND = 5870'. TD cal-ed as er Geolo ist. Penetration rate while rotating at TD - 5-10 ft/hr. Fluid losses minimal while drilling. Condition mud. ECD = 13.38 PPG. Max gas observed = 115 units. ADT = 2.39 HRS. AST = 1.72 HRS. Total Bit HRS = 118.93. Total Fluid loss this tour = 30 BBLS. Crew Chan e 01/17/2008 00:00 01:00 1.00 12,055 12,055 PROD1 DRILL CIRC P Section TD'd as per Geologist at 12055' MD. Circulate bottoms up with pumps at 180 GPM's - 2100 PSI. Reciprocate & rotate drill string brin in ECD's down to 13.6 PPG. 01:00 05:00 4.00 12,055 12,055 PROD1 DRILL CIRC P Held PJSM with crew. Discuss safety & hazard recogniiton issues. Discuss procedure to displace well. Designate a spill champion. Rig up and displace well with reconditioned 12.5 PPG 5 PPB LCM mud, with pumps at 180 GPM's 2150 PSI. reciprocate & rotate drill string observing ECD's at 13.63 PPG. Obtain slow pump rates with new mud wei ht. 05:00 05:45 0.75 12,055 12,055 PROD1 DRILL OWFF P Monitor well. Perform breathing test. Observed 17 3/4 BBL gain after 45 minutes. Flow slowing to see only 1/4 BBL gain in last 5 minutes with 6% flow. 05:45 06:45 1.00 12,055 12,055 PROD1 DRILL CIRC P Circulate bottoms up, at 140 GPM's - 1500 PSI. 120 RPM's monitoring well for gas on bottoms up. Observed 1401 units of gas. Max ECD = 14.09 PPG, at 3 BPM - 110 RPM's. 06:45 10:00 3.25 12,055 12,055 PROD1 DRILL CIRC P Continue circulating weighting up mud system to 12.7 PPG. Observed ECD's @ 14.3 PPG. UP WT = 155K, SO WT = 70K. r-- l~ae 39 of 4~ t~ Time Logs Date From To Dur S Depth E, Depth Phase_ Code Subcode _ T_ COM 01/17/2008 10:00 10:30 0.50 12,055 12,055 PROD1 DRILL OWFF P Monitor well. Perform breathing test. Observed 18.75 BBL gain after 30 minutes. Flow slowing to see only 1/4 BBL gain in last 5 minutes with 6% flow. Results same as first time. 10:30 12:00 1.50 12,055 12,055 PROD1 DRILL CIRC P Circulate bottoms up, at 3 BPM's - 1500 PSI. 120 RPM's monitoring well for gas on bottoms up. Observed 700 units of gas. Max ECD = 14.26 PPG, at - 110 RPM's. Total fluid loss for this tour = 46 BBLS. Crew Chan e 12:00 16:15 4.25 12,055 12,055 PROD1 DRILL CIRC P Continue circulating weighting up mud system to 12.8+ -12.9 PPG. Observed ECD's 14.2 PPG. 16:15 16:45 0.50 12,055 12,055 PROD1 DRILL OWFF P Monitor well. Perform breathing test. Observed 15 BBL gain after 30 minutes. Flow slowing to see only 1/4 BBL gain in last 5 minutes. Flow slowin to pearl a sto . 16:45 19:15 2.50 12,055 12,055 PROD1 DRILL CIRC P Circulate bottoms up, at 3 BPM's - 1500 PSI. 120 RPM's monitoring well for gas on bottoms up. Observed 577 units of gas. Max ECD = 14.01 PPG, at - 110 RPM's. 19:15 19:30 0.25 12,055 12,055 PROD1 DRILL OWFF P Monitor well. Observed slight breathing, with flow to nearly a stop. Obtain SPR's. UP WT = 160K, SO WT = 95K. 19:30 00:00 4.50 12,055 9,876 PROD1 DRILL REAM P BROOH from 12042' - 9876' MD. Pumps at 2 BPM - 900 PSI. RPM's = 120. Observed proper displacement, and good hole conditions. String speeds of 5 -30 ft/minute. Total fluid loss for the tour - 79 BBLS. Crew Chan e 01/18/2008 00:00 01:45 1.75 9,876 8,753 PROD1 DRILL REAM P Continue BROOH from 9876' - 8753' MD (SHOE). Pumps at 2 BPM - 600 PSI. RPM's = 120. Observed displacement 3 BBLS short, and good hole conditions. String speeds of 5 -30 ft/minute. Observed gas at up to 870 units 5 stands below shoe. 01:45 03:15 1.50 8,753 8,753 PROD1 DRILL CIRC P With bit at the shoe, CBU at 115 GPM - 1230 PSI. Reciprocate & rotate drill string. Observed gas at 122 units. Fluid loss = 34 BBLS. 03:15 03:30 0.25 8,753 8,753 PROD1 DRILL OWFF P Monitor well -Well flowing with flow slowing down observing no gas. Well breathin as before. F~ac~~ ~~ of • Time Logs I y ___ Date From To Dur S DeD~th _E. De th PhaSe Code Subcode T COM 01/18/2008 03:30 05:00 1.50 8,753 12,055 PROD1 DRILL TRIP P Trip back in hole from the shoe controlling trip speeds to prevent pushing fluid away. Worked assembly through spots at 11485' - 11676' MD. Washed through spot at 11755' - 11820' MD @ 85 GPM's - 1000 PSI. 50 RPM's - 9K TO. Continue trip in hole back to TD at 12055' MD. Total displacement calculated at 19 BBLS, with hole takin 54 BBLS. 05:00 07:30 2.50 12,055 12,055 PROD1 DRILL CIRC P Circulate bottoms up staging pumps to 97 GPM's to control losses. Observed 312 units of gas on bottoms u .Reci rotate & rotate drill strip . 07:30 08:00 0.50 12,055 12,055 PROD1 DRILL OWFF P Monitor well. Perform breathing test. Observed 22.5 BBL gain after 30 minutes. Flow slowing to see only 1.25 BBL gain in last 5 minutes. Flow slowin to near) a sto . 08:00 10:15 2.25 12,055 12,055 PROD1 DRILL CIRC P Circulate bottoms up staging pumps to 92 GPM's to control losses. Observed 500 units of gas on bottoms u .Reci rotate & rotate drill strip . 10:15 11:00 0.75 12,055 12,055 PROD1 DRILL OWFF P Monitor well. Perform breathing test. Observed 18.25 BBL gain after 30 minutes. Flow slowing to see only 1.5 BBL gain in last 5 minutes. Flow slowing to nearly a stop. Well indicating breathing issues and little or no as. 11:00 12:00 1.00 12,055 11,849 PROD1 DRILL TRIP P POOH on elevators from 12035' -11849' with slow string speed observing flow slowing but not stopped, consistant with breathing issues observed. Crew Change. Total fluid loss this tour = 48.5 BBLS. 12;00 14:45 2.75 11,849 8,750 PROD1 DRILL TRIP P Continue POOH on elevators from 11849' - 8750', at slower string speeds, observing flow stopped when monitor well at 10 stands pulled. Observed correct displacement. Obtain SLM. 14:45 15:30 0.75 8,750 8,750 PROD1 DRILL OWFF P Monitor well at the shoe -observed .5 BBL loss in 30 minutes. 15:30 20:00 4.50 8,750 385 PROD1 DRILL TRIP P Continue POOH from 8750' - 385' (BHA). Retrieve drift in drill string. Clean floor area. Monitor well -static. 20:00 22:00 2.00 385 0 PROD1 DRILL PULD P Breakout & lay down HWDP & Flex drill collars. Breakout & lay down MWD, motor & bit. Inspect & grade bit to 2/3/CT/A/X/I/BT/TD. Download of MWD in shed out of critical path. Calculated hole fill - 70.2 BBLS - Actual - 48 BBLS. Page 41 of 44 C~ ~~ Time Logs __ Date From To Dur 5. De th E. De th Phase Code Subcode T COM 01/19/2008 _ 19:00 20:00 1.00 8,188 8,188 COMPZ CASINC OTHR P Perform breathing test observing well giving back 5 BBLS in 30 minutes. Pump dry job, blow down top drive & lines. 20:00 23:15 3.25 8,188 0 COMPZ CASINC RUNL P POOH from 8188'. Observed dis lacement 3.55 BBLS short. 23:15 00:00 0.75 0 0 COMPZ CASIN OTHR P Breakout, inspect and lay down BOT running tools. Clean & clear rig floor. Monitor wel -static. Crew chan e. 01/20/2008 00:00 00:30 0.50 COMPZ DRILL OTHR P Clean & clear rig floor area. BOLDS - ull wear buskin . 00:30 01:00 0.50 0 0 COMPZ RPCOh RURD P Held PJSM. Discuss safety & hazard recognition issues. Discuss procedure to rig up and run 3 1/2" Completion tubin . Ri u tb runnin a ui ment. 01:00 08:00 7.00 0 8,186 COMPZ RPCOh RCST P Make up seal assembly and space out tubes. Continue run in hole picking up tubing from pipe shed, installing DS nipples and GLM's as per detail. Observed proper displacement. SIMOPS: Clean its. 08:00 08:30 0.50 8,186 8,186 COMPZ RPCO HOSO P Tagged up with No-go at 8186'. Bottom seal depth - 8239'. Space out install space out pups. Make up tbg han er. Make u lines to circulate. 08:30 09:45 1.25 8,186 8,186 COMPZ RPCOh CIRC P Mix corrosion inhibitor as planned and spot across the seals up to the lower GLM @ 8138'. Pumps at 1 BPM - 380 PSI. Blow down all lines & BOP stack. 09:45 10:30 0.75 8,186 8,186 COMPZ RPCOh RCST P Land tubing hanger. RILDS. UP WT = 10:30 11:00 0.50 8,186 8,186 COMPZ RPCO DHEO P Rig up and um down annulus to test to 1000 PSI. Recorded on chart. Bleed ressures. Install 11:00 12:00 1.00 0 0 COMPZ WELCT NUND P Held PJSM. Discuss safety & hazard recognition issues. Discuss procedure to nipple down BOP's. Nipple down BOP stack, kill & choke lines. Crew Chan e 12:00 12:30 0.50 0 0 COMPZ WELC NUND P Continue nipple down BOP stack & lines. 12:30 14:30 2.00 0 0 COMPZ WELCT NUND P Nipple up adapter flange to tubing spool. Nipple up WKM Gen 5 Tree & valves. Test hanger void to 250 / 5000 PSI - 10 minutes. 14:30 18:00 3.50 0 0 COMPZ WELCT OTHR P Pull BPV. Install two way check. Fill tree with diesel to test. Attempt to test observing two way check failed. Pull & install new two way check. Test tree to 250 / 5000 PSI - 10 minutes. Rig up and ull TWC with lubricator. Page +$~ Qt ~+~ rs ~1 Ctanc~~+~~'h~lpS Alaska, 1rr"1C.. 3S-08C _ _ aPr I kmm~na~nm i wAn T~.,A~ I pRnn SURFACE (0-4263, OD:9.625, wt:ao.oo> Perf Issas-ssa6> KRU 3S-08C _- _ _ __, I Annle fn) TS I rian (nl I SSSV Type: NIPPLE Orig Com letion: 1/21!2008 Angle @ TD: deg @ Annular Fluid: Last W/O: Rev Reason: NEW SIDETRACK Reference Lo Ref Lo Date: Last U date: 2/1 /2008 Last Tag: __ _ _ ___ TD; 12055 ftKB Last Tag Date: I Max Hole A_ ngle: 0 deg (a) I I I Casing String - ALL STRINGS Descri lion Slze To Bottom TVD V1k Grade Thread CONDUCTOR 16.000 0 108 108 62.50 H-40 WELDED SURFACE 9.625 0 4263 4263 40.00 L-80 BTCM INTERMEDIATE 7.000 0 4365 4365 26.00 L-80 BTCM WINDOW 7.000 4263 4264 4264 0.00 INTERMEDIATE 7.000. 4365 8795 8795 26.00 L-80 BTCM LINER 4.500 8188 12055 12055 12.60 L-80 IBTM __-- - -- Tubing String - l`UBING Size Top Bottom TVD Wt Grade Thread 3.500 0 5237 8237 9.30 L-SO EUE°rd M Perforations Summa _ _ Interval TVD Zone Status Ft SPF Date T Comment 9322 - 9328 9322 - 9328 6 1 1/19/2008 Pert Pert Pups w/six 1/2" holes Pu er u 9543 - 9548 9543 - 9548 5 1 1/19/2008 Perf Perf Pups w/six 1/2" holes Pu er u 10011 - 10016 10011 - 10016 5 1 1/19/2008 Perf Pert Pups w/six 1/2" holes Pu er u 10171 - 10177 10171 - 10177 6 1 1/19/2008 Pert Pert Pups w/six 1/2" holes Pu r u 10363 - 10368 10363 - 10368 5 1 1/19/2008 Pert Pert Pups w/six 1/2" holes Pu er u 10524 - 10528 10524 - 10528 4 1 1/19/2008 Perf Perf Pups w/six 1/2" holes Pu er u 10715 - 10720 10715 - 10720 5 1 1/19/2008 Perf Pert Pups w/six 112" holes Pu er u 10997 - 11002 10997 - 11002 5 1 1 /19/2008 Pert Pert Pups w/six 1 /2" holes Pu er u 11310 - 11315 11310 - 11315 5 1 1/19/2008 Pert Pert Pups w/six 1/2"holes Pu er u 11524 - 11530 11524 - 11530 6 1 1/19/2008 Perf Perf Pups w/six 1!2" holes Pu r u 11997 -12001 11997 -12001 4 1 1/19/2008 Pert Perf Pups w/six 1/2" holes Pup per pup Gas Lift MandrelsNalves SY MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 4589 4589 CAMCO MMG DMY 1.5 RK 0.000 0 1/20/2008 2 5774 5774 CAMCO MMG DMY 1.5 RK 0.000 0 1/20/2008 3 6646 6646 CAMCO MMG DMY 1.5 RK 0.000 0 1/20/2008 4 7361 7361 CAMCO MMG DMY 1.5 RK 0.000 0 1/20/2008 5 813.8 8138 CAMCO MMG SOV 1.5 RKP 0.000 0 1/20/2008 Other lu s e ui ., etc. -COMPLETION ~ De th TVD T e Descri lion ID 23 23 HANGER FMC GEN V TUBING HANGER 3.500 502 502 NIP CAMCO DS NIPPLE w/NO GO PROFILE 2.875 8186 8186 NIP CAMCO DS NIPPLE w/NO GO PROFILE 2.812 8188 8188 PACKER LINER HRD ZXP LINER TOP PACKER 4.430 8207 8207 NIP LINER RS PACKOFF SEAL NIPPLE 4.250 8225 8225 SEAL BAKER 80-40 BONDED SEAL ASSEMBLY 3.000 8241 8241 XO Bushing LINER CROSSOVER BUSHING 3.950 8417 8417 Cement 3S-086 WELLBORE CEMENT RETAINER set 12/6/2007 0.000 Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Uatc: 2!7!2008 Timc: .14:19:47 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 3S-08, True North Site: Kuparuk 3S Pad Vertical(TVD) Re ference: 3S-08C D141 1 27.7+27,1 ~ri Well: 3S-O8 Section (VS) Refereuce: Well (O:OON;O.OOE,225.00/Yzl}` Wellpath: 3S-O8C Survey Calculation A4ethod: Minimum Curvature ~ Db: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 3S-08 Slot Name: Well Position: +N/-S 80.06 ft Northing: 5993923.52 ft Latitude: 70 23 40.307 N +E/-W -149.82 ft Easting : 476305.45 ft Longitude: 150 11 34.033 W Position Uncertainty: 0.00 ft ~ Wellpath: 3S-08C Drilled From: 3S-08 50-103-20450-03 Tie-on Depth: 4207.98 ft Current Datum: 3S-08C D141 (27.7+27.5) Height 55.20 ft .Above System Datum: Mean Sea Level Magnetic Data: 12/11/2007 Declination: 22.76 deg Field Strength: 57608 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 27.50 0.00 0.00 225.00 Survey Program for DeSnitive Wellpath Date: 1/21/2007 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 85.90 85.90 3S-08 Gyro (85.90-85.90) (2) CB-GYRO-SS Camera based gyro single shot 194.59 4207.48 3S-08 IIFR (194.59-11575.10) ( 4262.50 8780.39 3S-08C IIFR+MS+SAG Halliburton MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8823.57 11998.16 3S-O8C IIFR+MS Schlumberger (8 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey SID tncl Azim TVD Sys TVD N/S El~V MapN b1apE Tool ft deg deg ft ft ft ft ---__ ft ft 27.50 0.00 0.00 27.50 -27.70 ' 0.00 0.00 5993923.52 ~ 476305.45 - TIE LINE 85.90 0.25 294.00 85.90 30.70 0.05 -0.12 5993923.57 476305.33 CB-GYRO-SS 194.59 1.11 173.09 194.58 139.38 -0.90 -0.21 5993922.62 476305.24 MWD+IFR-AK-CAZ-SC 287.13 4.28 161.69 287.01 231.81 -5.07 0.99 5993918.45 476306.42 MWD+IFR-AK-CAZ-SC 378.19 5.94 163.68 377.70 322.50 -12.81 3.38 5993910.70 476308.79 MWD+IFR-AK-CAZ-SC 467.89 8.61 154.90 466.68 411.48 -23.35 7.53 5993900.15 476312.91 MWD+IFR-AK-CAZ-SC 558.43 10.68 157.24 555.93 500.73 -37.23 13.65 5993886.25 476318.98 MWD+IFR-AK-CAZ-SC ! 650.83 12.73 151.36 646.41 591.21 -54.06 21.85 5993869.40 476327.12 MWD+IFR-AK-CAZ-SC 740.81 14.66 143.84 733.83 678.63 -71.96 33.32 5993851.47 476338.54 MWD+IFR-AK-CAZ-SC 831.43 17.32 139.80 820.94 765.74 -91.52 48.79 5993831.85 476353.95 MWD+IFR-AK-CAZ-SC 926.78 19.76 135.55 911.34 856.14 -113.87 69.25 5993809.44 476374.33 MWD+IFR-AK-CAZ-SC 1021.56 20.59 .132.90 1000.31 945.11 -136.66 92.68 5993786.58 476397.68 MWD+IFR-AK-CAZ-SC 1115.88 23.97 126.02 1087.59 1032.39 -159.22 120.33 5993763.93 476425.27 MWD+IFR-AK-CAZ-SC 1212.16 27.15 120.42 1174.45 1119.25 -181.86 155.11 5993741.19 476459.97 MWD+IFR-AK-CAZ-SC 1307.00 31.14 118.49 1257.27 1202.07 -204.52 195.34 5993718.40 476500.12 MWD+IFR-AK-CAZ-SC 1403.94 35.79 117.14 1338.11 1282.91 -229.42 242.62 5993693.35 476547.32 MWD+IFR-AK-CAZ-SC 1500.34 40.01 116.73 1414.16 1358.96 -256.23 295.41 5993666.38 476600.01 MWD+IFR-AK-CAZ-SC 1594.88 43.17 116.26 1484.86 1429.66 -284.21 351.57 5993638.22 476656.08 MWD+IFR-AK-CAZ-SC ~ 1689.93 48.19 114.63 1551.25 1496.05 -313.38 412.97 5993608.86 476717.38 MWD+IFR-AK-CAZ-SC 1785.37 52.53 114.97 1612.13 1556.93 -344.21 479.67 5993577.83 476783.98 MWD+IFR-AK-CAZ-SC ~ 1881.61 58.34 114.67 1666.70 1611.50 -377.46 551.57 5993544.35 476855.77 MWD+IFR-AK-CAZ-SC I 1974.76 64.78 116.63 1711.04 1655.84 -412.93 625.34 5993508.65 476929.42 MWD+IFR-AK-CAZ-SC ~ 2070.14 63.01 116.83 1753.01 1697.81 -451.45 701.84 5993469.89 477005.78 MWD+IFR-AK-CAZ-SC 2165.79 63.78 116.90 1795.85 1740.65 -490.10 778.13 5993431.01 477081.95 MWD+IFR-AK-CAZ-SC 2259.81 65.50 113.58 1836.12 1780.92 -526.30 854.97 5993394.56 477158.66 MWD+IFR-AK-CAZ-SC 2354.77 65.84 113.23 1875.25 1820.05 -560.67 934.38 5993359.95 477237.95 MWD+IFR-AK-CAZ-SC 2449.13 66.14 108.97 1913.66 1858.46 -591.69 1014.77 5993328.68 477318.24 MWD+IFR-AK-CAZ-SC ! • Halliburton Company Survey Report Cumpau~: GonocoPhillips Alaska Inc. Field: Kuparuk River Unit Site: Kuparuk 3S Pad Well: 3S-O8 WeIlpath: 3S-OSC Survev Dote: 2/1!2008 ' ' lime: 14:19:4? Page: 2 Co-ordinate(iVE) Reference: WeIL' 3S-08, True North Vertical (TVD)Reference: 3S-08C D141 (27.7+27.5) 55.2 Section (VS) Reference: Well (O.OON,O.OOE,225.OOAzi) Survey Calculation Method: Minimum Curvature Db: Oracle J IViD Inc! Azim TVD Sys TVD N/S ft deg deg ft ft ft 2544.66 65.87 108.96 1952.50 1897.30 -620.05 2639.94 66.03 109.60 1991.33 1936.13 -648.78 2734.92 65.43 106.67 2030.38 1975.18 -675.73 2829.59 65.55 104.26 2069.66 2014.46 -698.70 2925.17 65.42 105.22 2109.32 2054.12 -720.82 3021.05 65.82 105.29 2148.90 2093.70 -743.80 3116.62 65.99 107.00 2187.92 2132.72 -768.06 3211.43 65.70 106.00 2226.71 2171.51 -792.63 3305.54 65.08 107.19 2265.91 2210.71 -817.06 3400.21 65.38 108.39 2305.57 2250.37 -843.33 3493.92 65.83 107.92 2344.28 2289.08 -869.92 3588.25 65.79 107.34 2382.93 2327.73 -895.98 3683.84 65.23 108.21 2422.56 2367.36 -922.54 3779.24 65.86 107.05 2462.05 2406.85 -948.83 3874.73 65.74 106.75 2501.19 2445.99 -974.15 3970.16 65.42 106.62 2540.65 2485.45 -999.10 4063.08 65.81 108.79 2579.01 2523.81 -1024.84 4159.70 65.75 108.42 2618.65 2563.45 -1052.95 4207.48 65.69 108.13 2638.30 2583.10 -1066.61 4262.50 65.87 108.67 2660.87 2605.67 -1082.45 4358.07 64.79 113.08 2700.78 2645.58 -1113.37 4451.79 59.17 117.67 2744.80 2689.60 -1148.72 4500.26 58.64 117.36 2769.84 2714.64 -1167.89 4545.63 58.35 119.57 2793.55 2738.35 -1186.33 4639.73 57.68 119.64 2843.39 2788.19 -1225.76 4732.81 55.75 123.39 2894.49 2839.29 -1266.39 4826.15 53.84 126.45 2948.30 2893.10 -1310.02 4921.29 50.05 125.63 3006.94 2951.74 -1354.10 5016.64 45.72 124.21 3070.87 3015.67 -1394.60 5111.64 41.28 125.65 3139.76 3084.56 -1432.00 5205.60 38.12 126.72 3212.05 3156.85 -1467.42 5298.94 34.80 131.10 3287.12 3231.92 -1502.17 5392.35 33.12 135.91 3364.61 3309.41 -1538.03 5486.51 29.99 143.10 3444.87 3389.67 -1575.35 5582.19 28.97 151.87 3528.20 3473.00 -1614.92 5676.01 24.20 158.41 3612.09 3556.89 -1652.87 5770.29 23.16 165.79 3698.45 3643.25 -1688.82 5866.61 22.76 173.36 3787.16 3731.96 -1725.70 5961.20 22.17 173.36 3874.57 3819.37 -1761.60 6055.43 21.92 173.57 3961.91 3906.71 -1796.74 6149.85 23.25 174.93 4049.09 3993.89 -1832.82 6245.34 22.52 174.79 4137.06 4081.86 -1869.80 6340.50 22.48 174.49 4224.98 4169.78 -1906.06 6433.20 23.63 174.41 4310.27 4255.07 -1942.19 6528.01 22.90 173.88 4397.37 4342.17 -1979.44 6620.19 24.05 175.47 4481.92 4426.72 -2016.00 6715.84 23.64 175.17 4569.41 4514.21 -2054.54 6809.69 23.21 174.30 4655.52 4600.32 -2091.69 6898.12 25.37 180.04 4736.13 4680.93 -2127.99 6998.17 26.43 181.55 4826.13 4770.93 -2171.68 7093.67 26.94 186.24 4911.47 4856.27 -2214.44 7187.91 27.42 188.14 4995.31 4940.11 -2257.14 7378.00 30.06 200.22 5162.11 5106.91 -2345.23 I~aW - _ - MapN MapE fool ft ft ft -- - 1097.31 - _ _ 5993300.06 __ 477400.68 MWD+IFR-AK-CAZ-SC 1179.43 5993271.07 477482.70 MWD+IFR-AK-CAZ-SC 1261.70 5993243.86 477564.88 MWD+IFR-AK-CAZ-SC 1344.72 5993220.63 477647.81 MWD+IFR-AK-CAZ-SC 1428.82 5993198.24 477731.83 MWD+tFR-AK-CAZ-SC 1513.07 5993175.00 477816.00 MWD+IFR-AK-CAZ-SC 1596.87 5993150.48 477899.72 MWD+IFR-AK-CAZ-SC 1679.81 5993125.65 477982.57 MWD+IFR-AK-CAZ-SC 1761.81 5993100.96 478064.48 MWD+IFR-AK-CAZ-SC 1843.65 5993074.44 478146.24 MWD+IFR-AK-CAZ-SC 1924.75 5993047.59 478227.24 MWD+IFR-AK-CAZ-SC 2006.75 5993021.27 478309.16 MWD+IFR-AK-CAZ-SC 2089.59 5992994.46 478391.90 MWD+IFR-AK-CAZ-SC 2172.35 5992967.90 478474.57 MWD+IFR-AK-CAZ-SC 2255.69 5992942.32 478557.82 MWD+IFR-AK-CAZ-SC 2338.92 5992917.11 478640.96 MWD+IFR-AK-CAZ-SC 2419.54 5992891.12 478721.49 MWD+IFR-AK-CAZ-SC 2503.05 5992862.74 478804.90 MWD+IFR-AK-CAZ-SC 2544.40 5992848.96 478846.21 MWD+IFR-AK-CAZ-SC 2592.02 5992832.97 478893.76 MWD+IFR-AK-CAZ-SC 2673.14 5992801.79 478974.78 MWD+IFR-AK-CAZ-SC 2747.87 5992766.21 479049.39 MWD+IFR-AK-CAZ-SC 2784.68 5992746.92 479086.14 MWD+IFR-AK-CAZ-SC 2818.68 5992728.38 479120.08 MWD+IFR-AK-CAZ-SC 2888.08 5992688.74 479189.34 MWD+IFR-AK-CAZ-SC 2954.40 5992647.90 479255.53 MWD+IFR-AK-CAZ-SC 3016.94 5992604.07 479317.92 MWD+IFR-AK-CAZ-SC 3077.50 5992559.81 479378.33 MWD+IFR-AK-CAZ-SC 3135.46 5992519.13 479436.16 MWD+IFR-AK-CAZ-SC 3189.07 5992481.56 479489.65 MWD+IFR-AK-CAZ-SC 3237.52 5992445.99 479537.98 MWD+IFR-AK-CAZ-SC 3280.70 5992411.11 479581.05 MWD+IFR-AK-CAZ-SC 3318.55 5992375.13 479618.78 MWD+IFR-AK-CAZ-SC 3350.60 5992337.72 479650.71 MWD+IFR-AK-CAZ-SC 3375.90 5992298.06 479675.88 MWD+IFR-AK-CAZ-SC 3393.70 5992260.06 479693.56 MWD+IFR-AK-CAZ-SC 3405.36 5992224.08 479705.11 MWD+IFR-AK-CAZ-SC 3412.17 5992187.19 479711.79 MWD+IFR-AK-CAZ-SC 3416.35 5992151.28 479715.86 MWD+IFR-AK-CAZ-SC 3420.37 5992116.13 479719.77 MWD+IFR-AK-CAZ-SC 3424.00 5992080.04 479723.28 MWD+IFR-AK-CAZ-SC 3427.32 5992043.05 479726.49 MWD+IFR-AK-CAZ-SC 3430.72 5992006.79 479729.77 MWD+IFR-AK-CAZ-SC 3434.23 5991970.65 479733.17 MWD+IFR-AK-CAZ-SC 3438.05 5991933.39 479736.87 MWD+IFR-AK-CAZ-SC 3441.45 5991896.82 479740.15 MWD+IFR-AK-CAZ-SC 3444.60 5991858.28 479743.18 MWD+IFR-AK-CAZ-SC 3448.02 5991821.12 479746.48 MWD+IFR-AK-CAZ-SC 3449.74 5991784.82 479748.09 MWD+IFR-AK-CAZ-SC 3449.12 5991741.14 479747.33 MWD+IFR-AK-CAZ-SC 3446.20 5991698.39 479744.27 MWD+IFR-AK-CAZ-SC 3440.80 5991655.71 479738.74 MWD+IFR-AK-CAZ-SC 3418.13 5991567.70 479715.79 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 2/1/2008 Time: 14:19:47 Pagc: 3 Field: Kuparuk River Unit Co-ordinate(NE)Referenee: Wefl: 3S-08, True North Site: Kuparuk 3S Pad Vertical (TVD) Reference: 3S-08C D141 (27.7+27.5) 55.2 WeII: 3S-08 Section (VS) Reference: Well (O.OON,O.OOE,225.OOAzi) Wellpath: 3S-08G Survey Calculation iVlethod: Minimum Curvature Db: Oracle Sun~c~ ~~(D Incl lzim TVD SvsTVD N/S E/W 111apN Mapl: Tool ft deg deg ft ft ft ft ft ft 7473.04 32.88 204.84 5243.17 5187.97 -2391.00 3399.06 5991522.00 479696.57 MWD+IFR-AK-CAZ-SC ~ 7567.55 34.90 207.50 5321.62 5266.42 -2438.27 3375.79 5991474.81 479673.16 MWD+IFR-AK-CAZ-SC 7663.58 37.23 208.94 5399.25 5344.05 -2488.06 3349.05 5991425.10 479646.26 MWD+IFR-AK-CAZ-SC 7756.66 42.04 212.24 5470.92 5415.72 -2539.10 3318.77 5991374.17 479615.83 MWD+IFR-AK-CAZ-SC 7809.13 42.84 213.96 5509.64 5454.44 -2568.76 3299.44 5991344.57 479596.40 MWD+IFR-AK-CAZ-SC 7850.18 43.92 215.10 5539.48 5484.28 -2591.98 3283.45 5991321.40 479580.35 MWD+IFR-AK-CAZ-SC 7896.27 46.21 217.19 5572.03 5516.83 -2618.32 3264.20 5991295.13 479561.01 MWD+IFR-AK-CAZ-SC 7944.79 49.17 218.14 5604.69 5549.49 -2646.71 3242.28 5991266.81 479539.00 MWD+IFR-AK-CAZ-SC 8004.20 50.05 220.89 5643.19 5587.99 -2681.61 3213.48 5991232.00 479510.10 MWD+IFR-AK-CAZ-SC 8040.61 53.19 224.03 5665.79 5610.59 -2702.65 3194.21 5991211.03 479490.76 MWD+IFR-AK-CAZ-SC 8091.32 56.67 225.46 5694.93 5639.73 -2732.11 3164.99 5991181.66 479461.45 MWD+IFR-AK-CAZ-SC 8133.84 60.03 225.53 5717.24 5662.04 -2757.48 3139.18 5991156.38 479435.56 MWD+IFR-AK-CAZ-SC 8186.00 65.03 226.92 5741.29 5686.09 -2789.48 3105.77 5991124.49 479402.05 MWD+IFR-AK-CAZ-SC 8229.99 69.12 228.02 5758.42 5703.22 -2816.85 3075.91 5991097.21 479372.11 MWD+IFR-AK-CAZ-SC 8279.34 72.88 228.25 5774.48 5719.28 -2847.99 3041.17 5991066.19 479337.27 MWD+IFR-AK-CAZ-SC 8324.58 75.66 229.49 5786.75 5731.55 -2876.63 3008.37 5991037.66 479304.39 MWD+IFR-AK-CAZ-SC 8371.09 77.74 231.50 5797.45 5742.25 -2905.41 2973.45 5991008.99 479269.38 MWD+IFR-AK-CAZ-SG 8417.87 80.44 231.69 5806.30 5751.10 -2933.95 2937.46 5990980.57 479233.30 MWD+IFR-AK-CAZ-SC 8462.45 82.14 231.94 5813.05 5757.85 -2961.19 2902.82 5990953.44 479198.58 MWD+IFR-AK-CAZ-SC 8512.92 82.68 232.08 5819.72 5764.52 -2991.98 2863.39 5990922.78 479159.06 MWD+IFR-AK-CAZ-SC 8562.20 84.00 233.39 5825.43 5770.23 -3021.62 2824.44 5990893.27 479120.02 MWD+IFR-AK-CAZ-SC 8606.54 84.29 234.64 5829.96 5774.76 -3047.53 2788.75 5990867.47 479084.25 MWD+IFR-AK-CAZ-SC 8653.40 84.34 234.13 5834.60 5779.40 -3074.69 2750.84 5990840.44 479046.26 MWD+IFR-AK-CAZ-SC 8700.56 84.34 235.09 5839.25 5784.05 -3101.86 2712.58 5990813.38 479007.92 MWD+IFR-AK-CAZ-SC 8780.39 85.24 234.97 5846.50 5791.30 -3147.43 2647.44 5990768.03 478942.64 MWD+IFR-AK-CAZ-SC 8823.57 85.27 235.92 5850.07 5794.87 -3171.84 2612.00 5990743.74 478907.12 MWD+IFR-AK-CAZ-SC 8862.93 85.09 231.92 5853.38 5798.18 -3194.93 2580.31 5990720.75 478875.36 MWD+IFR-AK-CAZ-SC 8892.72 86.64 230.79 5855.53 5800.33 -3213.48 2557.10 5990702.27 478852.10 MWD+IFR-AK-CAZ-SC 8927.53 88.15 230.17 5857.11 5801.91 -3235.61 2530.28 5990680.23 478825.21 MWD+IFR-AK-CAZ-SC 8958.65 89.66 230.71 5857.71 5802.51 -3255.43 2506.29 5990660.49 478801.16 MWD+IFR-AK-CAZ-SC 8991.05 90.48 230.60 5857.67 5802.47 -3275.97 2481.23 5990640.03 478776.04 MWD+IFR-AK-CAZ-SC 9081.86 93.23 230.96 5854.73 5799.53 -3333.35 2410.93 5990582.87 478705.56 MWD+IFR-AK-CAZ-SC 9173.50 93.43 230.65 5849.40 5794.20 -3391.17 2340.02 5990525.29 478634.48 MWD+IFR-AK-CAZ-SC 9265.23 92.02 231.83 5845.04 5789.84 -3448.53 2268.58 5990468.16 478562.86 MWD+IFR-AK-CAZ-SC 9361.11 90.55 230.89 5842.89 5787.69 -3508.38 2193.71 5990408.55 478487.81 MWD+IFR-AK-CAZ-SC 9456.04 87.87 231.76 5844.20 5789.00 -3567.69 2119.61 5990349.48 478413.53 MWD+IFR-AK-CAZ-SC 9549.07 88.70 231.85 5846.99 5791.79 -3625.19 2046.53 5990292.22 478340.28 MWD+IFR-AK-CAZ-SC 9619.14 86.57 231.65 5849.88 5794.68 -3668.53 1991.56 5990249.06 478285.17 MWD+IFR-AK-CAZ-SC ~ 9710.67 86.50 231.62 5855.41 5800.21 -3725.24 1919.92 5990192.59 478213.36 MWD+IFR-AK-CAZ-SC 9806.76 85.50 231.59 5862.11 5806.91 -3784.77 1844.80 5990133.30 478138.06 MWD+IFR-AK-CAZ-SC I 9900.72 88.59 232.57 5866.95 5811.75 -3842.43 1770.78 5990075.88 478063.87 MWD+IFR-AK-CAZ-SC 9992.10 89.55 234.78 5868.44 5813.24 -3896.55 1697.17 5990022.00 477990.10 MWD+IFR-AK-CAZ-SC 10086.96 91.85 235.47 5867.28 5812.08 -3950.78 1619.36 5989968.02 477912.12 MWD+IFR-AK-CAZ-SC 10181.30 91.85 236.64 5864.23 5809.03 -4003.43 1541.14 5989915.62 477833.74 MWD+IFR-AK-CAZ-SC 10276.02 89.69 233.42 5862.96 5807.76 -4057.70 1463.55 5989861.60 477755.98 MWD+IFR-AK-CAZ-SC I 10370.20 90.79 233.68 5862.57 5807.37 -4113.66 1387.79 5989805.89 477680.06 MWD+IFR-AK-CAZ-SC 10462.73 90.03 234.61 5861.90 5806.70 -4167.85 1312.80 5989751.94 477604.90 MWD+IFR-AK-CAZ-SC 10558.37 90.00 237.39 5861.88 5806.68 -4221.33 1233.52 5989698.72 477525.46 MWD+IFR-AK-CAZ-SC 10650.01 90.41 241.87 5861.55 5806.35 -4267.65 1154.47 5989652.66 477446.28 MWD+IFR-AK-CAZ-SC 10741.45 92.27 237.55 5859.41 5804.21 -4313.74 1075.56 5989606.82 477367.23 MWD+IFR-AK-CAZ-SC 10836.14 89.52 238.50 5857.93 5802.73 -4363.87 995.25 5989556.95 477286.77 MWD+IFR-AK-CAZ-SC 10930.84 87.67 239.51 5860.25 5805.05 -4412.62 914.11 5989508.46 477205.47 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 2/1/2008 Time: 14:19:47 Page: 3 Field: Ku paruk River Unit Co-ordinate(,YE) Reference: Well: 3S-08, True North Site: Ku paruk 3S Pad Vertical (TVD) Re ference: 3S-08C D141 (27.7+27.5) 55.2 Nell: 3S-08 Sectio n(VS)Refer ence:- Well (O.OON,O.O OE,225.OOAzi) Wellpath:''35-08C Survey Calculation Method: Minimum Curvature rr Db: Oracle Survey 'SID Tucl Azim TVD Sc, ll'D ti/S E!W 'D4upV MapE Tool ft deg deg ft ft ft ft ft ft 10991.68 87.36 248.19 5862.90 5807.70 -4439.39 859.60 5989481.87 477150.89 MWD+IFR-AK-CAZ-SC 11038.64 87.39 247.93 5865.05 5809.85 -4456.91 816.08 5989464.49 477107.32 MWD+IFR-AK-CAZ-SC 11130.90 91.47 247.28 5865.97 5810.77 X492.05 730.80 5989429.62 477021.94 MWD+IFR-AK-CAZ-SC 11225.89 92.81 246.31 5862.42 5807.22 -4529.45 643.56 5989392.50 476934.59 MWD+IFR-AK-CAZ-SC 11317.93 89.49 242.56 5860.57 5805.37 -4569.15 560.58 5989353.07 476851.49 MWD+IFR-AK-CAZ-SC 11413.49 91.48 238.10 5859.76 5804.56 -4616.44 477.57 5989306.05 476768.34 MWD+IFR-AK-CAZ-SC 11506.25 92.37 237.40 5856.65 5801.45 -4665.91 399.17 5989256.83 476689.79 MWD+IFR-AK-CAZ-SC 11606.88 93.12 237.48 5851.83 5796.63 -4720.00 314.45 5989203.01 476604.91 MWD+IFR-AK-CAZ-SC 11699.21 88.53 238.57 5850.50 5795.30 -4768.88 236.16 5989154.39 476526.47 MWD+IFR-AK-CAZ-SC ~ 11789.94 87.39 236.82 5853.73 5798.53 -4817.33 159.53 5989106.19 476449.69 MWD+IFR-AK-CAZ-SC 11882.60 84.57 235.62 5860.22 5805.02 -4868.72 82.71 5989055.05 476372.72 MWD+IFR-AK-CAZ-SC 11977.35 85.57 235.08 5868.37 5813.17 -4922.39 5.05 5989001.63 476294.90 MWD+IFR-AK-CAZ-SC 11998.16 87.39 233.38 5869.64 5814.44 -4934.53 -11.80 5988989.54 476278.02 MWD+IFR-AK-CAZ-SC 12055.00 87.39 233.38 5872.23 ~ 5817.03 -4968.40 -57.37 5988955.82 ~ 476232.34 ~ PROJECTED to TD 3S-08C -Proposition to move u_p liner top packer • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, January 18, 2008 1:54 PM To: 'Kemper, Tyrone T.' Cc: Eggemeyer, Jerome C.; McKeever, Steve; Brink, Jason A; Gober, Howard Subject: RE: 3S-08C (207-'F63) -Proposition to move up liner top packer Ty, Moving the top of the liner as you propose is acceptable. Nothing further is needed. Tom Maunder, PE AOGCC Page 1 of 2 From: Kemper, Tyrone T. [mailto:Tyrone.T.Kemner@conocophillips.eom] Sent: Friday, January 18, 2008 1:42 PM To: Maunder, Thomas E (DOA) Cc: Eggemeyer, Jerome C.; McKeever, Steve; Brink, Jason A; Gober, Howard Subject: 3S-08C -Proposition to move up liner top packer Tom, I've tried to summarize our telephone conversation from earlier today: Initial completion pion (after drifting 6-118" production hole) assuming 9.0 to 9.5 ppg mud weight: • Run 4-1/2" liner with pre-pertd pups and set liner top packer at 8,610' MD (7" shoe at 8,795` MD & TD at 12,055' MD) • RIH with 3-1/2" tubing to liner top packer and displace to 9.0 to 9.5 ppg NaCI/NaBr brine • Sting 3-112" tubing into seafbore below liner top packer and Land tubing hanger in tubing spool" * This plan would have left 12.5 bbts of 9.0 to 9.5 ppg NaCI/NaBr brine in the 3-112" x 7" annulus between the lowest GLM (at 8,134` MD) and the liner top packer Proposed completion plan (after drilling 6-1/8" production hole) knowing 12.9 ppg mud weight: • Run 4-1/2" liner with pre-perPd pups and set liner top packer at 8,188' MD (7" shoe at 8,795` MD & TD at 12,055' MD} • RIH with 3-1/2" tubing to liner top packer and spot 12.9 ppg mud with corrosion inhibitor between the liner top packer and the lowest GLM (no options available fora 12.9 ppg brine} • Sting 3-1/2" tubing into sealbore below liner tap packer and land tubing hanger in tubing spoof** "* This wilt leave 1.5 bbls of 12.9 ppg mud with corrosion inhibitor in the 3-1/2" x 7" annulus between lowest the GLM (at 8,134' MD) and the liner top packer (vs. 12.5 bbls of mud if we were not to move up the finer top packer) I feet that moving the liner top packer up and reducing the volume of mud in the 3-1/2" x 7" annulus between the lowest GLM and the liner top packer will give us the best chance (in future workovers) to puff the 3-1/2" tubing 1/18/2008 3S-08C - Fropositian to move~Iiner top packer . Page 2 of 2 from the sealbore. Please let me know if the above proposal is acceptable. Also, let me know if you need further information. Regards, Ty Kemner Completions Engineer ConocoPhillips Alaska lnc. phone (907) 265-6480 cell (907) 632-9107 fax (918) 662-6975 tyrone.t. kemner~conocophillips.com 1/18/2008 ~~~~ ~ ~ ~ SARAH PAL/N, GOVERNOR CONSEBj?~ A'jip C ~L~+I ~ 333 W 7th AVENUE, SUITE 100 -7 ~i~ ~~~~~~11~~ii ---777-7 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Drilling Team Leader Conoco Phillips Alaska Inc. PO Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3S-O8C Conoco Phillips Alaska Inc. Permit No: 207-163 Surface Location: 2492' FNL, 954' FEL, SEC. 18, T12N, R8E, UM Bottomhole Location: 2204' FSL, 2232' FEL, SEC. 19, T12N, R8E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted 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 per ' . When providing notice for a representative of the Commission to wit ss a y required test, contact the Commission's petroleum field inspector (907) 59-3607 (pager). DATED this day of November, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConocoPhillips Post Office Box 100360 ~ ~~~ Anchorage, Alaska 99510-0360 Randy Thomas rt,J Phone (907) 265-6830 NU y ~ ~ 200 Fax: (907) 265-1535 EmaiL• randy.I.thomas@conocophillips.com .~~BSk? l~1 f~ Gay GOn~. Ci1f1Mi1SSI0f1 Ar~eh4rage November 15, 2007 Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, Rotary Sidetrack, Producer 3S-08C Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill/Sidetrack an onshore Producer well, KRU 3S-08C, a development well. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). The expected spud date is December 03, 2007. If you have any questions or require any further information, please contact Jason Brink at 265-6419. i +. Sincerely, i Randy Thomas GKA Drilling Team Leader i`I ~ l l .o~ i~CEli/~~3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ~ 9 20OT PERMIT TO DRILL ~"~Alaska di! ~ Gas Eons, Commission 20 AAC 25.005 QpChOfa~B 1a. Type of Work: Drill ^ Re-drill ^~ Re-entry ^ 1b. Current Well Class: Exploratory Development Oil O ~ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone^ Single Zone ^ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: 3S-08C 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 13538' ~ ND: 5829' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 2492' FNL, 954' FEL, Sec. 18, T12N, R8E, UM 7. Property Designation: ADL 380107 ~ Kuparuk Oil Pool Top of Productive Horizon: 439' FNL, 1568' FWL, Sec. 20, T12N, R8E, UM 8. Land Use Permit: ALK 4624 13. Approximate Spud Date: 12/3/2007 Total Depth: 2204' FSL, 2232' FEL, Sec. 19, T12N, R8E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 2232' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 476305 ~ y- 5993923 Zone- 4 10. KB Elevation (Height above GL): Z8.6' AMSL feet 15. Distance to Nearest well within Pool: 3S-03 , 16. Deviated wells: Kickoff depth: 4300 ft. Maximum Hole Angle: 94.8° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2681 psig . Surface: 2056 psig > 18. Casing Program \ S if ti Setting Depth Quantity of Cement Size pec ons ica Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 8.5" 7" 26# L-80 BTCM 8948' 108' , 108' 8948' , 5868' ~ 180 sx Class G w/GasBLOK 6.125" 4.5" 12.6# L-80 IBTM 4590' 8948', 5868' 13538' ~ 5829' , pre-perfed liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): 8815' Total Depth ND (ft): 6062' Plugs (measured) none Effective Depth MD (ft): 8592' Effective Depth ND (ft): Junk (measured) none Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 75 sx ArcticCrete 108' 108' Surface 4239' 9.625" 664 sx AS Lite, 391 sx LiteCrete 4263' 2662' Intermediate Production 8778' 7" 255 sx Class G w/GasBlok 8802' 6053' Liner Perforation Depth MD (ft): 8491'-8529' Perforation Depth TVD (ft): 5857'-5881' 20. Attachments: Filing Fee ^ BOP Sketch ^ Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^~ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jason Brink @ 265-6419 Printed Name Randy Thomas Title Drilling Team Leader / Signature ~ ~~~~ Phone ~(,S`68 3V Date ~~ ~t Sr~7 h All Drak Commission Use Only Permit to Drill Number: ~~~163~ API Number: 50- I03o?D-,~~S00300 Permit Approval Date: See cover letter for other requirements Conditions of apprOVa! : !f box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates gas contained in shales: Samples req'd: Yes ^ No ~, M to 'd: Yes ^ No [~ Other: ~ 5~~ ~~ ~ (2 ?1`J ~~~ H2S measures: Yes yN,~o - D sv eq'd: Yes [f~ No ^ 1~V ` ~ ` I' t ~1 ~/: .e• ROVED BY THE COMMISSION DATE: /~ ~ iD ,COMMISSIONER Form 10-401 Revised 12/2005 ! 1 ~ ~ ~ ~ ~ ~ ~ ~'~ ~` ~ ,ubmit in Duplicate `. J Ap~tion for Permit to Drill, Well 3S-08C Saved: 15-Nov-07 Permit It - We113S-08C Producer • ~ ,,, Application for Permit to Drill Document "'~ ~ ~~ ~'~ Well V41uR Table of Contents 1. Well Name .................................................................................................................................2 Requirements of 20 AAC 25.005 (~ ........................................................................................................................ 2 2. Location Summary ...................................................................................................................2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................................... 2 Requirements of 20 AAC 25.050(b) ........................................................................................................................ 2 3. Blowout Prevention Equipment Information ........................................................................3 q f ()() ................................................................................................................... Re uirements o 20 AAC 25.005 c 3 3 4. Drilling Hazards Information .................................................................................................3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests .........................................................3 Requirements of 20 AAC 25.005 (c)(S) ...............................'..............................................................................'.... 3 6. Casing' and Cementing Program .......................................................:................................:...4 I I 13. Proposed Drilling Program .....................................................................................................5 Requirements of 20 AAC 25.005 (c)(13)~ .............................:.1...... ~.............................:.1.......~..............................:L. S OIGINAL Requirements of 20 AAC 25.005(c)(6) ..........................................~......................................................................... 4 ~ ~ ~, ~. 7. Diverter System Information ..:................................:................................``............................4 Re uirements o 20 AAC 25.005 c 7 ~ ~ .............................; ........:................................. 4 ~ R' .f OO ........................................... I I, I, I, I 8. Drillin~ Fluid Program.....' .... , .........................' .....,..............................,.........................' ..4 ,,' Requirem,~nts of 20 AAC 2S. 005(c (g) ..:........ ...................... .......:............................. . .......:'................................. 4 ~ ~ ~~ .....:........................:~...............................'f , 9. Abnormally!. Pressured Formation Information. ..4 I ~ ~ .: ............................~........:'.............................~........ ~. .. 4 4 Requirements o 20 AAC 25.005 (')(9) 10. Seismic ~~ ~ ~I ~ ~' Re uirem Analysis ........................ ...... .....................................................................5 . ......... q ~ O( )~ ................. .. .........~......... ...... ...... ~. ....5 ents 20 AAC 25.005 c 10 •••••..'•••••••• ................................}................................t...5 11. Seabed'Conditton Analysi$ ................................ Requirements of 20 AAC 25.005 (c)(11) ................................................................................................................ S 12. Evidence of Bonding .........:~ ................................:~.......:........................::......1.:.....................:.:..5, ', Requirements of 20 AAC 25.005 (c)(12) ................................................................................................................ S. 3S-08C APD Page 1 of 7 Printed: 15-Nov-07 Ap~tion for Permit to Drill, Well 3S-08C Saved: 15-Nov-07 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .......................................7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................................ 7 15. Attachments ..............................................................................................................................7 Attachment 1 Directional Plan .............................................................................................................................. 7 Attachment 2 Drilling Hazards Summary ............................................................................................................. 7 Attachment 3 Well Schematic ................................................................................................................................ 7 Attachment 4 Cement Summary ............................................................................................................................. 7 1. Well Name Requirements of 20 AAC 25.005 (~ Each well must be ident~ed by a unique name designated by the operator acrd a unique API number assigned by tlxe commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 3S-08C. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat ident~ing the property` and the property's owners and showirag (A) the coordinates of the proposed location of the well at the surface, at tJze top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation mzd at total depth; Location at Surface 2492' FNL, 955' FEL, Sec. 18, T12N, R8E, UM NGSCoordinates RKB Elevation 56.3' AMSL Northings: 5,993,923 Eastings: 476,305 Pad Elevation 27.7' AMSL Location at Top of Productive Interval (Ku aruk) 439' FNL, 1568' FWL, Sec. 20, T12N, R8E, UM 1vGS Coordinates ` ` Measured Ike th, RKB: 8, 18' Northings: 5,990,689 Eastings: 478,829 Total Vertical Depth, RKB: 5,865' Total Vertical De th, SS: 5,809' ocation at Total De t ' '204', FSL, 2232' FEL, ec.,19, T12N, R8E, M GSCoordinares Measu;edD'epth, RKB: 13,538' Northings: 5,988,064 li.C'astzngs: 475,031 ' ~ Total Vertical De th, RKB: ~ 5,829' Total Vertical De th, SS: 5,773' ar7~ ~. (D other information required b ~20 At1C 25.OSO(b); Requirements of 20 AAC 2 '.050(b) If a,~rell is to be intentionally devikted, the application for. a Per~it to Drill (Form 10-401) must~~ ~ ~' (I) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, tincluding all adjacent wellbores within,200 feet of any ~~' portion of the proposed ia~~tl; ~ ~ ~~ l Please see Attachment 1: Directional Plan and (2) for all ~r~ells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are kno~a~n or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or i (B) state that the appli~ant is the only affected owner. ~ ~ ~ ~ ' 3S-08C APD Page 2 of 7 o ~ ~ ~ 1 ~ A ~ Prlnted: 15-Nov-07 The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Ap~ion for Permit to Drill, Well 3S-08C Saved: 15-Nov-07 Requirements of 20 AAC 25.005(c)(3) An application for' a Permit to Drill mzrst be accompanied by each of the following items, except for an item already on file with the commission and identfed in the application: (3) a diagram and description of the blowout prevention eguipment (BOPE) as reguired by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 141. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identOed in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressure in the Kuparuk C sand will exhibit a pore pressure of 8.9 ppg. This pressure is predicted based on actual bottom hole pressure data from existing wells in the field together with reservoir model forecasts. 2700 psi ~ Equivalent Mud Weight @TD = = 8.9 ppg 5828'TVD x 0.052 The maximum potential surface pressure (MPSP) while drilling is calculated using the predicted reservoir pressure, a 0.11 psi/ft gas gradient, and a reservoir top TVD of 5828'. MPSP = ~GradientMud - Gradient~aS )TVD Gradient,,~ua = 8.9 ppg x 0.052 =.0.46 f tZ t Gradie~nt~as ~= 0.11 f ti t TVD = 5828 ft ~ 'r '~ '! ~~ MPSP= 046 ft-0.11 ft 5$28 ft=2056psi~' ~~, j, I, t 1 1 ~ t ++ 1 1 {; ~ ' I' (B) data onl potential gas pones; ~~ ~ I ~ '~ The well~bore 's not expected to penetrate any gas zones. ~ ~ ~ ~~ ~ ~~ ~~ ', f i 41 and ~ ~~ (C) data concerni~ potential causes of hole prob~ems such as abnormally geo p~essured strata, lost circulation pones, and pones that have a propensity for d~erential sticking; Please see Attachment 2 - Drillin~ Hazards Summary I II ! ,. ~ ,. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) An application for a Permit to Drill must be accompanied by each of the folloiuirzg items, except for an item already on file with the commission and ident~ed in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.0300; ~ ~ ~ ~ ~ ~ ~ ~ 3S-08C APD Page 3 of 7 Printed: 15-Nov-07 A}~tion for Permit to Drill, Well 3S-08C Saved: 15-Nov-07 Drill out surface casing shoe and perform LOT test or FIT in accordance with the Kuparuk LOT /FIT procedure that ConocoPhillips Alaska has on file with the Commission. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre perforated liner, or screen to be installed; Casin and Cementin Pro ram Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) in (Ib/ft) Grade Conn. (ft) (ft) (ft) Cement Pro ram 16 24 62.5 H-40 Welded 108', Surf 108' / 108' 9-5/8 12-1/4 40.0 L-80 BTC 4,263 , Surf 4,263 % 2662' Cement Top planned @ 7948' MD. 7 8-1/2 26.0 L-80 BTCM 8948 Surf 8948' / 5868' Cemented w/ 180 sx Class "G" w/ GasBLOK 4-1/2 6-1/8 12.6 L-80 IBTM 4590 8948' / 5868' 13,538' / 5829' , Pre-perfed liner / uncemented 6. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.03 (h) (2); Please reference diverter schematic on file for Doyon 141. 7. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) ~ ~ '~ An application for a Permit to Drill must be accompanied by each of the follo~~~ing items, except for an item already on file with the commission a d identified in the application: (~f a drilln~g fluid program, incl~fding a diagram and description2 of the drilling fluid system, a~N required by 20 AAC 25.033; ?` i DI filling will be done'using mud systems having th i following properties: I I ~ ~ ,i Intermediate Interval Production Interval Mud 7j~pe ~ `} LSND ~ ~ F1oPro Density (p 9.5-10.2 9.0 Funnel Viscosity(sec) 42-55 42-55 Yield oint j (cP) i 25-32 22-28 API Filtrate!(cc) ( <6 ~ ~ <6 pH i , 9.0-9.5 ; 9.0-9.5 Solids (%) 9-14 ~ 9-14 I J I I I Diagram of Doyon 141 Mud System on file. ,. ,. ,. Drilling fluid practices will be in accordance with appropriate regulatigns stated in 20 AAC 25.'033. 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) I An application for a Perrnitl to Drill must be accompanied ~y each of the following items, except for mz item already on file whys the commission and ident fled in the application: ORIGINAL 3S-08C APD Page 4 of 7 Printed: 15-Nov-07 Ap~tion for Permit to Drill, Well 3S-08C Saved: 15-Nov-07 (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25.033(fl; N/A -Application is not for an exploratory or stratigaphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test 1~~ell, a seismic refraction or reflection analysis as required by 20 AAC 25.061(aJ; N/A -Application is not for an exploratory or stratigaphic test well. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, exceptfor an item already on file with the commission and identified in the application.• (11) for a well drilled from an offshore platform, mobile bottom founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(h); N/A -Application is not for an offshore well. 11. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application.• (12) evidence showing that the requirements of ~0 AAC 25.025 Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling progam is listed below. Please refer to Attachment 3: Well Schematic. Pre-Rig. Well Work: 1. Test wellhead Packoffs and lock down screws. `~ 2. Set 3.5" cement retainer in tubing tail. `Circulate tbg/IA to brine`'thru open GLM `' I'' ~ ~ I 3. Perform ' ombo MIT. I I I , 4. RU CT and'sting into cement r aine'r. Squeeze cement ay.'. Un-sting and leav 60' of cement above ret finer:,, S. Tag and pressure test the cement plug. (AOGCC witness needed} ~,~~ ,~ ~,~ ,~ 6. Chemica cut 3'.5" tubin , ~ i i ~~ ~ ~ g ~ ~ ~ ~'1 ~ 4 i ~ i ~I ~I ~ I I i 7. Set BPV and prep wellhead for rig arrival. I i I I ~, l ~, Rig Work: ~' l' ~' ~' 1. Move in and rig up. 2. Nipple down tree and tubing head' adapter. 3. Install BOP blanking plug and NU BOP on the 11" x SK flange. Test BOP to 250 PSI / 3500 PSI. 4. Pull blanking plug and BPV. I ~ I I ~ I ~ 3S-08C APD Page 5 of 7 Printed: 15-Nov-07 A~tion for Permit to Drill, Well 3S-08C Saved: 15-Nov-07 5. Pull and lay down the tubing hanger. 6. Make up 7" cast iron bridge plug and set inside 7" casing 400' below surface casing shoe depth. Test CIBP to 3000 psi. 7. Mechanically cut 7" casing 200' below surface casing show depth. 8. Pull and lay down 7" casing. 9. Make up 3-1/2" mule shoe, 1,000' of 3-1/2" tubing stinger, 4" drill pipe and RIH to CIBP. 10. Spot a balanced cement plug on top of cast iron bridge plug with the top of cement inside 9-5/8" casing shoe. 11. Pull out of hole and lay down 3-1/2" tubing stinger. 12. Pick up drilling BHA, 4" drill pipe, and run in hole to top of cement and tag for cement hardness. Test 9-5/8" casing to 2000 PSI for 30 minutes and record on chart. Start of Drilling operations: 13. Drill cement to kickoff point and dri1120' to 50' of new hole. Perform LOT/FIT. 14. Directionally drill 8-1/2" intermediate hole section through the top of the Kuparuk C sand landing at approximately 8918' MD / 5865' TVD and 85 degrees deviation. 15. Run and cement 7" casing. 16. Make up 6-1/8" drilling assembly. Clean out to float collar and perform 30 minute casing test to 3.,000 psi. Drill out 20 to 50 feet of new hole and perform LOT/FIT. 17. Circulate hole from LSND to drill-in fluid. ,~ 18. Dri116-1/8" horizontal seition to well TD at 13,538' MD / 5829' TVD. ~ i 19. Run and set 4-1/2" pre-perfed liner. ~' I 20. POOH, laying down (drill pipe as required. }l . Run 3-'h, 9.3#, L-80 Bing with profile nippl f, gasf lift mandrels ands 'nger assembly to depth: { 22. Circulate corrosion inhibited fluid into the 3-1/2" x7" annulus. ~3. St~~ng in, space out a~d lan~ hanger. Run in l~ck d~'Yvn screws. ~ ~~ ~ ~~ i 2~4. In~tall BPV and blanking plug. Nipple down BOP. Nipple up adapter, tree ~nd test to 5000 PSI. Pu~l blanking plug and BPV. ~5. Pressure tubing and annulus, then shear the v~lve in the bottom gas lii~ mandrel. Freeze protec~ the tubing and IA with diesel. ~ ~ , ~ . ~ , . 26. Set BPV. 27. Rig down 3S-08C APD Page 6 of 7 o ~ ~ ~ ~ ~ A ~ Printed: 15-Nov-07 A~tion for Permit to Drill, Well 3S-08C Saved: 15-Nov-07 Post Rig Procedure 1. Rig up slickline and install gas lift design. 2. Flowback well to tanks to clean up returns before diverting into production facility. 3. Put well on production. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling nand and cuttings and a statement of whether the operator intends to reguest authori=anon wader 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska does intend to request authorization for the use of this well for annular disposal operations at a later date provided the well meets the regulatory requirements. 14. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary ~ ~ ~, ~ ~,. I, I, I, I, I, I, ~ ~i ~ ~~ ~ fi ~ fi ~ 4i ~ ~ ~ ~ ~~ ~, ~~ ~ ~ 3S-08C APD Page 7 of 7 r ~ ~ ~ ~ ` , ~ ~ Printed: 15-Nov-07 ' ~1 1 `~ ~ I I Plan: 3S-08C (wp05) Sperry Drilling Services Proposal Report -Geographic 14 November, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 3S Pad 3S-08 Plan 3S-08C ~, I; t i, i ~. ~~, ~~ ~~ i ~~~ , Local Coordinate Origin: ~ Ceritered on Well 3S-08 ~ ~ f l Viewing Datum: ~ ~ ~I 3S-08C @ 55.70ft ~~ TVDs to System: N North Reference: ~ True Unit System: API - US Survey Feet r ^ # HA~L~~V~ i o^M ~parrq/ DrFtiir~ i ~ neIGINAL P/Of@Ct: KUparUk RIVer ~ln/t - - - - WELL DETAILS: 35-08 REFERENCE INFORMATION Site: Kuparuk 3S Pad Grom~d Level: 27.70 Co-ordinate (N/E) Reference: Well 3S-08, True North Well: 3S-08 +N/-S +E/-W Northing Fasting Latittude Longitude Slot Vertical (ND) Reference: 3S-08C @ 55.70ft Wellbore: Plan 3S-OSC 0.00 0.00 5993923.52 476305.45 70°23'40.307N 150°ll'34.033W Section (VS) Reference: Slot- (O.OON, O.OOE) Measured Depth Reference: 3S-08C @ 55.70ft Plan: 3S-O8C (wpOS) Calculation Method: Minimum Curvature Geodetic Datum: NAD 1927 (NADCON CONUS~laska Zone 04 e ~ ~ HALLIBURTON Ph il C °o ips i onoco 2333 gp~rry Drilling S~rviO~s CASING DETAILS sp ~ -"- No MD TVD TVDss Name Size 5/8" - - - - 1 4263.07 266L40 2605.70 95/8" 9-5/8 - ~ --~ - -- - - - - ' - - 2 8947.78 5867.79 5812.09 7" 7 <-_ 3 13537.43 5828.70 5773 41/2" 4-1/2 450 9518" -' --__ ~~ t ~ 2917 --___ \` ~ 5000 ' - KOP 3°/100' @ 4300' MD, 2677' ND, TFO 60°: 1695' FSL, 1665' FWL - Sec17-T12N-ROSE 5500 3500 3508 _ N c 6p00 ...~...~ ^o u ,0 4083 ~~L ~ _ -- U ' ' ' ' 'C 7" Csg @-894B' MD, 5868'-ND: 439' FNL, 1544' FWL - Sec20-T12N-ROSE FEL - Sec19-T12N-ROSE ND: 2204 FSL, 2232 MD, 5829 BHL @ 13538 }~~ ~ _ - - - f 4667 ~ 9000 H ' g0 ~ ~ W 15~~ ~ ~ 5250 ' n 0 i X0 i ~ _ - - - - _ _ _cpy- _ O = _ ~ _ - ~ 0 7" ~ o° o 0 "' 4112 1 " ~~ ~ ro ~ ~ ~ ~i rn rn ~ ~ 5833 _ _ _ _ , - - - - - - - - - - - g ~ ° 4 ~ ~ • • ,. .-' o w- 3S-08C C4-Top (10-31-07) ; ; ° :. o o .. • o 3S_OSC MB Heel (10-31-07) ; ~' ~S-08C MB T2 (10-31-07) ~ • 3S-08C MB T4 (10-31-07) : ~, 3S-08C MB_T6 (10-31-07) , ~ • • 35-08C MB_T8 (10-31-07) ;~• 3S-08C MB_Toe ( _ 10-31-07) 6417 _ - - - -: • _al 3S-08C MB_T1 (10-31-07) 3S-08C MB T3 (10-31-07) 3S-08C MB T5 (10-31-07) 3S-OSC MB_T7 (10-31-07) 3S-08C MB_T9 (10-31-07) -1750 -1167 -583 0 583 1167 1750 2333 2917 3500 4083 4667 Vertical Section at 225.00° (700 ft/in) Project: Kuparuk River Unit Well Details: 3S-OS REFERENCE INFORMATION Site: Kuparuk 3S Pad Ground Level: 27.70 Co-ordinate (N/E) Reference: Well 3S-O8, True North W@II: 3S-O8 - _ _ +N/-S +E/-W Northurg Fasting Latittude Longitude Slot Vertical (TVD) Reference: 3S-08C @ 55.70ft 0.00 _ --6'00 ,599392352- 476305.45 70°23'40.307N 150°1I'34.033W Measured Depth Reference: 3S-OSC @ 55.70ft Wellbore Plan 3S-08C Calculation Method: Minimum Curvature Plan: 3$-O8C (WpOS) _ - Geodetic Datum: NAD 1927 (NADCON CONUSp,laska Zone 04 CASING DETAILS No MD T~~ TVDss Nazve Size 0 ~ y° 1 4263.07 2661 40 2605.70 9 5/8" 9-5/8 y°° 2 8947.78 5867.79 5812.09 7" 7 yo 3 13537.43 5828.70 5773 41/2" 4-I/2 n o -500 N \ / - - - .- - h h N _ _ _ O -1600 - ~- _~ -_ _.. - _._ ~e N _ _____ ~° __----- 95/8" ° ------- ~ °° s~ KOP 3°/100' (Aar, 4300' MD, 2G7T 'IVD, TFO 60°: IG95' FSL, 1665' FWL- Sec17-T12N-R08 '~ -1500 ~5~0 4000 -2000 4500 ...~.r -- - _ - __ _ -- - - "~ - o ~ 5000 ,~' o -2500 s1sr/ ~ 0 ~ ST~O '~ 3000 7" Csg Cd, 8948' MD, 5868' TVD: 439' FNL, 1544' FWL - Sec20.T12N-R08 ~~. '70 - - - - _ _ _ 7" ~ 35-08C C4-Top (10.31-07) C ___ - 3SOSC MB_Heel (10-31-07) s Q -3500 _ _ - -- - ~ ---_ - _~~ -- - - - - - 3S-0BC M1iB_TI (I0.3I-07) _ - _ _ -3SOSC MB T2 (10.31-07) -1000 - - _ - - - 3SOSC MB_T3 (10.31-07) BHL cci 13538' MD, 5829' TVD: 2204' FSL, 2232' FFZ - Sec19-TI2N-ROS ~ ~ - _ _ i 3SOSC MB_T4 (10.31-07) i i -1500 i - -- - - - 3SOSC MB_TS (10-31-07) i ~ - - - - - - - 3S08C MB_TG (10.31-07) i i -5000 - - -- ~-i' - - ------ --.- - -- i _ _ _ _ 3SOSC MB_T7 (1031-U71 i __ - - it - ---- - --3S08C M6_3;`8 (111-31-1171 - ~/ ~s ~ --------- Conocohhillips o -5500 8~, i _ _ _ _ _ _ _ _ 3SOSC MB T9 (I0.3I-1171 ~S}CB r~ ~ - AO , ~ HALLBLIRTON - - -3s-oac MB_Tee(lo-3l-u71 -6000 a 1/2" - - 19 _ aP~~rY DrilBnp S~rwbN -2500 -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7( - ~ ~ ` ~ "'~" West(-)/East(+) (1000 fT/in) ~ ~ Halliburton Company Compass Proposal Report -Geographic _. Database: .Sperry EDM .11 Local Co-ordinate Reference: Well 3S-08 Company: ConocoPhillips Alaska, Inc. ND Reference: 3S-08C @ 55.70ft Project: Kuparuk River Unit MD Reference: ~S-08C @ 55.70ft Site: I~:uparuk 3S Pad North Reference: True Well: °~S-08 Survey Calculation Method: Minimum Curvature Wellbore: Plan 3S-08C Design: 3S-O8C (wp05) Project Kuparuk River Unit. North SI©pe Alaska. U nited States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor W e I I 3S-08 Well Position +N/-S 0.00 ft Northing: 5,993,923.52 ft Latitude: 70° 23' 40.307" N +E/-W 0.00 ft Easting: 476,305.45ft Longitude: 150° 11' 34.033" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 27.70ft Wellboro Plan 3S-08C Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2007 9/13/2007 22.89 80.81 57,600 - Design ~~.~ 3S-08C!wp05) Audit Notes: Version: Phase: PLAN Tie On Depth: 4,300.00 Vertical Section: Depth From (ND) +N/-S +E/-W Direction Ift) (~i (n) l°) -0.60 ' , , i 0.00 0.00 225.00 , i _ i Ilr It: ~I ~i ~i Ir. ~I ~~ Ir: 'I ii ', (r 'I ~~ ~1' ii ~ 4'I ~ II 'I I i' I ~ ~ II ~ I '~ I 1 I I 41 'I I J ~ I I II '~ ~ I 1 II ~'~ ,~ ,~ r ,~ ~ ,~ ~ ~ ~~ i. ,~ ~~ ~~ ~~ ~~ , . 11/14/2007 10:14: 28AM Page 2 of 8 _ ~~~~~~~ COMPASS 2003.11 Build 48 Halliburton Company Compass Proposal Report -Geographic Database: Sperry EDM .11 Local Go-ordinate Reference: Well 3S-08 Company: ConocoPhillips Alaska, Inc. TVD Reference: 3S-08C @ 55.70ft ' Project: Kuparuk River Unit MD Reference: 3S-08C @ 55.70ft Site: Kuparuk 3S Pad f North Reference: True Well: 3S-08 Survey Calculation Method: Minimum Curvature Wellbore: Flan 3S-08C Design: 3S-08C (wp05) Plan Summary Measured Dogleg Build Turn Depth Inclination Azimuth TVD TVDSS +N/-S +E/-W Rate Rate Rate TFO 1ft) l~) ice) (ft1 (ft) (ft) (ft) (°/100ft) (°/100ft) (°I100ft) (°) 4,300.00 65.86 108.36 2,ti76.48 2,620.%8 -1,093.26 2,624.01 0.00 0.00 0.00 0.00 4,400.00 67.39 111.17 2,716.17 2,660.47 -1,124.30 2,710.38 3.00 1.53 2.81 60.00 5,877.22 22.90 174.81 3,776.21 3,720.51 -1,709.68 3,437.80 4.00 -3.01 4.31 156.02 6,948.22 22.90 174.81 4,762.77 4,707.07 -2,124.81 3,475.47 0.00 0.00 0.00 0.00 8,803.38 85.00 235.15 5,855.20 5,799.50 -3,161.51 2,627.84 4.00 3.35 3.25 64.10 8,918.11 85.00 235.15 5,865.20 5,809.50 -3,226.83 2,534.04 0.00 0.00 0.00 0.00 8,948.11 85.00 235.15 5,867.81 5,812.11 -3,243.90 2,509.52 0.00 0.00 0.00 0.00 8,965.13 85.65 235.18 5,869.20 5,813.50 -3,253.59 2,495.60 4.00 3.80 0.16 2.42 8,997.71 85.65 235.18 5,871.68 5,815.98 -3,272.14 2,468.93 0.00 0.00 0.00 0.00 9,080.71 89.00 235.15 5,875.55 5,819.85 -3,319.50 2,400.89 4.00 4.04 -0.03 -0.47 9,375.71 89.00 235.15 5,880.70 5,825.00 -3,488.04 2,158.83 0.00 0.00 0.00 0.00 9,468.81 86.21 235.00 5,884.59 5,828.89 -3,541.29 2,082.57 3.00 -3.00 -0.16. -176.87 9,524.37 86.21 235.00. 5,888.26 5,832.56. -3,573.09 2,037.16. 0.00 0.00 0.00 0.00 9,676.60 90.77 235.27, 5,892.27 5,836.57., -3,660.06 1,912.34, 3.00 2.99 .0.18 3.43 , 10,016.60 ~ 90.77 235.27, 5,887.70 5,832.00 -3,853.75 1,632.93 0.00 0.00 0.00 0.00 10,151.96 94.82 234.95 5,881.10 5,825.40 , -3,931.06 1,522.06 3.00 2.99 -0.23 -4.47 10,202.78 194.82 234.95 5;876.83 5,821.13 -3,960.14 1,480.60 ~ 0.00 0.00 0.00 0.00 10,341.56 90.66 235.16 5,870.20 5,814.50 -4039.52 1,366.99 3.00 -3.00 0.15 177.14 11,166.56 `` 90.66 ' .235.16 ,860.70 5,805.00 -4`510.80 689.92 `! 0.00 0.00 10.00 I 0.00 `r 11,271.94 i 87.50 235.06 5,862.39 5,806.69 -4,571.06 603.50 ~ 3.00 -3.00 -0.09 -178.24 11,479 63 t 87.50 235.06 ~ 5,871.45 5,815.75 ~ -4,1689.89 433.40 ~ i 0.00 0.00 ~ i .00 0.00 I 11,610166 ~ 91.43 235.15' 5',872.67 5,816.97 ' -4,764.83 325.96 ' 3.00 3.00 0.07 1.27 12,210466 91.43 235.15 5,857.70 5,802.00 -5,107.58 -166.28 ! 0.00 0.00 0.00 0.00 12,266191 91.99 235.13 5,856.02 5,800.32 ~ -5,139.72 -212.41 1.00 1.00 -0.04 -2.14 12,736.40 j 91.99 235.13 ~! 5,839.70 5,784.00 ~' -5,407.98 -597.37 ; 0.00 0.00 ~' 0.00 0.00 12,79525 ' 92.79 235.99' 51'837.24 5,781.54 ,,41.23 -5,14I -645.86 J ~ '2.00 ~ 1.36 '' I1L47 47.30 ~ ~I 12,87671 pI 92.79 235.99 3,833.28 5,777.58 ~ ~ -5,?~86.73 -713.32 I0.00 0.00 ~ 9.00 0.00 13,018 16 90.11 235.09 5,829.70 5,774.00 -5,51166.73 -829.89 2.00 -1.89 -0.64 -161.30 , 13,537.77 190.11 235.09 5828.70 5,773.00 -5,64.11 -1,256.00 0.00 0.00 ~, 00 0.00 ~, ~' ' l i ~ i 11/14/2007 10:14:28AM Page 3 of 8 COMPASS 2003.11 Build 48 ~~~~~AL ~ ~ Halliburton Company Compass Proposal Report -Geographic Database: .Sperry EDM .11 Local Co-ordinate Reference: Well 3S-08 Company: ConocoPhillips Alaska, Inc. TVD Reference: 3S-08C @ 55.70ft Project: K:uparuk River Unit MD Reference: 3S-08C @ 55.70ft Site: Kuparuk 3S Pad North Reference: True Well: 3S-08 Survey Calculation Method: Minimum Curvature Wellbore: Plan 3S-08C Design: 3S-OoC (wp05) Planned Survey 3S-OoC (vd p05) Map Map MD Incl Azimuth ND (ft) TVDSS +N/-S +E!-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft1 (ft) lft) lft) (ft) (°/100ft) (ft) 4,300.00 65.86 108.36 2,676.48 2620.78 -1,093.26 2,624.01 5,992,822.06 478,925.72 0.00 -1,082.41 KOP 3°/100' @ 4300' MD, 2677' TV D, TFO 60°: 1695' FSL, 1 665' FWL - Sec17-T12N-R08E 4,400.00 67.39 111.17 2,716.17 2660.47 -1,124.30 2,710.38 5,992,790.74 479,011.98 3.00 -1,121.52 4,500.00 63.74 112.98 2,757.53 2701.83 -1,158.50 2,794.73 5,992,756.29 479,096.22 4.00 -1,156.99 4,600.00 60.12 114.91 2,804.58 2748.88 -1,194.28 2,875.37 5,992,720.25 479,176.73 4.00 -1,188.70 4,700.00 56.53 116.99 2,857.08 2801.38 -1,231.49 2,951.89 5,992,682.80 479,253.12 4.00 -1,216.50 4,800.00 52.98 119.24 2,914.78 2859.08 -1,269.93 3,023.92 5,992,644.14 479,325.03 4.00 -1,240.25 4,900.00 49.47 121.71 2,977.40 2921.70 -1,309.43 3,091.11 5,992,604.43 479,392.09 4.00 -1,259.84 5,000.00 46.03 124.45 3,044.64 2988.94 -1,349.78 3,153.14 5,992,563.89 479,453.98 4.00 -1,275.17 5,100.00 42.65 127.53 3,116.16 3060.46 -1,390.79 3,209.70 5,992,522.70 479,510.41 4.00 -1,286.16 5,200.00 39.37 131.02 3,191.61 3135.91 -1,432.26 3,260.51 5,992,481.07 479,561.09 4.00 -1,292.77 5,300.00 36.21 135.03 3,270.64 3214.94 -1,473.99 3,305.34 5,992,439.20 479,605.77 4.00 -1,294.96 5,400.00 33.21 139.67 3,352.85 3297.15 -1,515.78 3,343.96 5,992,397.30 479,644.25 4.00 -1,292.72 5,500.00 30.40 145.08 3,437.84 3382.14 -1,557.42 3,376.18 5,992,355.56 479,676.34 4.00 -1,286.05 5,600.00 27.86 151.44 3,525.20 3469.50 -1,598.71 3,401.84 5,992,314.19 479,701.87 4.00 -1,275.00 5,700.00 25.66 158.87 3,614.51 3558.81 -1,639.45 3,420.83 5,992,273.40 479,720.72 4.00 -1,259.62 5,800.00 23.90 167.45 3,705.33 ~ 3649.63 -1,679.44 3,433.04 5,992,233.37 ~ 479,732.81 4.00 ~ -1,239.98 5,877.22 22.90 174.81 3,776.21 3720.51 -1,709.68 3,437.80 5,992,203.12 479,737.47 4.00 -1,221.96 5,900.00 22.90 174.81 3,797.19 3741.49 -1,718.51 3,438.60 5,992,194.29 479,738.24 0.00 -1,216.29 ! 6,000.00 22.90 174.81 3,889.31 3833.61 -1,757.27 3,442.12 5,992,155.52 479,741.64 0.00 -1,191.36 6,100.00 22.90 1 74.81 3,981.42 3925.72 -1,796.03 3,445.63 5,992,116.75 47 9 ,745.03 0.00 -1,166.44 ` 1 0 0 9 . ~ j $ 1' r 6,300.00 22.90 174.81 4,1 65.66 41 .96 0 -1,873.56 3,452 7 5,992,039.22 479.;75 .82 0.00 -1,11 6.60 6,400.00 22.90 174.81 4,257.77 4202.07 -1,912.32 3,456.19 5,992,000.45 479,755.21 0.00 -1,091.68 6,500.00 22.90 174.81 4,349.89 4294.19 -1,951.08 3,459.70 5,991,961.68 479,758.61 0.00 -1,066.76 I 0 9 9 I ' 6,700.00 22.90' 174.81 4,534.1 2 4478.42 -2,028.0 3466.74 4 5,991,884. 47 ,765.40 0.00 -1,015.92 I. 6,800.00 22.9 X74.81 4,626.23 4570.53 -2,067.36 3470.26 5,991,845.38 479;768.79 0.00 -992,00 6,900.00 22.90 174.81 4,718.35 ~ 4662.65 -2,106.12 3, 73.77 5,991,806.61 ~ 479,772.19 0.00 ~ -967.08 6,948.22 22.90 I 174.81 4,762.77 ', 4707.07 -2,124.81 3 p475.4T 5,991,787.91 i', 479,773.82 0.00 i ; -955.06 i. 7,000.00 23.88 179.42 4,810.29 ~ 4754,59 -2,145.33 3,476.49. 5,991,767.40 ' 479,774.77 4.00 -941.27 7 100.00 26.10' 187.30 4,900.95 4845'.25 -2,187.40 3'473.89 5,991,725.33 °' 479 772.05 4.00 ' 909,68 , ~~ 7,200.00 28.69 13.94 4,989.75 ~ 493~i.05 -2,232.54 3C465.3~1i 5,991,680.23 ~ 479`763.32 4.00 ~ -87170 7,300.00 31.55. 19.52 5,076.25 i 502055 -2,280.51 3',450.781 5,991,632.31 ~ 479,~Y48.64 4.00 I -827.0 7 400.00 34.61 204.24 160.05 5 510435 -2,331.09 3,430.37 5,991,581.80 479, 28.07 4.00 , -777.31 , 17,500.00 37.83 28.25 , 5,240.72 518502 -2,384.03 3,404.1 5,991,528.95 .479,01.71 4.00 -721.5 7,600.00 41.17 211.72 5,317.87 5262:17 -2,439.06 3',372.34 5,991,474.02 479,669.70 ~ 4.00 -659.92 ~ 7 700.00 44.60 214.75 391.14 5 ~~ 5335.44 -2,495.93 3;335.00 5,991,417.28 ~ 479,632.19 4.00 ! -593.31 , 7,800.00 48.14 217.43 , 5,460.16 ~ 5404.46 -2,554.36 ,292.35 5,991,359.00 I 479,589.36 4.00 ~ -521.84 7,900.00 51.66 219.83 5,524.59 5468.89 -2,614.05 3,244.59 5,991,299.46 479,541.42 4.00 -445.86 ~ ~ 8,000.00 55.26 222.00 5,584.13 ~ 5528:43 -2,674.72 3,191.96' 5,991,238.96 479;488.60 4.00 -365'74 ~ .' 8,100.00 58.89 223.99 5,638.48 ~',~ 5582.78 -2,736.08 3,134.71 5,991,177.79 ~'~ 479,431.17 4.00 ',~ -281.87 8,200.00 62.55 225.83 5,687.37 5631.67 -2,797.83 3,073.13 5,991,116.24 479,369.39 4.00 -194.67 .8,300.00 66.24 227.55 5,730.58 5674.88 -2,859.66 3,007.50 5,991,054.63 479,303.58 4.00 -104.55 8,400.00 69.94 229.18 5,767.88 5712.18 -2,921.27 2,938.16 5,990,993.25 479,234.05 4.00 -11.95 8,500.00 73.66 230.73 5,799.11 5743.41 -2,982.36 2,865.44 5,990,932.39 479,161.14 4.00 82.68 ~ 8,600.00 77.39 ~ 232.23 5,824.09 ~ 5768.39 -3,042.64 2,89.69 5,990,872.35 ~ 479,085.21 4.00 1178 ~86 8,700.00 81.13 233.68 5,842.72 5787.02 -3,101.81 2,711.28 5,990,813.44 479,006.62 4.00 276.15 11/14/2007 10:14:28AM Page 4 of 8 COMPASS 2003.11. Build 48 l~L Halliburton Company Compass Proposal Report -Geographic Database: Sperry EDM .11 Local Co-ordinate Reference: Well 3S-08 Company: ConocoPhillips Alaska, Inc. ND Reference: 3S-08C @ 55.70ft Project: K:uparuk River Unit MD Reference: 3S-08C @ 55.70ft Site: K:uparuk 3S Pad North Reference: True Well: 3S-08 Survey Calculation Method: 'Minimum Curvature Wellbore: Plan 3S-08C Design: 3S-08C (wp05) Planned Survey 3S-02C (vdp05) MD Incl Azimuth ND (ft) 7VDSS +N/-S +E!-W (ft) (°) 1') Iftl (ft) (n) 8,800.00 84.87 235.10 5,854.90 5799.20 -3,159.59 2,630.60 8,803.38 85.00 235.15 5,855.20 5799.50 -3,161.51 2,627.84 8,900.00 85.00 235.15 5,863.62 5807.92 -3,216.51 2,548.85 8,918.11 85.00 235.15 5,865.20 5809.50 -3,226.83 2,534.04 3S-08C C4-Top (10-31-07) 8,947.78 85.00 235.15 5,867.79 5812.09 -3,243.71 2,509.79 7" Csg @ 8948' MD, 5868' TVD: 43 9' FNL, 1544' FWL - Sec 20-T12N-R08 E - 7" 8,948.11 85.00 235.15 5,867.81 5812.11 -3,243.90 2,509.52 8,965.13 85.65 235.18 5,869.20 5813.50 -3,253.59 2,495.60 8,984.86 85.65 235.18 5,870.70 5815.00 -3,264.82 2,479.45 3S-08C MB_T4 (10-31 -07) 8,997.71 85.65 235.18 5,871.68 5815.98 -3,272.14 2,468.93 9,000.00 85.74 235.18 5,871.85. 5816.15 -3,273.45 .2,467.05 9,012.17 86.23 235.17 5,872.70 5817.00 -3,280.38 2,457.09 3S-08C MB Heel (10-31-07) - 3S-08C MB_T6 (1 0-31-07) 9,080.71 89.00 235.15 ~ 5,875.55 5819.85 ~ 3,319.50 2,400.89 9,100.00 89.00 235.15 5,875.89 5820.19 -3,330.52 2,385.06 9,200.00 89.00 235.15 5,877.63 5821.93 -3,387.65 2,303.00 9,300.00 ' 89.00 235.15 5,879.38 5823.68 -3,444.79 2,220.95 9,375.71 89.00 235.15 5,880.70 5825.00 -3,488.04 2,158.83 3S-08C M~~T7 (10-31 ~ -07) ~~. `t: 9,400.00 88.27 235.11 5,881.28 5825.58 -3,501.92 2,138.91 9,468.81 86.21 235.00 '~ 5,884.59 5828.89 - ,541.29 2,082.57 9,50000 ~ 86.21 235.00 5,886.65 5830.95 -~,559i14 2,057.08 9,52437 86.21 235.00 5,88.26 5832.56 ,573; 09 2,037.16 9,600 00 '~ 88.48 235.13 5,891.77 5836.07 ,616.35 1,975.23 9,67~~0 90.77 235.27 5,892.27 5836.57 '-3,660.06 1,912.34 9,70000 90.77 235.27 i 5,891.95 5836.25 ,3,673.39 1,893.11 9,800.00 ' 90.77 235.27 5,890.61 5834.91 -3,730.36 1,810.93 9,900 00 `~ ~ 90.77 235.27 ' 5,8 99.27 5833.57 ,787:33 1,728.75 ,` ~ 0 ~~ ~ 7 I~ ~ 10,01 6.60 90.77 235.27 5,87. 0 5832.00 ,853 5 1,632.93 3S-08C MB~T3 (10-31-07) i . 10,100.00 93.26 235.07 5,884.76 5829.06 -3,901 1,564.52 10,151,.96 94.82 234.95 ', 5,881.10 5825.40 '-3,931.06 1,522.06 10,20b.00 94.82 234.95 ~ 5,877.07 5821.37 x3,958.55 1,482.87 10,202.78 94.82 234.95 5,876.83 5821.13 -3,960.14 1,480.60 10,300.00 i 91.91 235.10 5,871.13 5815.43 =4,015.77 1,401.08 10,341.56 90.66 235.16 '•, 5,870.20 5814.50 =4,039.52 1,366.99 10,400.00' 90.66 235.16 5,869.53 5813.83 -4,072.91 1,319.03 10,500.00' .90.66 235.16 5,868.38 5812.68 -4,130.03 1,236.96 10,600.00 90.66 235.16 5,867.23 5811.53 -4,187.16 1,154.89 10,700.00 90.66 235.16 5,866.07 5810.37 -4,244.28 1,072.82 10,800.P0 ' 90.66 235.16 . ~ 5,86.4.92 5809.22 -,301.41 990.75 10,900.00 90.66 235.16 5,863.77 5808.07 -4,358.53 908.68 Map Map Northing Easting DLSEV Vert Section {ft) (ft) ('1100ft) (ft) 5,990,755.92 478,925.76 4.00 374.05 5,990,754.01 478,923.00 4.00 377.36 5,990,699.26 478,843.84 0.00 472.11 5,990,689.00 478,829.00 0.00 489.87 5,990,672.19 478,804.70 0.00 518.96 5,990,672.00 478,804.42 0.00 519.29 5,990,662.36 478,790.47 3.80 535.98 5,990,651.18 478,774.29 0.00 555.35 5,990,643.90 478,763.75 0.00 567.96 5,990,642.60. 478,761.87 3.94. 570.21 5,990,635.70 478,751.88 4.05 582.16 5,990,596.76 478,695.56 4.04 649.56 5,990,585.79 478,679.70 0.00 668.54 5,990,528.92 478,597.48 0.00 766.96 5,990,472.05 478,515.25 0.00 865.38 5,990,429.00 478,453.00 0.00 939.89 ~; ~~~ ~~~ 5,990,415.18 478,433.03 3.00 963.80 5,990,376.00 478,376.58' 3.00 1,031.47 5, 90,358.23 478,351.04 !0.00 1,062.12 ~ 5, 90,34.4.35 478,331.08 ,0.00 1,086.06 , 5, 90,301.28 478,269.01 3.00 1,160.45 0,257.78 5, 478,205.99' 3.00 1,235.83 r 5,990,244.51 478,186.72 i 0.00 1,258.85 i 5,990,187.81 478,104.37 0.00 1,357.24 5, 90,13'.11 478,022.02 0.00 1,455.63 II 5,90,07 .41 6 477,939.67 ~ 00 ~ 1,554.02 ~ I .00 5,990,0 477,926.00 .00 1,570.35 5,990,017.62 477,857.44 • ~'.00 1,652.38 5,989,988.04 477,814.89', 3.00 1,703.42 ' I 5,989,960.68 477,775.62) 0.00 1,750.57 ~ 5,989,959.10 477,773.35 0.00 1,753.30 5,989,903.73 477,693.66' 3.00 1,848.86 ' 5,989,880.09 477,659.50', 3.00 1,889.76 ', 5,989,846.86 477,611.44 0.00 1,947.28 5,989,790.00 477,529.19 0.00 2,045.71 5,989,733.14 477,446.95 0.00 2,144.13 5,989,676.28 477,364.71 0.00 2,242.56 5,99,619.42 477,282.47 , I 0.00 2,340.99 I 5,989,562.56 477,200.23 0.00 2,439.41 11/14/2007 10:14:28AM Page 5 of 8 COMPASS 2003.11 Build 48 ORIGINAL Halliburton Company Compass Proposal Report -Geographic Database: .Sperry EDM .11 Local Co-ordinate Reference: :Well 3S-08 Company: ConocoPhillips Alaska, Inc. TVD Reference: 3S-08C @ 55.70ft Project: Kuparuk River Unit MD Reference: 3S-08C @ 55.70ft Site: Kuparuk 3S Pad North Reference: True Well: 3S-08 Survey Calculation Method: Minimum Curvature Wellbore: Plan 3S-08C Design: 3S-02C (wp05) Planned Survey 3S-08C (wp05) Map Map MD Incl Azimuth TVD (ft) TVDSS +Nl-S +EI-W Northing Easting DLSEV Vert Section (ftl (') (°) (ftl (ft) (ft) lft) (ft) (°I100ft) (ft) 11,000.00 90.66 235.16 5,862.62 5806.92 -4,415.66 826.61 5,989,505.70 477,117.98 0.00 2,537.84 11,100.00 90.66 235.16 5,861.47 5805.77 -4,472.78 744.54 5,989,448.85 477,035.74 0.00 2,636.26 11,166.56 90.66 235.16 5,860.70 5805.00 -4,510.80 689.92 5,989,411.00 476,981.00 0.00 2,701.77 3S-08C MB_T5 (10-3 1-OT) 11,200.00 89.66 235.13 5,860.61 5804.91 -4,529.91 662.48 5,989,391.98 476,953.50 3.00 2,734.69 11,271.94 87.50 235.06 5,862.39 5806.69 -4,571.06 603.50 5,989,351.02 476,894.40 3.00 2,805.49 11,300.00 87.50 235.06 5,863.62 5807.92 -4,587.12 580.52 5,989,335.04 476,871.37 0.00 2,833.09 11,400.00 87.50 235.06 5,867.98 5812.28 -4,644.33 498.62 5,989,278.09 476,789.30 0.00 2,931.46 11,479.63 87.50 235.06 5,871.45 5815.75 -4,689.89 433.40 5,989,232.74 476,723.94 0.00 3,009.79 11,500.00 88.11 235.08 5,872.23 5816.53 -4,701.55 416.72 5,989,221.14 476,707.22 2.99 3,029.83 11,600.00 91.11 235.14 5,872.91 5817.21 -4,758.74 334.70 5,989,164.22 476,625.04 3.00 3,128.27 11,610.66 91.43 235.15 5,872.67 5816.97 -4,764.83 325.96 5,989,158.16 476,616.27 3.01 3,138.76 11,700.00 91.43 235.15 5,870.44 5814.74 -4,815.87 252.66 5,989,107.36 476,542.82 0.00 3,226.67 11,800.00 91.43 235.15 5,867.95 5812.25 -4,872.99 170.62 5,989,050.50 476,460.61 0.00 3,325.08 11,900.00 91.43 235.15 5,865.45 5809.75 -4,930.12 88.58 5,988,993.64 476,378.40 0.00 3,423.48 12,000.00 91.43 235.15 5,862.96 5807.26 -4,987.24 6.54 5,988,936.78 476,296.19 0.00 3,521.88 12,100.00 91.43 235.15 5,860.46 ~ 5804.76 -5,044.37 -75.50 5,988,879.92 ~ 476,213.98 0.00 ~ 3,620.29 12,200.00 91.43 235.15 5,857.97 5802.27 -5,101.49 157.53 5,988,823.06 476,131.76 0.00 3,718.69 12,210.66 91.43 235.15 5,857.70 5802.00 -5,107.58 -166.28 5,988,817.00 476,123.00 0.00 3,729.18 3S-08C MB_T7 (10-3 1-07)~ i ; j .12,266.91 91.99 235.13 5,856.02 5800.32 -5,139.72 -212.41 5,988,785.01 476,076.77 1.00 3,784.53 12,300.00 91.99 X35.13 5,854.87 579.17 -5,158.62 -239.5 5,988,766.19 47,049.58 0.00 3,87.08 + 12,400.00 91.99 235.13 5,851.39 5795.69 -5,215.76 -321.54 5,988,709.32 475,967.41 0.00 5.47 3,91 ~ 12,500.00 91.99 235.13 5,847.92 5792.22 -5,272.90 -403.54 5,988,652.45 475;885.24 0.00 4,013.85 12 600.00 91.99 235.13 5,844.44 ~' 5788.74 -5,330.04 X485.53 5,988,595.57 ~ 475,803.08 0.00 ~ 4,112.23 , ~, 12,700.00 91.99 235.13 5,840.97 5785.27 -5,387.18 ~ 67.53 5,988,538.70 ~ 475,720.91 0.00 14,210.61 12,736.40 91.9 235.13 5,839.70 5784.00 -5,407.98 97.37 5,988,518.00 475,691.00 0.00 4,246.42 3S-08C MB T8 (10, 1-07) , 12,795.25 92.79' 235.99 5,837.24 i' 5781:54 -5,441.23 -645.86' 5,988,484.91 ~' 475,642.41 2.00 i 4,304'.22 12,800.00 92.79 235.99 5,837.01 ~ 5781.31 -5,443.88 X649.80 5,988,482.27 475,638.47 0.00 ~ 4,308.88 12,876.71 92.7 ~ 25.99 5,833.28 t 5777.58 -5,486.73 713.32 5,988,439.62 475;574.82 0.00 ~ 4,384.10 ~~ 12,900.00 92.3 ~~5.85 5,832.24 I 577.54 -5,499.77 ~732.5~ 5,988,426.65 ~ 475<,~555.51 2.00 4,40.94 13,000.00 90.46 235.20 5,829.79 I 5774.09 -5,556.35 -814.99' 5,988,370.33 475,472.93 2.00 ~ 4,50 .22 13,018.16 90.11 235.09 5,829.70 577 .00 ~ -5,566.73 -829.89 ~ 5,988,360.00 475,458.00 2.01 ~ 4,52 .10 ~ 3S-08C MB_T9 (10-31-07)~ ~ ~~ ; 13,100.00 90.11. 235.09 5,829.54 '~ 5773.84 -5,613.57 '-897.01 5,988,313.38 ', 475,390.75 0.00 '~ 4,603.67 ' 13,200.00 90.1) 235.09 5,829.35 i 5773.65 -5,670.80 'c979.01' 5,988,256.41 l 475,308.57 0.00 j 4,702.13 13,300.00 90.11 235.09 5,829.16 5773.46 -5,728.03 -1,061.01 5,988,199.45 475,226.39 0.00 4,800.58 1,13,400.00 90.11 235.09 5,828.97 5773.27 -5,785.26 -1,143.02 5,988,142.48 475144.22 0.00 4,89,9.03 13,500.00 90.11 235.09 5,828.77 ~ 5773.07 ~ -5,842.49 -1,225.02 5,988,085.52 ~. ~ 475,062.04 0.00 ', 4,997.49 13,537.43 90.11 235.09 5,828.70 5773.00 -5,863.92 -1,255.71 5,988,064.20 475,031.28 0.00 5,034.34 4112" 13,537.77 90.11 235.09 5,828.70 5773.00 -5,864.11 -1,256.00 5,988,064.00 475,031.00 0.00 5,034.68 BHL ~ 13538' MD, 1829' TVD: 2204' FSL, 2232'IFEL ? Sec19-T12N-R08E - 3S-08C, MB_Toe (10-31-07) 11/14/2007 10:14:28AM Page 6 of 8 {~~ I t I I 1 COMPASS 2003.11 Build 48 ~~ Halliburton Company Compass Proposal Report -Geographic Database: .Sperry EDM .11 Local Co-ordinate Reference: 'Well 3S-08 Company: ConocoPhillips Alaska, Inc. TVD Reference: 3S-08C @ 55.70ft Project: Kuparuk River Unit MD Reference: 3S-08C @ 55.70ft Site: Kuparuk 3S Pad North Reference: True Well: ~~-08 Survey Calculation Method: Minimum Curvature Wellbore: Plan 3S-08C Design: S-08C (wp05) Geologic Targets Plan 3S-08C TVD TVDSS Target Namo +N/-S +E!-W Northing Eastiny (ft) (ft) - Shapo ft ft (ft) (ft) 5,865.20 3S-OSC C4-Top (10-31-07) -3,226.83 2,534.04 5,990,689.00 478,829.00 - Point 5,829.70 3S-08C MB_T9 (10-31-07) -5,566.73 -829.89 5,988,360.00 475,458.00 - Polygon Point 1 0.00 0.00 5,988,360.00 475,458.00 Point 2 -297.38 -426.10 5,988,064.00 475,031.00 5,887.70 3S-08C MB_T3 (10-31-07) -3,853.75 1,632.93 5,990,065.00 477,926.00 - Point 5,892.70 3S-08C MB_T2 (10-31-07) -3,642.76 1,937.30 5,990,275.00 478,231.00 - Polygon Point 1 0.00 0.00 5,990,275.00. 478,231.00 Point 2 -210.99 -304.36 5,990,065.00 477,926.00 5,857.70 3S-08C MB_T7 (10-31-07) -5,107.58 -166.28 5,988,817.00 476,123.00 - Polygon Point 1 0.00 0.00 5,988,817.00 476,123.00 , Point 2 -300.40 -431.09 5,988,5.18.00 475,691.00 , 5,860.70 3S-08C MB_T5 (10-31-07) -4,510.80 689.92 5,989,411.00 476,981.00 -Point ' ~ ' 5,870.70 ~ ~ 3S-08C MB_T4 (10-31-07j -4,015.50 1;401.42 5,989,904.00 ~ 477,694.00 - Polygon ` point 1 (, `, 0.00 `,+ 0.00 5,989,904.001~ 477,694.00 (,~ Point 2 ~I -495.31 -711.50 5,989,411.00' 476,981.00 5,872.70 ' 3S-O8C MB_T6 (10~31-07) -4,764.99 325.69 5,989,158.00 476,616.00 - Potygon I, I I, I, I, ' I, i. Point ' 0.00 0.00 5,989,1 8.00 , 476,616.00 , + Point ~ -342.60 -491.97 5,988,8 7.00 ~~ 476,123.00 5,82.70 ~ 3S-08C MB_Toe (10 , 1-07) -5,864.11 -1,256.00 5,988,0 4.00 ' , 475,031.00 ~ , -Point ~ i~ ~ ~ ~ ~ . Q.t 0 I~ 5,P + ~ 3S-08C MB_T1 (1031-07 ~ -3,488.04 ~ 2,158.83 5,990,49.00 ~~ 478,453.00 ~; I; o ~ ~ 0 5 3S-08C MB_T8 (10-31-07~ -5,407.98 -197.37 5,988,51,8.00 ~ 475,691.00 Po nt l I ' 5,872.70 I 3S-08C MB_Heel (10-31-07). -3,226.83 ~ 2,534.04 5,990,689.00 I 478,829.00 + - Polygon ~ I ~ I ~ I I I Point 1 0.00 0.00 5,990,689.00 478,829.00 Point 2 ~ -261.22 ~ -375.21 5,990,429.00 478,453.00 11/14/2007 10:14:28AMPage 7 of 8 COMPASS 2003.11 Build 48 Halliburton Company Compass Proposal Report -Geographic Database' .Sperry EDM .11 Local Co-ordinate Reference: Well 3S-08 Company: ConocoPhillips Alaska, Inc. TVD Reference: 3S-08C @ 55.70ft Project Kuparuk River Unit MD Reference: 3S-08C @ 55.70ft Site: K:uparuk 3S Pad North Reference: `True Well: 3S-08 Survey Calculation Method: Minimum Curvature Wellbore: Plan 3S-08C Design: 3S-08C (wp05) Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter Ift) (ft1 ('7 (") 4,263.07 2,661.40 9-5/8 12-1/4 8,947.78 5,867.79 7 8-112 13,537.43 5,828.70 4-112 6-314 Plan Annotations Measured Vertical Local Coor dinates Depth Depth +N/-S +E/-W Comment (ft) (ft) (ft) (ft) 4,300.00 2,676.48 -1,093.26 2,624.01 KOP 3°/100' @ 4300' MD, 2677' TVD, TFO 60°: 1695' FSL, 1665' FWL -Sect 8,947.78 5,867.79 -3,243.71 2,509.79 7" Csg @ 8948' MD, 5868' TVD: 439' FNL, 1544' FWL - Sec20-T12N-R08E 13,537.77 5,828.70 -5,864.11 -1,255.99 BHL @ 13538' MD, 5829' TVD: 2204' FSL, 2232' FEL - Sec19-T12N-R08E ~ ~ I . i ~ i i I ~ I, I, ~, (, ~ I,. 1, 1.. I.. L li f ,, , r i I i ~ ~ ~ I I. I. ~i, I, .. f 1 I 7 I y. i ~. i ~ I I I ~ I Ifr 1 1 1 1 ,, I ,, , 11/14/2007 10:14:28AM Page 8 of 8 COMPASS 2003.11 Build 48 i ! ~a~ ConocoPhillips Plan: 3S-08C (wp05) Sperry Drilling Services Anticollision Summary 14 November, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit ,Kuparuk 3S Pad ' ~ 3S-08 ' Plan 3S-08C' i, I: I,: i,, I,: ~,: ~ I ~ I ~ 1 1 Ir l , , ~ ~ ~~' ~, ~ ~ ~ ~~ I~ I. ' ~, ~ I~ ~ 41 ~1 ~ ~I l i Local Coordinate Origin: ~ ~ Centered on Well 3S-08 I, T1VDs to System: I ! 3S-08C @ 55.70N I II North Reference: ~ ` True ~~ Unit System: ~' ~~ API - US Survey Feet's ~~ ~, ~ '', HLL[BURTON ® I Bp®rry drilling Servfc~s ~~~~~ i i I ~ I ~ -- - SURVEY PROGRAl11 "- - - - Date: 2 007-1 1-1 4700:00:00 Validated: Yes Version: Depth From Depth To Survey/131an Tool 86.40 SG.40 CB-GYRaSS 195.09 4300.00 NiW'D+IFR-AK-CAZrSC 4300A0 1353Z4d 3S-OSC (wp05) MWD+IFR-AK-CA~SC r_ _-~ 3~~ ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 50Statlons Depth Range From: 4300 To 13537.7734556752 Maximum Range:693.350347729304 Reference: Plan: 3S-08C (wp05) 0 3S 3S-OS 2~0 270 From Colour To MD I 0 4250 4250 4500 4500 5000 5000 6000 6000 14000 180 Travelling Cylinder Azimuth (TFO+ALI) ~°) vs Centre to Centre Separation i30 ftlin( 180 Travelling Cylinder Azimuth (TFO+AZI) (°J vs Centre to Centre Separation X200 ft/inJ NAD 27 ASP Zone 4 : WELL DETAILS: 3508 Ground Level: 27.70 +N/-S +EI-W Northing Easting Latittude Longitude Slot - 0.00 0.00 _ -5993923.52 - - 476305.45 70~1'40.307N,.1504i1'34.033W _ REFERENCEINFQRMATION -.- - - -- ___ Co-ordinate (NIE) Reference: Well 3508, True NoRh Vertical (TVD) Reference: 3508C ~ 55.70tt Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: 3SOSC ~ 55.70ft Calculation Method: Minimum Curvature - COMPANY DETAILS: ConocoPhillips Alaska, Inc. Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based 90 SECTION pETRILS s44 M° iM na Tv° «ws .FJ-w ap TFac4 vs« r.te.l 4b0.W 65.% 108.36 26]6.48-1 W3.26 2614.01 O.W O.W -108241 2 44W.W 6].]9 111.1] 2]16.1]-1124.]0 2110.38 3.W eO.W -1121.52 3 56]].22 22.% 1]4.81 3P6.21 -1709.88 ]4]].80 O.W 156.02-1221.% 4 6949.22 22.% 1]4.81 4]62.]7 -2124.81 34]S.d] O.W O.W -955.06 5 BBW.38 %.W 2]5.15 5855.20 3161.51 262].84 d.W 64.10 37].36 991A.11 6 0 23~ 15 5865.20 -3226.83 2534 04 0 W 489.8] 35-Otll: l4-iap 110.31-Oil ] 8948.11 %.W 2]5.15 586].81 3243.% 2508.52 O.W O.W 519.29 6 8%5.13 85.65 235.18 5869.20 3253.59 24%.W 4.W 2.42 535.% 9 899].]1 %.fi5 235.18 56]1.68 3212.td 24%.9] O.W 0.00 56].% 10 9080.71 B9.W 235.15 59]5.553319.50 24W.B9 4.W -0.4] 649.56 11 9J]571 89.W 1]5.15 5 -O-J4A6.04 2158.83 O.W OW 939.89 3SOBC MB TI (10.31 ~.i'. 12 9468.81 98]1 2]S.W 5884.59 3541.29 2082.5] ].00 -1]6.8] 1031.47 13 %24.3] %.21 335.W 5888.2fi 35]].09 20J].16 0.00 O.W 10%.% 14 %T9.fi0 %.]] 2]5.27 5691.2] 36W.W 1912.N 3.00 ].43 1235.83 15 1W16.60 90.1] 1352] 586]]0-3853]5 i6J293 U.W O.W 15/435 JS.OBC M617110.31-:~:, 16 10151.% 91.82 231.95 5861.10 3931.% 1522.% 3.W 4A] 1]WA2 1] 192o2.7e 91.e2 234.% Sn]fi.e] 3%0.14 1680.W 9.W o.W 1]5].]0 18 10341.56 %.% 235.16 5670.20-0039.52 1388.% 3.W 1]].14 1889.]6 19 1166.56 90.66 2]51fi 566070451460 O.W 1]Ot.]i 35-08C MB TS (1P31 ~: ~, 20 112]1.94 8].50 235.08 5862.39 45]1.% W3.50 3.W -1]8.24 2805.49 2t 114T9.6J 9].50 335.% 5871.454889.89 433.40 O.W O.W 3W9.]9 22 11610.66 91.43 235.15 59]2.6) 4]64.83 J25.% 3.00 1.2] 3138.]6 10 66 91 J3 1 5851.)0 5101 SA -166 28 4W 3728 18 35-0AG MB P (10.31 -0', 24 122%.91 91.99 235.13 5858.02 5139.72 -212.41 1.00 -2.14 3]84.5] "' " 23'].13 5639.]0 .540'98 -59]37 O.W O.W 4146.41 J..-OBC M010 (10.31-i]. 26 12]%.25 92.]9 235.99 583].24 E44t.2] 4]45.86 2.00 1].W 430422 2] 128]6.71 92.]9 135.98 583].28 -5486.)] -]13J2 0.00 O.W 4364.10 09 9+9 "'989 1.W -1 130 45~3.t0 350P 6 T911P3'-:" _ -.~ YJ 3509 5A3A. 5854.1 - ~S6.W O.W 60.W 5034,68 SSOB MB T 4110.'!'-]:~ s • Halliburton Company Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 11/14/2007 Time 11:34:54 Page: 1 Field: Kuparuk River Unit Reference Site: Kuparuk 3S Pad Co-ordinate(NE) Reference: Well. 3S-08, True North Reference R'ell: 3S-08 Vertical (TVD) Reference: 3S-08C: D141 (27.7+28) 55.7 Reference 1i'ellpath: Plan 3S-O8C Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: 3S-08C (wp05) & NOT PLANNED f Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.00 to 13537.80 ft Scan Method: Trav Cylinder North Maximum Radius: 1550.98 ft Error Surface: Ellipse + Casing Casing Points ~ ~ MD 'FVD Diameter Hole Size Aame i n ft ft in 4263.07 2661.40 9.625 12.250 9 5/8" 8947.78 5867.78 7.000 8.500 7" 13537.79 5828.70 4.500 6.750 4 1 /2" Plan: 3S-08C (wp05) Date Composed: 9/17/2007 Version: 5 Principal: Yes Tied-to: From: Definitive Path Summary __ _ _ <-------_-_-_-_-_- Offset V1'cllpath -------------------> Reference Offset Ctr-Ctr \o-Go Allowable Site ~i'ell N'cllpath h1D ~4D Distance Area Deviation ~'1'arning ft ft ft ft ft _-- Kuparuk 3S Pad 3S-08 3S-08 V5 4324.40 4325.00 0.26 38.82 -38.56 FAIL: Minor 1/200 Kuparuk 3S Pad 3S-08 3S-O8A V3 4299.40 4300.00 0.23 18.10 -17.88 FAIL: Minor 1/200 Kuparuk 3S Pad 3S-O8 3S-086 V4 4299.40 4300.00 0.23 18.10 -17.88 FAIL: Minor 1/200 ~~: f: ': ~i ~ I, I, I; 4i ~ ~~ ~ ~~ I~ ~~ 1~ ~ ~ ~ i `; ~i I, ~ f~ I~ ~ , ~: 1 I, ~ 4~ !~ ~~ ~I ', ~ I GRAM ORIGINAL N a0 N N ~ (n~~ V 00 N N ~ _ ~ Z rn i~ v J_ Q N ~ r N Lll ~ ~ ~ ~ ~ ~ W () N ~ Z N U QOVao°r ~~ti~ ~~~ N ~A ~ ~ ~ ~ M OO 1~ N ~~ V c0 O r N M Z 'c ~~ As a,a ~ rNi c 3 v Y Y 10 ep~~~ :n YYr~iarNi s .. Vii- ci c a ~''~~aa ~a` 3 ~ Z ~ ~~ ® ~ , \ L ~ ~ AO M C {Y ° c ~ ~ V =~ • • o / _..... ~ Q 0 u O ~ ~ ~ ~ _ m ~ v ~ ~ ~ ~ ~ ~~ //^^O~ ~ V) ORIGIN 0 0 0 rn d C_0 N N i11 r u~ d~ n e} m- O`0 N lC~- ~ Z O) n V' J Q y O ~ M f- y h r h W D ~ N n ~ ~c°o o~ Z N ~ Q ~ao~0~ U ~~r~a0 t0 t0 N yl 40 ~ N ~A 1A O ~- f~ MOO i~ lO~M ao°o~ Q r N M Z '~ N N ~ ~d ( w N V C. C 3 p p~~ NN lJ~ O Imo ~or>n N M N O Y Y ~ ~ pNj V CC. c,cg > 7N Ay YYr>ath '_ I~mYaa N~¢¢ .o rnrn ~ F'i::-y ~ ~ `~3~a o .c~ '~ Zw - n m ~ ~ ~ q ~ V •~a ~ ~ ~~ v ~ ~ C m ~ O 0 Q o V I n l~!/ll OOSL) (+)4NoN/(-)43noS 0 0 ti 0 0 0 O O V C_ O O r O "' o + M y N W w d 3 o ~. o I O ~~ o ~ O r 0 0 0 M L 3S-08C Drilling Hazards Summary 8-1/2" Hole Event Risk Level Miti anon Strate Shale stability in HRZ, K-1, Low Control with higher MW and proper drilling and Miluveach ractices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on tri s as a last resort. Barite Sa Low Good drillin ractices as documented in well Ian. Differential Sticking Moderate Periodic wiper trips. Do not leave pipe static for extended eriod of time. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increased mud weight as needed. Ensure adequate kick tolerance rior to drillin a interval. Lost Circulation Moderate Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 6-1/8" Hole Event Risk Level Miti anon Strate High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling pay interval. Pump and rotate out on tri s as a last resort. Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools,' Increased mud weight as needed. Monitor PVT e ui ment. Kee hole full ~ Differential Sticking Moderate Periodic wiper trips. Do not leave pipe static for extended period of time. Stop losses with LC ~ 'i decision tree. !j I Lost Circulation Moderate k Use PWD to mong r~hole cpleaning. Use ~ '~ decision tree desi n d for roduction later Is. '~, Well Control Moderate Close observations of flow checks while making ~ con',nections and before tr'i in will be erformed. Siderite Nodules causing high ~ Moderate ~ Near bit inclination vi~ill b~ first indicator thal~ a dqg doglegs ~; I leg'problem has developed. Watch for hard drilling .and kee deflection low in hi h siderite areas. l I 1. !, I, l I I i 1 i i i ~ j ~ j I j I j ~i 3S-08C Drilling Hazards Summary.doc Page 1 of 1 3S-08C wp(05) ~ Proposed Completion Schematic 3-1/2" Completion String ConocoPhillips Circulate corrosion inhibitor up to bottom GLM before landing tubing hanger. 3 'h" FMC Gen V tbg hanger, 3 'h" 9.2# L-80 EUE 8rd mod Spaceout Pups as Required, SPECIAL DRIFT 2.91" 3 'h" 9.2# L-80 EUE 8rd mod Tubing to Surface, SPECIAL DRIFT 2.91" 16" 62.5# H-40 Conductor +/-108' MDlND 3 ''/z" Camco'DS' nipple w/ 2.875" No-Go Profile. 3 ''/2" x 6' L-80 EUE 8rd mod handling pups installed above and below, set at +/- 500' MD Completion, from hanger to `DS' nipple, to be be drifted to 2.91". Station # Depth (MD) Depth (TVD) GLM 1 4611 2820 GLM2 5793 3700 GLM3 6662 4500 GLM4 7375 5138 GLMS 8136 5638 (4) 3 '/2" x 1-1/2" Camco'MMG' mandrels with dummv valves 3 'h" x 6', L-80 EUE 8rd mod handling pups installed above and below. Surface csg. 9-5/8" 40# L-80 BTC +/- 4263' MD/ 2662' TVD (1) Deepest 3 '/z" x 1-1/2" Camco'MMG' mandrel w/ shear valve, pinned for 2000 psi shear (casing to tubing differential). (2 joints) 3 '/2" 9.2# L-80 EUE 8rd mod Tubing (Space out na no greater than 70 degree inclination) 3 'h" Camco'DS' nipple w/ 2.813" No-Go `profile. 3 '/z" x 6' L-80 EUE 8RD Mod pup ' installed above and below i I ~; 8'/z" hole size: Intermediate csg 7" 26.0# L-80 BTCM +/- 8948' MD / 5868' TVD Top Kuparuk C sand +/- 8918' MD / 5865' TVD BHP = 2460 - 2700 PSI 5828' TVD 0 0 0 0 8.1 - 8.9 Pp9 EMW 0 0 0 0 6-1/8" hole size: ° 4-1/2" 12.8# L-80 IBTM Pre-Perfed Pups ° With 4-'/~' 12.6# L-80 IBTM Blank Tubing (1 ea. 5 ft perforated pup per 7 joints / 6, '/z" holes per pup) +/- 13,538' MD / 5829' TVD 'II i 4 Baker 80-40 GBH-22 Locator Sub w/ 3-1/2"+EUE box ,Length = 1.00' Baker seal assembly w/ 15' stroke and 1/2 mule shoe ,Length = 17.00' BOT HR Liner Running tool w/ rotating dog sub'nd HydraulicPush''r Tool ~ I HR ZXP w/ HD liner Top Packer w/ 10' Tie Back Extension ID 5.250 ~5" TKC coupling ~ ~~ RS Nipple 5" BTC pin x pin , 5" TKC coupling . Flex Lock Liner Hanger 5" BTC pin x pin 5" TKC coupling 80-40 Seal Bore Extension 5" BTC pin x pin 20' 5" TKC coupling Cross-over sub 5" BTC pin x 4-1/2" IBTM (With Torque Ring) Pup jt. 4-1/2" 12.6# L-80 IBTM (With Torque Rings) 4-1/2" 12.6# L-80 IBTM Perfed Pups and flank Liner (With Torque ° Rings) °° ° Silver Bullet Shoe 4-1/2" 12.6# L-80 IBTM (Torque Ring or Baker O o 0 0 0 0 0 0 ° 0 0 0 11 /8/2007 ,< _ JAB Schlumberger CemCADE Preliminary Job Design 7" Intermediate Casin Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Nordic 3 Location: Tarn Client: ConocoPhillips Alaska, Inc. Revision Date: 11/8/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com Previous Csg. < 9 5/8", 36.0# casing at 4,263' MD i, < Top of Tail at 7,948' MD i. t < 7~', 26.0# casing ~' it 8 1/2" OH I' I' TD at 8,948' MD (5,868' TVD) Volume Calculations and Cement Systems Volumes are based on 50% excess. Tail slurry is designed for 1000' MD above the intermediate casing shoe. Maximum ECDs during cement job are expected to be 12.45 ppg. Tail Slurry Minimum thickening time: 200 min. (Pump time plus 120 min.) GasBLOK w/ Class G + 2 gps D600G + 0.1% B155 + 0.2 gps D047 + 0.35% D065 @ 15.8 ppg - 1.17 ft3/sk 0.1268 ft3lft x 1000' x 1.50 (50% excess) = 190.2 ft3 0.2148 ft3/ft x 80' (Shoe Joint) = 17.2ft3 17.2 ft3 + 190.2 ft3 = 207.4 ft3 207.4 ft3/ 1.17 ft3/sk = 177.3 sks Round up to 180 sks BHST = 128, Estimated BHCT = 82~. (BHST calculated using a gradient of 2.2/100 ft. below the permafrost) PUMP SCHEDULE ' Pump Stage Stage Cumulative ' - _ ~ i_~..~. T:.v .. T:...... i Stage ~bpm) (bbl) v (min) (min) ~~ Comments Drop Bottom Plug 10.0 10.0 5 25 5.0 15.0 MudPUSH ill / tart Pumping Spacer ~ 3 21.3 i ~ Tail Slur~Y ~ 6 38 ' 6. ix and Pump Tail Slur ' ' Drop Top Plug ~- 5.0 26.3 Displacemd~t 5 339 ' 6 67.8 99.1 tart Displacement ' ~, 'MUD REMOV~-L ~~ ~ f~ I I ~ I ~ 4i i Recommended Mud Properties: 10.3 ppg, Pv < 15, TY < 22. As thin and light as possible ( (to aid in mud removal during cementing. ~ , Spacer Properties: 13.0 ppg MudPUSH", II, Pv - 19-22, TY = 22-29 Centralizers: Recommend 2 per joint across zones of interest for proper cement ~' placement. ,. , ' ~~ l 0!31GINAL • ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Brink, Jason A [Jason.Brink@conocophittips.comj Sent: Thursday, November 29, 2007 2:22 PM To: Maunder, Thomas E (DOA) Cc: Thomas, Randy L Subject: RE: H2S on 3S Pad Attachments: GtCA H2S State Report 2007-11.x1s Tom At the bottom of the CPF-3 tab you will find the drillsite 3S wells including H2S levels. Let me know if you need more information. w c~\ 1 45~ Q rQ,~ ~~rly'- Jason Brink 1 i Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska, Inc. Office :907-265-6419 Cell :907-748-4826 Fax :907-265-1.535 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, November 29, 2007 12:45 PM To: Brink, Jason A Cc: Thomas] Randy L Subject: H2S on 3S Pad Jason, I am reviewing the application for 3S-08C. I don't find any information regarding H2S on DS 3S. Coutd you provide information regarding H2S levels in the wells at 3S? I need this to complete my review. Thanks in advance. Tom Maunder, PE AOGCC 11 /29/2007 6050000 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 800000 Alaska Department of Natural Resources Land Administration System Page 1 of 3 • _ ~;~:;. - =:r ~_ , .~~ r,.~ . ; ~ .:~: ~ ~~r~~r's Search Sta#e Cabins ~t~i1'~~ ~ 3~~.1CC9es . Alaska DIVR Case 5umma-~ File Type: ADL _ ~ File Number: 380107 ~ Printable Case File_Summ.a..ry See Township, Range, Section and Acreage? C Yes ~ No New Search l_A8 ~Aenu I Case Abstract I Case Detail I Land Abstract File: ADL 3811107 `"~'r~' ~ Search fior Status Plat Updates :1 of I I;'~6%x'007 C'ustorner: OOOlOG3 !6 CONOCOPHILLIPS ALASKA, INC. ATTENTION: LAND MANAGER PO BOX 100360 ANCHORAGE AK 995100360 Case Type: ~~~_ OIL & GAS LEASE COMP DNR Urzit.~ 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 01/29/1993. Total Acres: 2448.000 Date Initiated: 08/25/1992 Office ofPrirnaiyReshonsibilih~: DOG DIV OIL AND GAS Last Transaetiorz Date: 12/0712005 Case Subtype: S NORTH SLOPE 1 ast Trunsactron: DR DOCUMENT RECORDED ILlef•Idian.~ U Totivnship: 012N Range: 008E Section: 17 ~.~`ection .~1c~res: 640 Se~~rch Plats Meridian: U 7~n,~nship: 012N Range: 008 F. Section: 18 S'~-cirnn ,Ic res: 5;; ~l7ef~~idian: I, Tr~u~nship: 012N Range: 0081: S"ection: 19 ~~~_c~tr~»1.~Ic~rc~s: Sti; ll~eridi~rn.~ 11 7~n~~nsliip: 012N Range: 008[.: ~'ection: ~U ti'rc~lirur .I~~j~c~s: E;~0 Legat Description 08-? ~- 199? * *SALE NOT/Ch hEGAI. DF,SC'RIPTIOi'~'* * Tfz.1CT %~-10 T. 1?N., R. b'E., U~l1IATMERIDIAN, ALASh'.9, TRACTA SECTION 1 i, UNSURVEYED, ALL, 610 :=ICRES,~ SECTION 18, UNSURhEYED, ALL, X83 AC2L.'S: ,S'6CTION 19, t%11!SC;RVE~1D. Al,l, ~8~ ACRES: .SECTION 20, UN,SURVEYED, ALL, 6-10 ACRES. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=3 8010... 11 /26/2007 Alaska Department of Natural Resources Land Administration System Page 2 of 3 THIS TRACT CONTAINS 2, 448 ACRES MORE OR LESS. ****10/01/2002 UNITIZEDLE4SELEGAL DESCRIPTION*************** ENTIRE LEASE COMMITTED TO KUPARUK RIVER UNITEIGHTH EXPANSION KUPARUK RIVER UNIT TRACT 1~0 T. 12N., R 8E., UMIAT MERIDIAN, ALASKA SECTION 17, UNSURVEYED, ALL, 640 ACRES: SECTION 18, UNSURVEYED, ALL, 583 ACRES; SECTION 19, UNSURVEYED, ALL, 585 ACRES; SECTION 20, UNSURVEYED, ALL, 640 ACRES. THIS TRACT CONTAINS 2, 448 ACRES MORE OR LESS. * ~ *10/01/2002 PARTICPATING AREA LEASE LEGAL DESCRIPTION ~` LEASE COMMITTED IN PART TO KUPARUK RISER PARTICIPATINU AREA MNHI EXPANSION KUPARUK RIVER UNIT TRACT 1 ~ 0(PARTIAL) T. 12N. , R. 8E. , UMIAT MERIDIAN, ALASKA SECTION 17, UNSURVEYED, AI,L, 640 ACRES; .SECTION 18, UN,SURY'EYED, ALL, 583 ACRES; S6CTIO1'~~ 19, UN.SURG'EY"ED, NI/2, INCL UDING ALL NAVIGABLE WATER BODIES, 292.50 :1 C'RES; SECTION20, UNSURVEYED, Nl/?, 320ACRES; CONT.AI,~VING 1, 83~. ~ 0 ACRES ~LIORE OR LESS. *:k ,k :k*;krx:k#*:kxM~ <:k*x~k 'X--~~:=k ~: ~:k ;;<x ~: ~k* <:;<x*~*=k:x:~*y~~k>:+~~*+~=k a:~**~***##>k.:k :%>;c 06-0l-200 ~ ~~` * * LEA,S'E CONTRACTED IN PART FR0:1I THE KP1 "* 'CR~~1 GE REMIANING IN KPA IS DESCRIBED AS FULLO~i'S: http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=3 8010... 11 /26/2007 Alaska Department of Natural Resources Land Administration System Page 3 of 3 • KUPARUKRIVER UNIT KUPARUKRIVER PARTICIPATING AREA TRACT 1 ~ 0 (PARTIAL) T.12 N., R. 8 E., UMIATMERIDIAN, ALASKA SECTION 17: ALL. 60.00 ACRES; SECTION 18: ALL, 583.00 ACRES; SECTION 19: N3, INCL UDING ALL NAVIGABLE WATER ~3ODIES, 292.00 ACRES; SECTION 20: NWT, 160.00 ACRES; THIS TRACT CONTAINS 1.67. ~ 0 ACRES, MORE OR LESS. ~k~*=k~k#*:k;~~#****=k~k:k~#x~~:kM~~k~***#*x**~k****~k~~*~k*~=k**=k*~k*=k*~#~~*****~~k x:< Last updated on 11/26/2007. Not sure who to contact? Have a question about DNR? Visit the Ptal~lic In~orrna~c?n C;~nt:er. Report technical problems with this page to the ~1l~r~~t;~r. Site optimized for Netscape 7, IE 6 or above. This site also requires that all O®~CTF must be accepted. State of_Aiaska Natural. Resources LAS Home Copyright Privacy System Status http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=3 8010... 11 /26/2007 ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ 3~S 'O~G PTD# ~D~>6,~0 Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT {OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , API No. 50- - - API number are production should continue to be reported as a of the between 60-69) original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number {50- -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with ZO AAC EXCEPTION 25.055. Approval to pcrforate 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. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for j~name Qf well) until after (Comvany Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. SComaany Name) must contact the Commission to obtain advance approval of such water welt testing ro ram. 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O r O r N M V' M f0 1~ Of) M r N M~~ f0 1~ r r r r r CD O O N r r N N N M I In t0 f~ GO N N N N N N O O r N M M N M~ M M M ~ M f0 h CD O M M M M -- . U - - n --- _ ---- -..- n ^ ~ m ~ C a+ N 0 a+ ~ N a + ~ G N V ° O im : (p 'w N p~ ~ V / N W m ~ ~ (~ ~ ~ .. ~ C i C L W G L O V ~ Q Q Q W Q ~ Q Q Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well Nistory file and to simplify Tending infom~ation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made io chronologically . organize this category of information. • 35-08C.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision• 3 $ LisLib $Revision: 4 $ Thu Mar 06 09:40:06 2008 Reel Header Service name .............LISTPE Date .....................08/03/06 on 9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. Tape Header Service name .............LISTPE Date . ...................08/03/06 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comment5 .................STS LIS Writing Physical EOF Comment Record TAPE HEADER Kuparuk MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA C~ scientific Technical services Library. scientific Technical services 3s-08C 501032045003 ConocoPhillips Alaska, Inc. Sperry Sun 06-MAR-08 MWD RUN 1 JOB NUMBER: Mw-000547705 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 18 12N 8E 2492 955 .00 55.70 27.70 WELL CASING RECORD Page 1 • 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 3S-08C.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 4263.0 • 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR P4) PRESSURE WHILE DRILLING (PWD) AND DRILLSTRING DYNAMICS SENSOR (DDS). 4. MWD DATA IS CONSIDERD PDC PER THE E-MAIL FROM R. ELGARICO OF CONOCOPHILLIPS ALASKA TO R KALISH OF SPERRY DRILLING SERVICES DATED 31-JAN-2008. 5. MWD RUN 1 REPRESENTS WELL 35-08C INTERMEDIATE HOLE SECTION WITH API # 50-103-20450-03. THE INTERMEDIATE HOLE REACHED A TOTAL DEPTH OF 8825'MD/5851'TVD. PRODUCTION HOLE DATA WERE NOT ACQUIRED BY SPERRY DRILLING SERVICES. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED DUAL GAMMA RAY COMBINED SEXP = SMOOTHED EXTRA-SHALLOW PHASE SHIFT RESISTIVITY SESP = SMOOTHED SHALLOW PHASE SHIFT RESISTIVITY SEMP = SMOOTHED MEDIUM PHASE SHIFT RESISTIVITY SEDP = SMOOTHED DEEP PHASE SHIFT RESISTIVITY SFXE = SMOOTHED RESISTIVITY FORMATION EXPOSURE TIME-HOURS SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 comment Record Page 2 i • FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE RPX RPS RPM RPD FET GR ROP 1 3S-08C.tapx clipped curves; all bit runs merged. .5000 START DEPTH 4209.0 4209.0 4209.0 4209.0 4209.0 4217.0 4263.5 STOP DEPTH 8770.5 8770.5 8770.5 8770.5 8770.5 8778.0 8825.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE $wD 1 4209.0 8826.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 4209 8825.5 6517.25 9234 4209 8825.5 ROP MWD FT/H 0 387.94 147.603 9115 4263.5 8825.5 GR MWD API 51.56 444.24 126.372 9123 4217 8778 RPX MWD OHMM 0.11 20.8 3.56895 9124 4209 8770.5 RPS MWD OHMM 0.06 2000 3.98495 9124 4209 8770.5 RPM MWD OHMM 0.06 2000 6.09263 9124 4209 8770.5 Page 3 i 3S-08C.tapx RPD MWD OHMM 0.02 2000 18.129 FET MWD HOUR 0.2 5 0.886908 First Reading For Entire File..........4209 Last Reading For Entire File...........8825.5 File Trailer Service name... .......STSLIB.001 Service sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/03/06 Maximum Physical Record..65535 File Ty e ................L0 Next Fl~e Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/06 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD • 9124 4209 8770.5 9124 4209 8770.5 Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 4209.0 8770.5 RPS 4209.0 8770.5 RPM 4209.0 8770.5 RPD 4209.0 8770.5 FET 4209.0 ~ 8770.5 GR 4217.0 8778.0 ROP 4263.5 8825.5 LOG HEADER DATA DATE LOGGED: 17-DEC-07 SOFTWARE SURFACE SOFTWA RE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8826.0 TOP LOG INTERVAL (FT): 4209.0 BOTTOM LOG INTERVAL (FT): 8826.0 BIT ROTATING SPEE D (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 21.9 MAXIMUM ANGLE: 85.2 Page 4 • • 3S-08C.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132478 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 4263.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 10.20 MUD VISCOSITY (S): 46.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 4.000 84.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.415 143.6 MUD FILTRATE AT MT: 4.900 84.0 MUD CAKE AT MT: 4.000 84.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWDO10 FT/H 4 1 68 4 2 GR MwD010 API 4 1 68 8 3 RPX MWDO10 OHMM 4 1 68 12 4 RPS MWDO10 OHMM 4 1 68 16 5 RPM MWDO10 OHMM 4 1 68 20 6 RPD MWDO10 OHMM 4 1 68 24 7 FET MWDO10 HOUR 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 4209 8825.5 6517.25 9234 4209 8825.5 ROP MWDO10 FT/H 0 387.94 147.603 9115 4263.5 8825.5 GR MWDO10 API 51.56 444.24 126.372 9123 4217 8778 Page 5 3s-08C.tapx RPX MWDO10 OHMM 0.11 20.8 3.56895 9124 4209 8770.5 RPS MWDO10 OHMM 0.06 2000 3.98495 9124 4209 8770.5 RPM MWDO10 OHMM 0.06 2000 6.09263 9124 4209 8770.5 RPD MWDO10 OHMM 0.02 2000 18.129 9124 4209 8770.5 FET MWDO10 HOUR 0.2 5 0.886908 9124 4209 8770.5 First Reading For Entire File..........4209 Last Reading For Entire File...........8825.5 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/06 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/03/06 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS Lis writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/03/06 Ori qin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library PhyS1Ca1 EOF Physical EOF End Of LIS File scientific Technical services scientific Technical services Page 6