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Home My WebLink About207-090Originated: Delivered to:7-Mar-25 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 2N-310 50-103-20549-00 909873379 Kuparuk River 3-Phases Saturation Analysis Field & Processed 27-Feb-25 0 1 2 2T-37 50-103-20227-00 909890550 Kuparuk River Multi Finger Caliper Field & Processed 25-Feb-25 0 1 3 2W-01 50-029-21273-00 9097400015 Kuparuk River Multi Finger Caliper Field- Final 1-Feb-25 0 1 4 3C-10A 50-029-21356-01 909890673 Kuparuk River Packer Setting Record Field- Final 4-Mar-25 0 1 5 3M-22 50-029-21740-00 909747918 Kuparuk River Leak Detect Log with ACX Field & Processed 8-Dec-24 0 1 6 7 8 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 207-090 195-101 185-010 213-083 187-067 T40197 T40198 T40199 T40200 T40201 3/7/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.07 10:31:59 -09'00' 2N-310 50-103-20549-00 909873379 Kuparuk River 3-Phases Saturation Analysis Field & Processed 27-Feb-25 0 1 207-090 ORIGINATED TRANSMITTAL DATE: 11/22/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5170 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5170 2N-310 50103205490000 Stim Tube 14-Nov-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 207-090 T39796 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.22 09:43:30 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Originated:Delivered to:12-Jun-24 Alaska Oil & Gas Conservation Commiss 12Jun24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER # FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED CD4-587 50-103-20867-00-00 223-098 Colville River WL PPROF FINAL FIELD 29-Apr-24 2F-18 50-029-22720-00-00 Kuparuk River WL CBL FINAL FIELD 5-May-24 2F-18 50-029-22720-00-00 Kuparuk River WL GR FINAL FIELD 5-May-24 WD-02 50-103-20285-00-00 198-258 Colville River WL WFL FINAL FIELD 11-May-24 2N-310 50-103-20549-00-00 207-090 Kuparuk River WL Perforation FINAL FIELD 11-May-24 CD1-01A 50-103-20299-01-00 212-099 Colville River WL WFL FINAL FIELD 13-May-24 CD1-33A 50-103-20357-01-00 222-105 Colville River WL WFL FINAL FIELD 12-May-24 Transmittal Receipt ________________________________X__________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Ousidame@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T38933 T38934 T38934 T38935 T38936 T38937 T38938 2N-310 50-103-20549-00-00 207-090 Kuparuk River WL Perforation FINAL FIELD 11-May-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.13 09:21:58 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Pull Patch/Convert to PROD Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11840'feet 11230', 11530', 11541'feet true vertical 6036' feet None feet Effective Depth measured 11230'feet 10613', 10633'feet true vertical 5470' feet 4990', 5004' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 10627' MD 5000' TVD Packers and SSSV (type, measured and true vertical depth) 10613' MD 10633' MD 2202' MD 4990' TVD 5004' TVD 1919' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 3521' 2394' Burst Collapse Production Liner 10800' 1223' Casing 5152' 4-1/2" 10828' 11840' 6036' 3490' 110'Conductor Surface Intermediate 20" 9-5/8" 79' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 207-090 50-103-20549-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0375074, ADL0380053 Kuparuk River Field/ Tarn Oil Pool (Cairn) KRU 2N-310 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 63 Gas-Mcf MD ~ Size 110' 160 131971 Well was Shut-In ~~ 213 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker G-22 Seal Assembly Packer: HRD ZXP Liner Top Packer SSSV: TRM-4PE-CF SSSV Katherine O'Connor katherine.oconnor@conocophillips.com (907) 263-3718Senior Interventions Engineer Open:Re-perf:11185-11205' (Cairn), New: 11133-11137', 11140-11150', 11157-11177' (Cairn) Closed: 11272-11348', 11358-11410' 11436-11446' (Bermuda), 11670-11690' (Esker) Open: Re-Perf: 5432-5449' (Cairn), New: 5389-5392', 5395-5403', 5409-5425' (Cairn) Closed: 5506-5574', 5583-5631', 5655-5665' (Bermuda), 5876-5895' (Esker) Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:09 pm, May 23, 2024 Digitally signed by Kate Dodson DN: OU=Wells, O=ConocoPhillips, CN=Kate Dodson, E= kate.dodson@conocophillips.com Reason: Signing on behalf of Katherine O'Connor Location: Date: 2024.05.23 11:00:11-08'00' Foxit PDF Editor Version: 13.0.0 Kate Dodson RBDMS JSB 053024 DSR-5/23/24 DTTMSTART JOBTYP SUMMARYOPS 5/10/2024 PUMPING TRACKING ONLY FREEZE PROTECT PUMPED 40 BBLS DSL DWN TBG PUMPED 10 BBLS DSL DWN FL 5/10/2024 OPTIMIZE WELL PERFORATE INTERVAL 11,185' - 11,205' WITH 20' X 2.88" HSD POWERJET, 6 SPF, 60 DEG PHASING, CCL TO TOP-SHOT = 3.3', CCL STOP = 11,181.7', CORRELATE TO TOWN SUPPLIED GR LOG DATED 5/2/24. JOB IN PROGRESS 5/11/2024 OPTIMIZE WELL CONTINUE TO PERFORATE INTERVALS W/ POWERJET, 6 SPF, 60 DEG PHASE GUNS: RUN #2: 11,157' - 11,177', CCL TO TOP-SHOT = 3.3', CCL STOP = 11,153.7'. RUN #3: 11,133' - 11,137' & 11,140' - 11,150' , CCL TO TOP-SHOT = 3.3', CCL STOP = 11,129.7' TURN WELL OVER TO OPS TO BOL, JOB IS COMPLETE. 2N-310 Perforations Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:RKB 11,495.0 2N-310 7/7/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added Cairn perforations 2N-310 5/11/2024 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 7/27/2008 ninam 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 20 18.73 31.0 110.0 110.0 133.00 J-55 WELDED SURFACE 9 5/8 8.83 30.5 3,520.9 2,393.7 40.00 L-80 Buttress Thread INTERMEDIATE 7 6.28 28.2 10,828.0 5,151.9 26.00 L-80 BTC LINER 4 1/2 3.96 10,616.5 11,840.0 12.60 L-80 IBT MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 26.0 Set Depth … 10,627.3 Set Depth … 5,000.0 String Max No… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT ID (in) 3.96 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) 26.0 26.0 0.00 HANGER 10.850 FMC Tubing Hanger w/ 2.66' Pup 3.958 2,201.6 1,919.2 61.68 SAFETY VLV 6.000 4.5" TRM-4PE-CF SSSV 3.813" DBProfile 1/4" SS line **BROKEN FLAPPER 9/4/2008** T&C Non- Upset 3.813 3,503.6 2,387.9 70.36 GAS LIFT 5.984 4.5" X 1" KBG-2-1R w/ dummy valve BK-5 Latch CAMCO KBG-2- 1R 3.860 6,664.6 3,487.6 70.13 GAS LIFT 5.984 4.5" X 1" KBG-2-1R w/ Dummy valve BK-5 Latch CAMCO KBG-2- 1R 3.860 9,185.2 4,357.0 69.84 GAS LIFT 5.984 4.5" X 1" KBG-2-1R w/ dummy valve BK-5 Latch CAMCO KBG-2- 1R 3.860 10,446.5 4,875.6 49.53 GAS LIFT 5.984 4.5" X 1" KBG-2-1R w/ DCK-2 Shear valve BEK-5 Latc CAMCO KBG-2- 1R 3.860 10,526.9 4,929.4 46.70 SLEEVE 5.490 "CMD" Sliding sleeve w/ 3.813" X- Profile T&C Non- Upset 3.813 10,611.9 4,989.0 44.32 LOCATOR 5.770 BAKER NO GO LOCATOR T&C Non- Upset 3.958 10,612.9 4,989.7 44.29 SEAL ASSY 4.940 Baker G-22 Locator seal assembly OD 4.94 ID 3.93 T&C Non- Upset 3.930 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,200.0 1,918.5 61.60 ISO-SLEEVE HOLD OPEN SLEEVE (NO SEALS) 10.3' OAL 7/17/2023 3.180 11,230.0 5,470.0 31.17 CIBP CIBP W/ MOE @ 11,230' RKB, OAL = 1.24', OE = 3.49" SALE 7/16/2023 0.000 11,530.0 5,744.2 19.08 CMT PLUG CEMENT PLUG, PT TBING TO 3000 psi 2/28/2008 0.000 11,541.0 5,754.6 19.26 SAND PLUG SAND PLUG 2/27/2008 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) 3,503.6 2,387.9 70.36 1 Gas Lift DMY BK-5 1 0.0 12/27/2007 5:30 0.000 6,664.6 3,487.6 70.13 2 Gas Lift DMY BK-5 1 0.0 12/27/2008 10:00 0.000 9,185.2 4,357.0 69.84 3 Gas Lift DMY BK-5 1 0.0 9/24/2007 2:00 0.000 10,446.5 4,875.6 49.53 4 GAS LIFT OV BK 1 0.0 7/14/2023 12:00 0.250 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) 10,632.7 5,004.0 43.70 PACKER 5.990 "HRD" ZXP LINER TOP PACKER 3.875 10,660.7 5,024.3 42.87 NIPPLE 5.550 CAMCO DB-6 NIPPLE 3.750 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,133.0 11,137.0 5,389.0 5,392.2 5/11/2024 6.0 APERF 2.875" POWER JET GUNS, 6 SPF, 60 DEGREE PHASE 11,140.0 11,150.0 5,394.7 5,402.9 5/11/2024 6.0 APERF 2.875" POWER JET GUNS, 6 SPF, 60 DEGREE PHASE 11,157.0 11,177.0 5,408.6 5,425.2 5/11/2024 6.0 APERF 2.875" POWER JET GUNS, 6 SPF, 60 DEGREE PHASE 11,185.0 11,205.0 5,431.9 5,448.7 CAIRN, 2N-310 4/4/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,185.0 11,205.0 5,431.9 5,448.7 CAIRN, 2N-310 5/10/2024 6.0 RPERF 2.875" POWER JET GUNS, 6 SPF, 60 DEGREE PHASE 11,272.0 11,348.0 5,506.3 5,573.7 BERMUDA, 2N- 310 3/11/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random DEVIATED, 2N-310, 5/13/2024 12:41:04 PM Vertical schematic (actual) LINER; 10,616.5-11,840.0 IPERF; 11,670.0-11,690.0 FRAC; 11,670.0 SAND PLUG; 11,541.0 CMT PLUG; 11,530.0 APERF; 11,436.0-11,446.0 APERF; 11,358.0-11,410.0 APERF; 11,272.0-11,348.0 CIBP; 11,230.0 RPERF; 11,185.0-11,205.0 FRAC; 11,185.0 APERF; 11,185.0-11,205.0 APERF; 11,157.0-11,177.0 APERF; 11,140.0-11,150.0 APERF; 11,133.0-11,137.0 INTERMEDIATE; 28.3-10,828.0 GAS LIFT; 10,446.5 GAS LIFT; 9,185.2 GAS LIFT; 6,664.6 SURFACE; 30.5-3,520.9 GAS LIFT; 3,503.6 ISO-SLEEVE; 2,200.0 SAFETY VLV; 2,201.6 CONDUCTOR; 31.0-110.0 KUP INJ KB-Grd (ft) 35.81 RR Date 9/25/2007 Other Elev… 2N-310 ... TD Act Btm (ftKB) 11,840.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032054900 Wellbore Status INJ Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBORE2N-310 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,358.0 11,410.0 5,582.8 5,631.0 BERMUDA, 2N- 310 3/9/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,436.0 11,446.0 5,655.4 5,664.8 BERMUDA, 2N- 310 3/9/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,670.0 11,690.0 5,875.9 5,894.7 ESKER, 2N-310 11/17/2007 6.0 IPERF 2.88" HSD PJ 2906 HMK, 60 Deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 11,670.0 11,690.0 1 FRAC 11/25/2007 0.0 0.00 0.00 11,185.0 11,205.0 2 FRAC 4/6/2008 0.0 0.00 0.00 DEVIATED, 2N-310, 5/13/2024 12:41:04 PM Vertical schematic (actual) LINER; 10,616.5-11,840.0 IPERF; 11,670.0-11,690.0 FRAC; 11,670.0 SAND PLUG; 11,541.0 CMT PLUG; 11,530.0 APERF; 11,436.0-11,446.0 APERF; 11,358.0-11,410.0 APERF; 11,272.0-11,348.0 CIBP; 11,230.0 RPERF; 11,185.0-11,205.0 FRAC; 11,185.0 APERF; 11,185.0-11,205.0 APERF; 11,157.0-11,177.0 APERF; 11,140.0-11,150.0 APERF; 11,133.0-11,137.0 INTERMEDIATE; 28.3-10,828.0 GAS LIFT; 10,446.5 GAS LIFT; 9,185.2 GAS LIFT; 6,664.6 SURFACE; 30.5-3,520.9 GAS LIFT; 3,503.6 ISO-SLEEVE; 2,200.0 SAFETY VLV; 2,201.6 CONDUCTOR; 31.0-110.0 KUP INJ 2N-310 ... WELLNAME WELLBORE2N-310 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Pull Patch/Convert to PROD Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11840'feet 11230', 11530', 11541'feet true vertical 6036' feet None feet Effective Depth measured 11230'feet 10613', 10633'feet true vertical 5470' feet 4990', 5004' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 10627' MD 5000' TVD Packers and SSSV (type, measured and true vertical depth) 10613' MD 10633' MD 2202' MD 4990' TVD 5004' TVD 1919' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 323-318 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker G-22 Seal Assembly Packer: HRD ZXP Liner Top Packer SSSV: TRM-4PE-CF SSSV Natalie Dye natalie.b.dye@conocophillips.com (907) 265-1027Senior Production Engineer Open: 11185-11205' (Cairn) Closed: 11272-11348', 11358-11410' 11436-11446' (Bermuda), 11670-11690' (Esker) Open: 5432-5449' (Cairn) Closed: 5506-5574', 5583-5631', 5655-5665' (Bermuda), 5876-5895' (Esker) measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 63 Gas-Mcf MD ~ Size 110' 160 131971 Well was Shut-In ~~ 213 measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 207-090 50-103-20549-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0375074, ADL0380053 Kuparuk River Field/ Tarn Oil Pool (Cairn) KRU 2N-310 Plugs Junk measured Length Production Liner 10800' 1223' Casing 5152' 4-1/2" 10828' 11840' 6036' 3490' 110'Conductor Surface Intermediate 20" 9-5/8" 79' 3521' 2394' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:14 am, May 16, 2024 Natasha Dye Digitally signed by Natasha Dye Date: 2024.05.16 10:04:10 -08'00' RBDMS JSB 052124 DSR-5/20/24 DTTMSTART JOBTYP SUMMARYOPS 5/11/2023 ACQUIRE DATA (AC EVAL) T POT (PASSED), T PPPOT (PASSED), IC POT (PASSED), IC PPPOT (PASSED). 6/16/2023 PUMPING TRACKING ONLY FREEZE PROTECT TBG & FL PUMPING FROM VALVE SHELTER PUMPED 40 BBLS DIESEL DOWN TBG PUMPED 5 BBLS DIESEL DOWN FLOWLINE JOB COMPLETE 7/7/2023 OPTIMIZE WELL DRIFT & TAG, BTM @ 11,495' RKB. MEASURE SBHP @ 11359' RKB (4081 PSI) IN PROGRESS. 7/8/2023 OPTIMIZE WELL PULLED ISO SLEEVE @ 2200' RKB. DRIFTED TUBING DOWN TO LINER PACKER W/ 2.84 GAUGE RING. SET WEATHERFORD PULLING TOOL (TTS STYLE RELEASABLE) IN PATCH, JARRED ON PATCH 1 HOUR, IN PROGRESS 7/9/2023 OPTIMIZE WELL PULLED WEATHERFORD UPPER PATCH 11,175' RKB. ATTEMPTED TO PULL LOWER PACKER 11,205 RKB, IN PROGRESS 7/10/2023 OPTIMIZE WELL JARRED ON LOWER PACKER 11,202 RKB (40 MIN) WIRE PARTED AT THE COUNTER HEAD LEAVING PARTED WIRE ON SURFACE. TIE BACK WIRE & POOH W/ ALL WIRE/TOOLS. IN PROGRESS 7/12/2023 OPTIMIZE WELL ATTEMPTED TO PULL LOWER PACKER @ 11,202' RKB (SHEARED GS 3 TIMES). IN PROGRESS. 7/13/2023 OPTIMIZE WELL PULLED LOWER WEATHERFORD ER PKR @ 11,205' RKB. IN PROGRESS 7/14/2023 OPTIMIZE WELL BRUSH n' FLUSH TBG BELOW CAIRN PERFS FROM 11,100' RKB THRU 11,300' RKB. PULLED DMY VALVE & REPLACED W/ 1/4" OV @ 10,447' RKB (ACHIEVED SUCCESSFUL DDT ON IA), READY FOR ELINE. 7/16/2023 OPTIMIZE WELL SLB E-LINE: MAKE UP 3.49" OD CAST IRON BRIDGE PLUG ON BAKER 10 SETTING TOOL TOOL WITH CCL/GR. SET PLUG AT 11230', ABOVE BERMUDA BUT BELOW CAIRN PERFORATIONS. CCL TO CE = 26.7', CCL STOP DEPTH = 11203.3'. CORRELATED TO TUBING TALLY: PERFORATIONS AT 11272' AND 11185' AND TO COLLARS FROM SLB PERFORATION RECORD DATED 9-MAR-2008. JOB IS FOR SL 7/17/2023 OPTIMIZE WELL DRIFT & TAG SSSV @ 2201' RKB W/ 2.85" GUAGE RING. INSTALL ISO SLEEVE IN SSSV @ 2201' RKB, JOB COMPLETE. 7/26/2023 OPTIMIZE WELL DRIFTED TBG W/ 2.25" CENT, 1.75" SAMPLE BAILER TO TOP OF CIBP @ 11,230' RKB. JOB IN PROGRESS. 7/27/2023 OPTIMIZE WELL MEASURED SBHP @ 11,200' RKB (MAX = 3994 PSI). READY FOR ELINE 4/19/2024 OPTIMIZE WELL LOG CORRELATED TO SLB PERF RECORD DATED 9-Mar-2008. PERFROMED 30 MIN STATION AT 11228' (2' ABOVE CIBP), NO FLOW OBSERVED UP OR DOWN, WELL LEFT S/I. JOB IS COMPLETE. 2N-310 Convert Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:RKB 11,495.0 2N-310 7/7/2023 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added Cairn perforations 2N-310 5/11/2024 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 7/27/2008 ninam 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 20 18.73 31.0 110.0 110.0 133.00 J-55 WELDED SURFACE 9 5/8 8.83 30.5 3,520.9 2,393.7 40.00 L-80 Buttress Thread INTERMEDIATE 7 6.28 28.2 10,828.0 5,151.9 26.00 L-80 BTC LINER 4 1/2 3.96 10,616.5 11,840.0 12.60 L-80 IBT MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 26.0 Set Depth … 10,627.3 Set Depth … 5,000.0 String Max No… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT ID (in) 3.96 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) 26.0 26.0 0.00 HANGER 10.850 FMC Tubing Hanger w/ 2.66' Pup 3.958 2,201.6 1,919.2 61.68 SAFETY VLV 6.000 4.5" TRM-4PE-CF SSSV 3.813" DBProfile 1/4" SS line **BROKEN FLAPPER 9/4/2008** T&C Non- Upset 3.813 3,503.6 2,387.9 70.36 GAS LIFT 5.984 4.5" X 1" KBG-2-1R w/ dummy valve BK-5 Latch CAMCO KBG-2- 1R 3.860 6,664.6 3,487.6 70.13 GAS LIFT 5.984 4.5" X 1" KBG-2-1R w/ Dummy valve BK-5 Latch CAMCO KBG-2- 1R 3.860 9,185.2 4,357.0 69.84 GAS LIFT 5.984 4.5" X 1" KBG-2-1R w/ dummy valve BK-5 Latch CAMCO KBG-2- 1R 3.860 10,446.5 4,875.6 49.53 GAS LIFT 5.984 4.5" X 1" KBG-2-1R w/ DCK-2 Shear valve BEK-5 Latc CAMCO KBG-2- 1R 3.860 10,526.9 4,929.4 46.70 SLEEVE 5.490 "CMD" Sliding sleeve w/ 3.813" X- Profile T&C Non- Upset 3.813 10,611.9 4,989.0 44.32 LOCATOR 5.770 BAKER NO GO LOCATOR T&C Non- Upset 3.958 10,612.9 4,989.7 44.29 SEAL ASSY 4.940 Baker G-22 Locator seal assembly OD 4.94 ID 3.93 T&C Non- Upset 3.930 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,200.0 1,918.5 61.60 ISO-SLEEVE HOLD OPEN SLEEVE (NO SEALS) 10.3' OAL 7/17/2023 3.180 11,230.0 5,470.0 31.17 CIBP CIBP W/ MOE @ 11,230' RKB, OAL = 1.24', OE = 3.49" SALE 7/16/2023 0.000 11,530.0 5,744.2 19.08 CMT PLUG CEMENT PLUG, PT TBING TO 3000 psi 2/28/2008 0.000 11,541.0 5,754.6 19.26 SAND PLUG SAND PLUG 2/27/2008 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) 3,503.6 2,387.9 70.36 1 Gas Lift DMY BK-5 1 0.0 12/27/2007 5:30 0.000 6,664.6 3,487.6 70.13 2 Gas Lift DMY BK-5 1 0.0 12/27/2008 10:00 0.000 9,185.2 4,357.0 69.84 3 Gas Lift DMY BK-5 1 0.0 9/24/2007 2:00 0.000 10,446.5 4,875.6 49.53 4 GAS LIFT OV BK 1 0.0 7/14/2023 12:00 0.250 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) 10,632.7 5,004.0 43.70 PACKER 5.990 "HRD" ZXP LINER TOP PACKER 3.875 10,660.7 5,024.3 42.87 NIPPLE 5.550 CAMCO DB-6 NIPPLE 3.750 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,133.0 11,137.0 5,389.0 5,392.2 5/11/2024 6.0 APERF 2.875" POWER JET GUNS, 6 SPF, 60 DEGREE PHASE 11,140.0 11,150.0 5,394.7 5,402.9 5/11/2024 6.0 APERF 2.875" POWER JET GUNS, 6 SPF, 60 DEGREE PHASE 11,157.0 11,177.0 5,408.6 5,425.2 5/11/2024 6.0 APERF 2.875" POWER JET GUNS, 6 SPF, 60 DEGREE PHASE 11,185.0 11,205.0 5,431.9 5,448.7 CAIRN, 2N-310 4/4/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,185.0 11,205.0 5,431.9 5,448.7 CAIRN, 2N-310 5/10/2024 6.0 RPERF 2.875" POWER JET GUNS, 6 SPF, 60 DEGREE PHASE 11,272.0 11,348.0 5,506.3 5,573.7 BERMUDA, 2N- 310 3/11/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random DEVIATED, 2N-310, 5/13/2024 12:41:04 PM Vertical schematic (actual) LINER; 10,616.5-11,840.0 IPERF; 11,670.0-11,690.0 FRAC; 11,670.0 SAND PLUG; 11,541.0 CMT PLUG; 11,530.0 APERF; 11,436.0-11,446.0 APERF; 11,358.0-11,410.0 APERF; 11,272.0-11,348.0 CIBP; 11,230.0 RPERF; 11,185.0-11,205.0 FRAC; 11,185.0 APERF; 11,185.0-11,205.0 APERF; 11,157.0-11,177.0 APERF; 11,140.0-11,150.0 APERF; 11,133.0-11,137.0 INTERMEDIATE; 28.3-10,828.0 GAS LIFT; 10,446.5 GAS LIFT; 9,185.2 GAS LIFT; 6,664.6 SURFACE; 30.5-3,520.9 GAS LIFT; 3,503.6 ISO-SLEEVE; 2,200.0 SAFETY VLV; 2,201.6 CONDUCTOR; 31.0-110.0 KUP INJ KB-Grd (ft) 35.81 RR Date 9/25/2007 Other Elev… 2N-310 ... TD Act Btm (ftKB) 11,840.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032054900 Wellbore Status INJ Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBORE2N-310 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 11,358.0 11,410.0 5,582.8 5,631.0 BERMUDA, 2N- 310 3/9/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,436.0 11,446.0 5,655.4 5,664.8 BERMUDA, 2N- 310 3/9/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,670.0 11,690.0 5,875.9 5,894.7 ESKER, 2N-310 11/17/2007 6.0 IPERF 2.88" HSD PJ 2906 HMK, 60 Deg phase Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 11,670.0 11,690.0 1 FRAC 11/25/2007 0.0 0.00 0.00 11,185.0 11,205.0 2 FRAC 4/6/2008 0.0 0.00 0.00 DEVIATED, 2N-310, 5/13/2024 12:41:04 PM Vertical schematic (actual) LINER; 10,616.5-11,840.0 IPERF; 11,670.0-11,690.0 FRAC; 11,670.0 SAND PLUG; 11,541.0 CMT PLUG; 11,530.0 APERF; 11,436.0-11,446.0 APERF; 11,358.0-11,410.0 APERF; 11,272.0-11,348.0 CIBP; 11,230.0 RPERF; 11,185.0-11,205.0 FRAC; 11,185.0 APERF; 11,185.0-11,205.0 APERF; 11,157.0-11,177.0 APERF; 11,140.0-11,150.0 APERF; 11,133.0-11,137.0 INTERMEDIATE; 28.3-10,828.0 GAS LIFT; 10,446.5 GAS LIFT; 9,185.2 GAS LIFT; 6,664.6 SURFACE; 30.5-3,520.9 GAS LIFT; 3,503.6 ISO-SLEEVE; 2,200.0 SAFETY VLV; 2,201.6 CONDUCTOR; 31.0-110.0 KUP INJ 2N-310 ... WELLNAME WELLBORE2N-310 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2H-11 50-103-20052-00 185261_2H-11_SCMT Post-BiSN_22Aug2023 185261_2H-11_SCMT Pre-BiSN_27Jul2023 2H-12 50-103-20053-00 185262_2H-12_PPROF_01Jun2023 2H-17 50-103-20329-00 200019_2H-17_IPROF_01Jul2023 2K-07 50-103-20107-00 189071_2K-07_RBP_17Apr2023 2M-20 50-103-20169-00 192048_2M-20_LDL_30Mar2022 2M-29 50-103-20183-00 192097_2M-29_Patch_30Dec2022 2N-310 50-103-20549-00 207090_2N-310_CIBP_16Jul2023 2N-316 50-103-20342-00 200090_2N-316_EVO RPB_23Mar2023 200090_2N-316_LDL Caliper_02Sept2022 2N-329 50-103-20257-00 198067_2N-329_PLUG-LDL_03Mar2023 198067_2N-329_RST_31Dec2022 2T-14 50-103-20061-00 186044_2T-14_Patch_11Jun2022 2U-12 50-029-21304-00 185041_2U-12_LDL_06Aug2023 7of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38372 T38373 T38374 T38375 T38376 T38377 T38378 T38379 T383780 T38381 T38382 2/29/2024 2N-310 50-103-20549-00 207090_2N-310_CIBP_16Jul2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:56:50 -09'00' P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 3, 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitors, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Brennen Green or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Brennen Green ConocoPhillips Well Integrity Field Supervisor Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2023.07.03 11:18:45-08'00' Foxit PDF Editor Version: 12.1.2 Brennen Green ConocoPhillips Alaska Inc.Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-offReport of Sundry Operations (10-404)KRUWell Name API # PTD #Initial top of cementVol. of cement pumpedFinal top of cementCement top off date Corrosion inhibitorCorrosion inhibitor/ sealant dateft bbls in gal1A-24 5002922984-0000 200-181 N/APost Conductor Ext21.5" 3/7/2022 12.7 7/2/20232L-323 5010320282-0000 198-251 N/APost Conductor Ext11" 7/31/2022 3.4 7/2/20232N-310 5010320549-0000 207-090 12' 2.3 7" 5/31/2023 4.25 7/2/20232N-322 5010320678-0000 213-179 9' 10" 1.1 6" 5/31/2023 2.1 7/2/20233G-08 5010320128-0000 190-065 10' 2" 1.0 5" 5/31/2023 1 7/2/2023Date 07/03/20231A, 2L, 2N, & 3G Pads2N-3105010320549-0000207-09012'2.37"5/31/20234.257/2/2023 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: Convert INJ to PROD 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11840'None Casing Collapse Conductor Surface Intermediate Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 11185-11205' (Cairn) 11272-11348', 11358-11410', 11436-11446' (Bermuda) 11670-11690' (Esker) 4-1/2" 5432-5449' (Cairn) 5506-5574', 5583-5631', 5655- 5665' (Bermuda) 5876-5895' (Esker) 11840'1223' 4-1/2" 20" 9-5/8" 79' 3490' Perforation Depth MD (ft): 7"10800' MD 110' 2394' 5152' 110' 3521' 10828' Length Size TVD Burst PRESENT WELL CONDITION SUMMARY 6036' 11530' 5744' 11530', 11541' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0375074, ADL0380053 207-090 P.O. Box 100360, Anchorage, AK 99510 50-103-20549-00-00 ConocoPhillips Alaska, Inc. KRU 2N-310 Kuparuk River Field N/A Tubing Grade: Tubing MD (ft): 10633' MD and 5004' TVD 11175' MD and 5423' TVD 2202' MD and 1919' TVD Perforation Depth TVD (ft): Tubing Size: L-80 10627' 6/15/2023 Packer: HRD ZXP Liner Top Packer Packer WFD ER Patch Packer Assembly SSSV: TRM-4PE-CF SSSV 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Natalie Dye n1135@conocophillips.com (907) 659-7519 Production Engineer Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Current Pools: Tarn Oil Pool (Bermuda) Proposed Pools: Tarn Oil Pool (Cairn) By Grace Christianson at 3:55 pm, May 31, 2023 323-318 Natasha Dye Digitally signed by Natasha Dye Date: 2023.05.31 14:48:10 -08'00' 10-404 X VTL 6/12/2023 SFD 6/8/2023 DSR-5/31/23 Pull patch X GCW 06/12/2023 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.12 16:09:12 -08'00' RBDMS JSB 061423 2N-310 Convert to Cairn Producer 26 May 2023 Expected start date: 15 June 2023 Natalie Dye Background & Objecve 2N-310 has been iden#$ed as a previous CAIRN producer that is capable of producing an immense amount of forma#on gas. To arrest the GKA $eld-wide indigenous gas decline, we would like to shut o2 the Bermuda perfs of this well and open up the CAIRN forma#on to produc#on. A CAIRN 4owback was performed in 2008 showing 500 BLPD and 10MMSCFD. It is likely this well will eventually go back to a Bermuda injector eventaully, so a millable plug will be set to retain that op#on. The only easily millable plugs are larger than the patch ID, so the patch needs to be pulled before the plug can be set. Objecve: Convert from Bermuda injector to Cairn producer by pulling the patch and then se:ng a plug above the Bermuda perfora#ons. Procedure 1. Dri; and tag Weatherford patch packer at ~11,175’ RKB 2. A@empt to pull Weatherford patch 3. If successful, brush and 4ush below around plug set area ~11,205-11,270’ RKB 4. RIH to set plug @ ~11260’ RKB (avoiding collars) 5. Bring well online 6. Run spinner/temp/pressure log from 11,100’ RKB down to plug set depth to con$rm no cross4ow is occurring between the Bermuda and Cairn sand 7. A;er con$rming no cross4ow, RDMO 8. If cross4ow is seen on log, reset plug ~30’ above the previous and log to con$rm good set MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, January 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2N-310 KUPARUK RIV U TARN 2N-310 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/26/2023 2N-310 50-103-20549-00-00 207-090-0 W SPT 5004 2070900 1500 1500 1500 1500 1500 71 71 72 72 4YRTST P Brian Bixby 12/21/2022 30 MinPretest Initial 15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name: KUPARUK RIV U TARN 2N-310 Inspection Date: Tubing OA Packer Depth 160 2300 2245 2235IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB221225045059 BBL Pumped:3 BBL Returned:2.7 Thursday, January 26, 2023 Page 1 of 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 Perforate New Pool Repair Well Re-enter Susp Well Other: SC Repair ConocoPhillips Alaska, Inc. Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,180' feet feet true vertical 6,036'feet feet Effective Depth measured feet 11,175' &10,633' feet true vertical feet 5,423' & 5,004' feet Perforation depth Measured depth 11,185'- 11,690'feet True Vertical depth 5,432'-5,896'feet Tubing (size, grade, measured and true vertical depth) 4.5" L-80 10,627 5,000' Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name:Roger Mouser Contact Email:N1927@cop.com Authorized Title:Well Integrity Field Supervisor Contact Phone:1-907-659-7506 322-161 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: Authorized Name and Digital Signature with Date: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Conductor TVD 110' Weatherford ER PKR 11,175' MD,5,423' TVD,HRD ZXP LINER TOP 10,633' MD, 5,004 'TVD/ SSSV 4.5" TRM-4PE-CF 2,202' MD,1,919' TVD Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0375074 / ADL0380053 Kuparuk River / Tarn Oil P.O.BOX 100360, Anchorage, AK 3. Address: KRU TARN 2N-310 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 207-090 50-029-20549-00-00 Length 80' 3,491' Size Surface Intermediate 20" 9.625" 7"10,800' Casing measuredPlugs Junk measured measured true vertical Packer MD 110' 3,521' 2,394' 5,125'10,828' Burst Collapse Form 10-404 Revised 10/2021 Submit Within 30 days of Operations By Anne Prysunka at 9:56 am, Nov 28, 2022 50-103-20549-00-00 SFD P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 27, 2022 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the Surface Casing repair on KRU 2N-310 (PTD 207-090). Please contact Brennen Green or me at 659-7506 if you have any questions. Sincerely, Roger Mouser Well Integrity Field Supervisor N1927@conocophillips.com ConocoPhillips Alaska, Inc. Date Event Summary Executive Summary SC Repair 04/06/22 Received approved Sundry 322-161 for Surface Casing repair of 2N-310 05/10/22 CUT WINDOWS INTO THE CONDUCTOR (COMPLETE) SCLD (SC LEAK @ ~66.5") 10/26/22 (SC REPAIR) EXCAVATE TO 16' (IN PROGRESS) REMOVE CELLAR BOX (COMPLETE) 10/28/22 (SC REPAIR) EXCAVATE TO 16', SET 10'DX16'H SHORING CAN (COMPLETE). 10/31/22 (SC Repair) Welders removed 11' 1.75" from conductor, Removed remaining cement from surface casing, cleaned and buffed surface casing, located and marked a hole in surface casing. 11/01/22 (SC Repair) Located surface casing hole at 53", OA FL at 66", Drilled, tapped, and plugged surface 11/03/22 (SC Repair) Mistras layed out A and B bands, Removed fluid from OA to 14' 6" from bottom of starter head, Surface casing damage inspection waived by AOGCC. 11/04/22 (SC Repair) Pressured and purged OA with N2 until O2 was ~5% and LEL was ~5 ppm at lower plug, 11/05/22 (SC Repair) Verified OA FL @ 14', OA FL inflowed 12" overnight. 11/08/22 (SC Repair) Verified OA FL, Pressured and purged OA with N2 until O2 = 6.5% and LEL = 0 ppm. 11/13/22 (SC REPAIR) RIGGED UP COOPER HEAT TO THE STARTER HEAD (COMPLETE) 11/14/22 (SC REPAIR) PURGED THE OA (COMPLETE) 11/15/22 (SC REPAIR) WELDED AND NDE THE COLLARS TO THE "A" AND "B" BAND (COMPLETE) FIT THE SLEEVE TO THE COLLARS (COMPLETE). AES Welders, welded the B bands and the A bands to the SC (rings were stacked and welded in the fab shop). A and B bands are made as following. Bottom ring: 9.75" I.D. x 0.500" Wall x 8" long X65. Top ring: 10.75" I.D. x 0.500" Wall x 4" long API 5L-X65 Mistras NDE the A and B bands (passed) Welders fit the Sleeve to the A and B bands (12.75" diameter x 0.500" Wall x 109" long API 5L-X65) 11/16/22 (SC REPAIR) RIG DOWN THE COOPER HEAT UNIT (COMPLETE) WELD SC SLEEVE (IN PROGRESS) 11/17/22 (SC REPAIR) WELD SC SLEEVE (COMPLETE) NDE SC SLEEVE AND STARTER HEAD (PASS) TOTAL REPAIRED AREA = 117" 11/19/22 (SC REPAIR) SCLD (IN PROGRESS) AOGCC INSPECTOR, AUSTIN MCLEOD WAIVED WITNESS 11/20/22 (SC REPAIR) SCLD (COMPLETE) DENSO WRAPPED THE SC SLEEVE (COMPLETE) Start T/I/O = SI/0+/1230 15 min T/I/O = SI/0+/1175 (-55 psi) OA FL @ 1014' 30 min T/I/O = SI/0+/1125 (-30 psi) OA FL @ 1050' No leaks at surface. 11/21/22 (SC REPAIR) WELD CONDUCTOR (COMPLETE) RIG DOWN SCAFFOLDING (COMPLETE) AES Welders, welded the Conductor to the original Conductor. 11' 2" long x 20" diameter x 0.375 wall X65 11/23/22 (SC REPAIR) REMOVE SHORING "CAN" (COMPLETE) BACKFILL EXCAVATION (IN PROGRESS) 11/25/22 (SC REPAIR) WELDED STEEL CELLAR TO CONDUCTOR, BACKFILLED TO CELLAR GRADE, TURNED OVER TO OPERATIONS FOR WELLHEAD PLATFORM REINSTALL. WELLHEAD JEWELRY NEEDS NORMALED UP (IN PROGRESS) 11/26/22 (SC Repair) : Normal Up Wellhead Jewelry (Complete), Bled IA & OA pressures (Complete). 5HJJ-DPHV%2*& )URP:HOO,QWHJULW\6SHFLDOLVW&3)Q#FRQRFRSKLOOLSVFRP! 6HQW:HGQHVGD\$XJXVW30 7R5HJJ-DPHV%2*&:DOODFH&KULV'2*&%URRNV3KRHEH/2*&'2$$2*&&3UXGKRH%D\ 6XEMHFW&3$,IRUPVIRU6,LQMHFWRUVRQ$XJ $WWDFKPHQWV0,7.5813$'6,7(676[OV[0,7.58/$6,7(67[OV[0,7.588 6,7(67[OV[ ůůͲWůĞĂƐĞƐĞĞƚŚĞϭϬͲϰϮϲĨŽƌŵƐĨŽƌƚŚĞƐŚƵƚŝŶ͕ŶŽŶͲǁŝƚŶĞƐƐĞĚD/dͲ/ƐƉĞƌĨŽƌŵĞĚŽŶϮƵŐϮϬϮϮ͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨ ǇŽƵŚĂǀĞĂŶǇƋƵĞƐƚŝŽŶƐŽƌĐŽŶĐĞƌŶƐ͘ 'XVW\)UHHERUQ :HOO,QWHJULW\6SHFLDOLVW &RQRFR3KLOOLSV$ODVND,QF 2IILFHSKRQH &HOOSKRQH &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH .581 37' Submit to: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2070900 Type Inj N Tubing 10 140 140 140 Type Test P Packer TVD 5004 BBL Pump 1.9 IA 85 1800 1750 1750 Interval 4 Test psi 1500 BBL Return 1.9 OA 0 0 0 0 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1981730 Type Inj N Tubing 1645 1650 1645 1645 Type Test P Packer TVD 4903 BBL Pump 2.4 IA 225 2510 2460 2440 Interval 4 Test psi 1500 BBL Return 1.7 OA 140 150 150 150 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1981170 Type Inj N Tubing 1460 1450 1450 1430 Type Test P Packer TVD 4770 BBL Pump 1.4 IA 360 2200 2140 2130 Interval 4 Test psi 1500 BBL Return 1.4 OA 240 430 430 430 Result P Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2011420 Type Inj N Tubing 650 650 650 650 Type Test P Packer TVD 4375 BBL Pump 2.1 IA 410 1800 1750 1740 Interval 4 Test psi 1500 BBL Return 2.1 OA 230 360 350 350 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c all In t eg r ityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: 2N-310 2N-321A 2N-348 Notes: 2N-331 Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 2N Pad N/A Hembree / Hills 08/02/22 Form 10-426 (Revised 01/2017)2022-0802_MIT_KRU_2N-pad_4wells 9 9 9 9 9 9 - 5HJJ 2N-310 ! 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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2N-310 (PTD 207-090) Report of surface casing leak Date:Monday, March 21, 2022 10:09:55 AM Attachments:AnnComm Surveillance TIO for 2N-310.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, March 21, 2022 9:57 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: KRU 2N-310 (PTD 207-090) Report of surface casing leak Chris, KRU 2N-310 (PTD 207-090) was reported by Operations to have had fluids come out of the conductor late on 3/18/22. DHD responded over the weekend by performing a SCLD and determining a surface casing leak at approximately five feet. The plan is to secure the well ASAP after which MITs will be performed to prove tubing and production casing integrity. The well will then be progressed toward a surface casing repair. A 90 day TIO trend and wellbore schematic are attached. Please let us know if you disagree or have any questions with the plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 2N-310 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2N-310 2022-03-19 1 1 0 OA 2N-310 2022-03-20 1 1 0 OA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 11,509.0 6/5/5021 2N-310 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag Depth. Pulled & Set Hold Open Sleeve 6/6/2021 2N-310 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 18.73 Top (ftKB) 31.0 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 Wt/Len (l… 133.00 Grade J-55 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 30.5 Set Depth (ftKB) 3,520.9 Set Depth (TVD) … 2,393.7 Wt/Len (l… 40.00 Grade L-80 Top Thread Buttress Thread Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 28.2 Set Depth (ftKB) 10,828.0 Set Depth (TVD) … 5,151.9 Wt/Len (l… 26.00 Grade L-80 Top Thread BTC Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 10,616.5 Set Depth (ftKB) 11,840.0 Set Depth (TVD) …Wt/Len (l… 12.60 Grade L-80 Top Thread IBT MOD Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,616.5 4,992.3 44.19 SBE BAKER 80-40 SEAL BORE EXTENSION 5.000 10,632.7 5,004.0 43.70 PACKER "HRD" ZXP LINER TOP PACKER 3.875 10,642.3 5,010.9 43.42 HANGER BAKER FLEX LOCK LINER HANGER 3.875 10,660.7 5,024.3 42.87 NIPPLE CAMCO DB-6 NIPPLER 3.750 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 26.0 Set Depth (ft… 10,627.3 Set Depth (TVD) (… 5,000.0 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 26.0 26.0 0.00 HANGER FMC Tubing Hanger w/ 2.66' Pup 3.958 2,201.6 1,919.2 61.68 SAFETY VLV 4.5" TRM-4PE-CF SSSV 3.813" DBProfile 1/4" SS line **BROKEN FLAPPER 9/4/2008** 3.813 10,526.9 4,929.4 46.70 SLEEVE "CMD" Sliding sleeve w/ 3.813" X-Profile 3.813 10,611.9 4,989.0 44.32 LOCATOR BAKER NO GO LOCATOR 3.958 10,612.9 4,989.7 44.29 SEAL ASSY Baker G-22 Locator seal assembly OD 4.94 ID 3.93 3.930 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 2,200.0 1,918.5 61.60 HOLD OPEN SLEEVE HOLD OPEN SLEEVE (NO SEALS) 10.3' OAL 6/7/2021 3.180 11,175. 0 5,423.5 33.65 PATCH WEATHERFORD ER PACKER, OAL 28.1', 4.5" FR PACKER, SPACER PIPE SNAP LATCH ASSY SET ON BOTTOM PACKER (OAL 61') 11/23/2008 2.250 11,530. 0 5,744.2 19.08 CMT PLUG CEMENT PLUG, PT TBING TO 3000 psi 2/28/2008 0.000 11,541. 0 5,754.6 19.26 SAND PLUG SAND PLUG 2/27/2008 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 11,185.0 11,205.0 5,431.9 5,448.7 CAIRN, 2N-310 4/4/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,272.0 11,348.0 5,506.3 5,573.7 BERMUDA, 2N- 310 3/11/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,358.0 11,410.0 5,582.8 5,631.0 BERMUDA, 2N- 310 3/9/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,436.0 11,446.0 5,655.4 5,664.8 BERMUDA, 2N- 310 3/9/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,670.0 11,690.0 5,875.9 5,894.7 ESKER, 2N-310 11/17/2007 6.0 IPERF 2.88" HSD PJ 2906 HMK, 60 Deg phase Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 11/25/2007 11,670.0 11,690.0 0.0 0.00 0.00 2 FRAC 4/6/2008 11,185.0 11,205.0 0.0 0.00 0.00 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,503.6 2,387.9 70.36 CAMCO KBG-2- 1R 1 Gas Lift DMY BK-5 0.000 0.0 12/27/2007 5:30 2 6,664.6 3,487.6 70.13 CAMCO KBG-2- 1R 1 Gas Lift DMY BK-5 0.000 0.0 12/27/2008 10:00 3 9,185.2 4,357.0 69.84 CAMCO KBG-2- 1R 1 Gas Lift DMY BK-5 0.000 0.0 9/24/2007 2:00 4 10,446.5 4,875.6 49.53 CAMCO KBG-2- 1R 1 GAS LIFT DMY BK 0.000 0.0 11/25/2008 12:00 Notes: General & Safety End Date Annotation 7/27/2008 NOTE: View Schematic w/ Alaska Schematic9.0 DEVIATED, 2N-310, 6/7/2021 8:37:14 AM Vertical schematic (actual) LINER; 10,616.5-11,840.0 FRAC; 11,670.0 IPERF; 11,670.0-11,690.0 SAND PLUG; 11,541.0 CMT PLUG; 11,530.0 APERF; 11,436.0-11,446.0 APERF; 11,358.0-11,410.0 APERF; 11,272.0-11,348.0 PATCH; 11,175.0 FRAC; 11,185.0 APERF; 11,185.0-11,205.0 INTERMEDIATE; 28.3-10,828.0 SEAL ASSY; 10,612.9 LOCATOR; 10,611.9 SLEEVE; 10,526.9 GAS LIFT; 10,446.5 GAS LIFT; 9,185.2 GAS LIFT; 6,664.6 SURFACE; 30.5-3,520.9 GAS LIFT; 3,503.6 HOLD OPEN SLEEVE; 2,200.0 SAFETY VLV; 2,201.6 CONDUCTOR; 31.0-110.0 HANGER; 26.0 KUP INJ KB-Grd (ft) 35.81 Rig Release Date 9/25/2007 2N-310 ... TD Act Btm (ftKB) 11,840.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032054900 Wellbore Status INJ Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBORE2N-310 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Ext Conductor ConocoPhillips Alaska, Inc.Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,840'feet 11,530'-11,541'feet true vertical 6,036'feet feet Effective Depth measured feet 11,175', 10,633'feet true vertical feet 5,424', 5,004'feet Perforation depth Measured depth 11,185'-11,690' feet True Vertical depth 5,432'-5,895' feet Tubing (size, grade, measured and true vertical depth)4 1/2" L-80 10,627' 5,000' Packers and SSSV (type, measured and true vertical depth)Weatherford ER MD-11,175' TVD-5,423' 4.5" TRM-4PE-CF MD- 2,201' TVD- 1,919' HRD ZXP LINER MD- 10,633' TVD- 5,004' 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: 8/25/2021 Contact Phone: 321-338 Authorized Name: Authorized Signature with date: Senior Engineer:Senior Res. Engineer: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283 WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Roger Mouser / Roger Winter n1927@conocophillips.com 659-7506 Well Integrity Field Supervisor NA NA NA NA NA NA NA NA NA NA N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Liner Production Conductor 79'20"110'110' Intermediate 10,800'7"10,828'5,152' Surface 3,490'9 5/8"3,521'2,394' Packer measured true vertical Casing Length Size MD TVD N/A Kuparuk River/Tarn Oil Plugs measured Junk measured Burst Collapse 207-090 50-029-20549-00-00 ADL0375074/ADL0380053 KRU TARN 2N 310 P.O. Box 100630, Anchorage, Alaska 99508 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name 4. Well Class Before Work:5. Permit to Drill Number: ntt e Fra O g g g l g y e 6. A y G L PG AAC 25 R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 6:49 pm, Aug 25, 2021 Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.08.25 14:52:13-08'00' Foxit PDF Editor Version: 11.0.0 Roger Winter VTL 9/9/21 DSR-8/26/21 RBDMS HEW 8/26/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 25 August 2021 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. Well KRU 2N-310 (PTD 207-090) conductor extension Sundry # 321-338. Summary: Conductor has been extended to cover surface casing Please contact Roger Winter or Roger Mouser at 659-7506 if you have any questions. Sincerely, Roger Winter Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.08.25 14:51:29-08'00' Foxit PDF Editor Version: 11.0.0 Roger Winter Date Event Summary Executive Summary Conductor extension 08/21/21 Prep conductor for extension 08/24/21 Weld extension on conductor Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 11,509.0 6/5/5021 2N-310 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag Depth. Pulled & Set Hold Open Sleeve 6/6/2021 2N-310 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 18.73 Top (ftKB) 31.0 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 Wt/Len (l… 133.00 Grade J-55 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 30.5 Set Depth (ftKB) 3,520.9 Set Depth (TVD) … 2,393.7 Wt/Len (l… 40.00 Grade L-80 Top Thread Buttress Thread Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 28.2 Set Depth (ftKB) 10,828.0 Set Depth (TVD) … 5,151.9 Wt/Len (l… 26.00 Grade L-80 Top Thread BTC Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 10,616.5 Set Depth (ftKB) 11,840.0 Set Depth (TVD) … Wt/Len (l… 12.60 Grade L-80 Top Thread IBT MOD Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,616.5 4,992.3 44.19 SBE BAKER 80-40 SEAL BORE EXTENSION 5.000 10,632.7 5,004.0 43.70 PACKER "HRD" ZXP LINER TOP PACKER 3.875 10,642.3 5,010.9 43.42 HANGER BAKER FLEX LOCK LINER HANGER 3.875 10,660.7 5,024.3 42.87 NIPPLE CAMCO DB-6 NIPPLER 3.750 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 26.0 Set Depth (ft… 10,627.3 Set Depth (TVD) (… 5,000.0 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 26.0 26.0 0.00 HANGER FMC Tubing Hanger w/ 2.66' Pup 3.958 2,201.6 1,919.2 61.68 SAFETY VLV 4.5" TRM-4PE-CF SSSV 3.813" DBProfile 1/4" SS line **BROKEN FLAPPER 9/4/2008** 3.813 10,526.9 4,929.4 46.70 SLEEVE "CMD" Sliding sleeve w/ 3.813" X-Profile 3.813 10,611.9 4,989.0 44.32 LOCATOR BAKER NO GO LOCATOR 3.958 10,612.9 4,989.7 44.29 SEAL ASSY Baker G-22 Locator seal assembly OD 4.94 ID 3.93 3.930 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 2,200.0 1,918.5 61.60 HOLD OPEN SLEEVE HOLD OPEN SLEEVE (NO SEALS) 10.3' OAL 6/7/2021 3.180 11,175. 0 5,423.5 33.65 PATCH WEATHERFORD ER PACKER, OAL 28.1', 4.5" FR PACKER, SPACER PIPE SNAP LATCH ASSY SET ON BOTTOM PACKER (OAL 61') 11/23/2008 2.250 11,530. 0 5,744.2 19.08 CMT PLUG CEMENT PLUG, PT TBING TO 3000 psi 2/28/2008 0.000 11,541. 0 5,754.6 19.26 SAND PLUG SAND PLUG 2/27/2008 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 11,185.0 11,205.0 5,431.9 5,448.7 CAIRN, 2N-310 4/4/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,272.0 11,348.0 5,506.3 5,573.7 BERMUDA, 2N- 310 3/11/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,358.0 11,410.0 5,582.8 5,631.0 BERMUDA, 2N- 310 3/9/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,436.0 11,446.0 5,655.4 5,664.8 BERMUDA, 2N- 310 3/9/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,670.0 11,690.0 5,875.9 5,894.7 ESKER, 2N-310 11/17/2007 6.0 IPERF 2.88" HSD PJ 2906 HMK, 60 Deg phase Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 11/25/2007 11,670.0 11,690.0 0.0 0.00 0.00 2 FRAC 4/6/2008 11,185.0 11,205.0 0.0 0.00 0.00 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,503.6 2,387.9 70.36 CAMCO KBG-2- 1R 1 Gas Lift DMY BK-5 0.000 0.0 12/27/2007 5:30 2 6,664.6 3,487.6 70.13 CAMCO KBG-2- 1R 1 Gas Lift DMY BK-5 0.000 0.0 12/27/2008 10:00 3 9,185.2 4,357.0 69.84 CAMCO KBG-2- 1R 1 Gas Lift DMY BK-5 0.000 0.0 9/24/2007 2:00 4 10,446.5 4,875.6 49.53 CAMCO KBG-2- 1R 1 GAS LIFT DMY BK 0.000 0.0 11/25/2008 12:00 Notes: General & Safety End Date Annotation 7/27/2008 NOTE: View Schematic w/ Alaska Schematic9.0 DEVIATED, 2N-310, 6/7/2021 8:37:14 AM Vertical schematic (actual) LINER; 10,616.5-11,840.0 FRAC; 11,670.0 IPERF; 11,670.0-11,690.0 SAND PLUG; 11,541.0 CMT PLUG; 11,530.0 APERF; 11,436.0-11,446.0 APERF; 11,358.0-11,410.0 APERF; 11,272.0-11,348.0 PATCH; 11,175.0 FRAC; 11,185.0 APERF; 11,185.0-11,205.0 INTERMEDIATE; 28.3-10,828.0 SEAL ASSY; 10,612.9 LOCATOR; 10,611.9 SLEEVE; 10,526.9 GAS LIFT; 10,446.5 GAS LIFT; 9,185.2 GAS LIFT; 6,664.6 SURFACE; 30.5-3,520.9 GAS LIFT; 3,503.6 HOLD OPEN SLEEVE; 2,200.0 SAFETY VLV; 2,201.6 CONDUCTOR; 31.0-110.0 HANGER; 26.0 KUP INJ KB-Grd (ft) 35.81 Rig Release Date 9/25/2007 2N-310 ... TD Act Btm (ftKB) 11,840.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032054900 Wellbore Status INJ Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBORE2N-310 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP 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?N/A Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 11180' Casing Collapse Conductor Surface Intermediate Packers and SSSV Type:PKR:Packers and SSSV MD (ft) and TVD (ft):PKR: PKR: HRD ZXP LINER Top PKR: MD 10633' TVD 5004' SSSV:SSSV: 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 Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:7/6/2021 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 659-7506 Weatherford ER 4.5" TRM-4PE-CF MD 11175' TVD 5423' MD 2202' TVD 1919' Size Authorized Signature: 7/20/2021 4 1/2" Perforation Depth MD (ft): L-80 COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): 5432'-5896' Perforation Depth TVD (ft):Tubing Size: 11185'-11690' Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0375074/ADL0380053 207-090 P.O. Box 100630, Anchorage, Alaska 99508 5010320549-0000 ConocoPhillips Alaska, Inc. KRU TARN 2N 310 Kuparuk River/Tarn Oil 6036' PRESENT WELL CONDITION SUMMARY 11530', 11541' Length TVD Burst 10627' MD 2394' 5152' 3521' 10800' 110'110' 10828' 79'20" 9 5/8" 7" 3491' Well Integrity Field Supervisor Roger Mouser / Roger Winter n1927@conocophillips.com m n P s 66 t y t _ c Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:41 pm, Jul 06, 2021 321-338 Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.07.06 13:21:02-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Winter SFD 7/6/2021 x SFD Ext conductor 10-404 DSR-7/6/21 50-029-20549-00-00 Photo document pre and post work VTL 7/14/21 JLC 7/14/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.14 12:46:11 -08'00' RBDMS HEW 7/14/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 06 July 2021 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. Well KRU 2N-310 (PTD 207-090) to extend conductor. Summary: Conductor has subsided or well has grown 7” or more so we would like to add conductor to cover the surface casing. Please contact Roger Winter or Roger Mouser at 659-7506 if you have any questions. Sincerely, Roger Winter Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.07.06 13:20:38-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Winter Conductor has subsided or well has grown 7” or more Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 11,509.0 6/5/5021 2N-310 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag Depth. Pulled & Set Hold Open Sleeve 6/6/2021 2N-310 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 18.73 Top (ftKB) 31.0 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 Wt/Len (l… 133.00 Grade J-55 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 30.5 Set Depth (ftKB) 3,520.9 Set Depth (TVD) … 2,393.7 Wt/Len (l… 40.00 Grade L-80 Top Thread Buttress Thread Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 28.2 Set Depth (ftKB) 10,828.0 Set Depth (TVD) … 5,151.9 Wt/Len (l… 26.00 Grade L-80 Top Thread BTC Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 10,616.5 Set Depth (ftKB) 11,840.0 Set Depth (TVD) … Wt/Len (l… 12.60 Grade L-80 Top Thread IBT MOD Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,616.5 4,992.3 44.19 SBE BAKER 80-40 SEAL BORE EXTENSION 5.000 10,632.7 5,004.0 43.70 PACKER "HRD" ZXP LINER TOP PACKER 3.875 10,642.3 5,010.9 43.42 HANGER BAKER FLEX LOCK LINER HANGER 3.875 10,660.7 5,024.3 42.87 NIPPLE CAMCO DB-6 NIPPLER 3.750 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 26.0 Set Depth (ft… 10,627.3 Set Depth (TVD) (… 5,000.0 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 26.0 26.0 0.00 HANGER FMC Tubing Hanger w/ 2.66' Pup 3.958 2,201.6 1,919.2 61.68 SAFETY VLV 4.5" TRM-4PE-CF SSSV 3.813" DBProfile 1/4" SS line **BROKEN FLAPPER 9/4/2008** 3.813 10,526.9 4,929.4 46.70 SLEEVE "CMD" Sliding sleeve w/ 3.813" X-Profile 3.813 10,611.9 4,989.0 44.32 LOCATOR BAKER NO GO LOCATOR 3.958 10,612.9 4,989.7 44.29 SEAL ASSY Baker G-22 Locator seal assembly OD 4.94 ID 3.93 3.930 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 2,200.0 1,918.5 61.60 HOLD OPEN SLEEVE HOLD OPEN SLEEVE (NO SEALS) 10.3' OAL 6/7/2021 3.180 11,175. 0 5,423.5 33.65 PATCH WEATHERFORD ER PACKER, OAL 28.1', 4.5" FR PACKER, SPACER PIPE SNAP LATCH ASSY SET ON BOTTOM PACKER (OAL 61') 11/23/2008 2.250 11,530. 0 5,744.2 19.08 CMT PLUG CEMENT PLUG, PT TBING TO 3000 psi 2/28/2008 0.000 11,541. 0 5,754.6 19.26 SAND PLUG SAND PLUG 2/27/2008 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 11,185.0 11,205.0 5,431.9 5,448.7 CAIRN, 2N-310 4/4/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,272.0 11,348.0 5,506.3 5,573.7 BERMUDA, 2N- 310 3/11/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,358.0 11,410.0 5,582.8 5,631.0 BERMUDA, 2N- 310 3/9/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,436.0 11,446.0 5,655.4 5,664.8 BERMUDA, 2N- 310 3/9/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,670.0 11,690.0 5,875.9 5,894.7 ESKER, 2N-310 11/17/2007 6.0 IPERF 2.88" HSD PJ 2906 HMK, 60 Deg phase Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 11/25/2007 11,670.0 11,690.0 0.0 0.00 0.00 2 FRAC 4/6/2008 11,185.0 11,205.0 0.0 0.00 0.00 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,503.6 2,387.9 70.36 CAMCO KBG-2- 1R 1 Gas Lift DMY BK-5 0.000 0.0 12/27/2007 5:30 2 6,664.6 3,487.6 70.13 CAMCO KBG-2- 1R 1 Gas Lift DMY BK-5 0.000 0.0 12/27/2008 10:00 3 9,185.2 4,357.0 69.84 CAMCO KBG-2- 1R 1 Gas Lift DMY BK-5 0.000 0.0 9/24/2007 2:00 4 10,446.5 4,875.6 49.53 CAMCO KBG-2- 1R 1 GAS LIFT DMY BK 0.000 0.0 11/25/2008 12:00 Notes: General & Safety End Date Annotation 7/27/2008 NOTE: View Schematic w/ Alaska Schematic9.0 DEVIATED, 2N-310, 6/7/2021 8:37:14 AM Vertical schematic (actual) LINER; 10,616.5-11,840.0 FRAC; 11,670.0 IPERF; 11,670.0-11,690.0 SAND PLUG; 11,541.0 CMT PLUG; 11,530.0 APERF; 11,436.0-11,446.0 APERF; 11,358.0-11,410.0 APERF; 11,272.0-11,348.0 PATCH; 11,175.0 FRAC; 11,185.0 APERF; 11,185.0-11,205.0 INTERMEDIATE; 28.3-10,828.0 SEAL ASSY; 10,612.9 LOCATOR; 10,611.9 SLEEVE; 10,526.9 GAS LIFT; 10,446.5 GAS LIFT; 9,185.2 GAS LIFT; 6,664.6 SURFACE; 30.5-3,520.9 GAS LIFT; 3,503.6 HOLD OPEN SLEEVE; 2,200.0 SAFETY VLV; 2,201.6 CONDUCTOR; 31.0-110.0 HANGER; 26.0 KUP INJ KB-Grd (ft) 35.81 Rig Release Date 9/25/2007 2N-310 ... TD Act Btm (ftKB) 11,840.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032054900 Wellbore Status INJ Max Angle & MD Incl (°) MD (ftKB) WELLNAME WELLBORE2N-310 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP ! " # $! % " "#&$' ( )$*"" +($ ,-(# . #/&$ 0& 1$$ " ## ! 2 -2 3 $ 4( 56 $7895 7 ( :(5 7 ( ;(5 7 , #( :( , #( ;( :5 7 5:(7'<5:(7 1*8=$$, " & 6 < ;< ;:(5 7;(5 7 ) ." !< ( >< ,- (# # *, ( + !< " &6 &$'(6 /;#(??? 6@? " #?&$' ! "$ ", " ( " #$ " #! $ & > : & 6" &&A:& =23 $ ,- 23 $ ;,(>3 # "::&&$, B,"::&&$ ( " " , ? , #, C 54807)/+%84 D 0& # ! # ! !# D 1+%)8+=E)0)%.*1=E .+1%*8=E*./%**/=E /08%/48= *%9)F 099)8) 1*8=)).= *%9)F /1*= <B (GH6< < , < < , < ; :%*,%"; ? 0F8188= .*48= ( :(5 7 81)1= ++)= 8= .+)= )8F 4%+91F 04= 6%18 8/)0=:( $9 I<9 +.8= ,6I 6I&6$(?"$, ;&$"::&&$ !"!# $!# )8")+)18 (6.188+. /1*= )80%848 >-88./8E E <44+8 +8%8.%)8+*4%88 " <E& ( ;(5 7 D +0**= +.8=E+*= %#%&%! !#$ ' #( 8= ).4*= ! ## !#%!$ D$ :(5 7 +*.)%+**4=E++8/%++0*=E++1.% +/.=E+/++%+//+=E+10+% +14+= <8/..=:(+88*=;( <0+=:(+*).=;( <)81=:(/..1=;( ;))8)=:(44=;( 8%*8. # .9)8)8 ) * +)*,-',-' * , ). By Samantha Carlisle at 11:52 am, Jun 03, 2021 321-279 Sayeed Abbas Digitally signed by Sayeed Abbas Date: 2021.06.03 11:05:07 -08'00' DSR-6/3/21DLB 06/09/2021 -00 DLB ; ADL0375074 VTL 6/9/21 DLB X 10-404 0 X dts 6/9/2021 JLC 6/10/2021 6/10/21Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.06.10 08:41:44 -08'00' RBDMS HEW 6/11/2021 ! "# $% & ## #' ( )*+ , ( - #% "# ( #' . #( / ( 0 #(% , #( (/ 1 2234 ( ) / ' / % )*+ . ## . # ( ( % 5# )*+ . . 0 - ( ( # ( #% " ' .. 67 )8 + ( ' ' &% ' "3) 9 : "# $ "! +)8 + Sayeed Abbas Digitally signed by Sayeed Abbas Date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ast Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: MANDREL ORIENTATION 3/6/2016 2N-310 pproven Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 18.73 Top (ftKB) 31.0 Set Depth (ftKB) 110.0 Set Depth (TVD) … 110.0 Wt/Len (l… 133.00 Grade J-55 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 30.5 Set Depth (ftKB) 3,520.9 Set Depth (TVD) … 2,393.7 Wt/Len (l… 40.00 Grade L-80 Top Thread Buttress Thread Casing Description INTERMEDIATE OD (in) 7 ID (in) 6.28 Top (ftKB) 28.2 Set Depth (ftKB) 10,828.0 Set Depth (TVD) … 5,151.9 Wt/Len (l… 26.00 Grade L-80 Top Thread BTC Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 10,616.5 Set Depth (ftKB) 11,840.0 Set Depth (TVD) … Wt/Len (l… 12.60 Grade L-80 Top Thread IBT MOD Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,616.5 4,992.3 44.19 SBE BAKER 80-40 SEAL BORE EXTENSION 5.000 10,632.7 5,004.0 43.70 PACKER "HRD" ZXP LINER TOP PACKER 3.875 10,642.3 5,010.9 43.42 HANGER BAKER FLEX LOCK LINER HANGER 3.875 10,660.7 5,024.3 42.87 NIPPLE CAMCO DB-6 NIPPLER 3.750 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 26.0 Set Depth (ft… 10,627.3 Set Depth (TVD) (… 5,000.0 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 26.0 26.0 0.00 HANGER FMC Tubing Hanger w/ 2.66' Pup 3.958 2,201.6 1,919.2 61.68 SAFETY VLV 4.5" TRM-4PE-CF SSSV 3.813" DBProfile 1/4" SS line **BROKEN FLAPPER 9/4/2008** 3.813 10,526.9 4,929.4 46.70 SLEEVE "CMD" Sliding sleeve w/ 3.813" X-Profile 3.813 10,611.9 4,989.0 44.32 LOCATOR BAKER NO GO LOCATOR 3.958 10,612.9 4,989.7 44.29 SEAL ASSY Baker G-22 Locator seal assembly OD 4.94 ID 3.93 3.930 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 2,201.6 1,919.2 61.68 SLEEVE DMY FRAC SLEEVE NO-GO (OAL 123.5") 12/27/2008 3.180 11,175. 0 5,423.5 33.65 PATCH WEATHERFORD ER PACKER, OAL 28.1', 4.5" FR PACKER, SPACER PIPE SNAP LATCH ASSY SET ON BOTTOM PACKER (OAL 61') 11/23/2008 2.250 11,530. 0 5,744.2 19.08 CMT PLUG CEMENT PLUG, PT TBING TO 3000 psi 2/28/2008 0.000 11,541. 0 5,754.6 19.26 SAND PLUG SAND PLUG 2/27/2008 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 11,185.0 11,205.0 5,431.9 5,448.7 CAIRN, 2N-310 4/4/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,272.0 11,348.0 5,506.3 5,573.7 BERMUDA, 2N- 310 3/11/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,358.0 11,410.0 5,582.8 5,631.0 BERMUDA, 2N- 310 3/9/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,436.0 11,446.0 5,655.4 5,664.8 BERMUDA, 2N- 310 3/9/2008 6.0 APERF 2-7/8" HSD 2906PJ, 60 deg random 11,670.0 11,690.0 5,875.9 5,894.7 ESKER, 2N-310 11/17/2007 6.0 IPERF 2.88" HSD PJ 2906 HMK, 60 Deg phase Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 11/25/2007 11,670.0 11,690.0 0.0 0.00 0.00 2 FRAC 4/6/2008 11,185.0 11,205.0 0.0 0.00 0.00 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,503.6 2,387.9 70.36 CAMCO KBG-2- 1R 1 Gas Lift DMY BK-5 0.000 0.0 12/27/2007 5:30 2 6,664.6 3,487.6 70.13 CAMCO KBG-2- 1R 1 Gas Lift DMY BK-5 0.000 0.0 12/27/2008 10:00 3 9,185.2 4,357.0 69.84 CAMCO KBG-2- 1R 1 Gas Lift DMY BK-5 0.000 0.0 9/24/2007 2:00 4 10,446.5 4,875.6 49.53 CAMCO KBG-2- 1R 1 GAS LIFT DMY BK 0.000 0.0 11/25/2008 12:00 Notes: General & Safety End Date Annotation 7/27/2008 NOTE: View Schematic w/ Alaska Schematic9.0 APERF; 11,436.0-11,446.0 APERF; 11,358.0-11,410.0 APERF; 11,272.0-11,348.0 PATCH; 11,175.0 APERF; 11,185.0-11,205.0 FRAC; 11,185.0 INTERMEDIATE; 28.3-10,828.0 GAS LIFT; 10,446.5 GAS LIFT; 9,185.2 GAS LIFT; 6,664.6 SURFACE; 30.5-3,520.9 GAS LIFT; 3,503.6 SLEEVE; 2,201.6 SAFETY VLV; 2,201.6 CONDUCTOR; 31.0-110.0 vqo • . 2,C��19� RECEIVED C MAR 2 2 20l6 WELL LOG TRANSMITTAL#903080915 AOG3 To: Alaska Oil and Gas Conservation Comm. March 11, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 995013/ 201(0 �g�ED + t �� tvl.K.BENDER ��11 x RE: Multi Finger Caliper: 2N-310 Run Date: 1/25/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-310 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20549-00 Multi Finger Caliper(Field Log) 1 color log 50-103-20549-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com MA"Li`/) Signed: Date: A Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~'~ _ ~~Q Well History File Identifier Organizing (done) o,.o,~a iuuuiumiuiu Reu.~~reaea mumir~~~iiiiii RESCAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: DIGI AL DATA Diskettes, No. ^ Other, No/Type: gY• Maria r.~ _ Date: `a" f ~ ,~ ~/D ~ Project Proofing gY; Maria Date: ~ ~.. ~ Q ti x ~ 30 = I O D on Scanning Prepara _ BY: Maria Date: ! ~,. ~ ' " / ~~ Production Scanning OVERSIZED (Scannable) ^ Maps: her Items Scann ble by a Large Scanner ~ (rJ' OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ lsl + ~ =TOTAL PAGES (Count does not include cover sheet) ' n /s/ V Stage 1 Page Count from Scanned File: -~~. (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: r a, I ~ ~s~ I Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO gY; Maria .Date: ~s~ IIIIIIIIIII his Dint unless rescanning is required. III III I Scanning is complete at t p canned II I II ~I II I I III I I III ReS gY; Maria Date: ~s~ Quality Checked III (VIII (~) IIII II Comments about thls file: 10/6/2005 Well History File Cover Page.doc • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 April 13,2011 a.O7 ~ ©q aN- 3!a Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: `' . A Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped November 11, 2001. The corrosion inhibitor /sealant was pumped February 17 and 18, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 4113/11 2M & 2N PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 2M -05 50103201680000 1920470 Surface NA 16" NA 2.5 2/17/2011 2M -06 50103201760000 1920770 Surface NA 19" NA 2.5 2/18/2011 2M -30 50103201800000 1920840 Surface NA 16" NA 4.25 2/17/2011 2N -303 50103203520000 2001690 26' 5.00 20" 11/8/2001 4.4 2/17/2011 2N -306 50103204900000 2040620 SF NA 24" NA 2 2/17/2011 2N -310 50103205490000 2070900 SF NA 28" NA 5.1 2/17/2011 2N -342 50103205470000 2070680 24" NA 24" NA 7 2/17/2011 • • Page 1 of 1 Regg, James B (DOA) From: Phillips, Jim (ASRC Energy Services) [Jim.Phillips@contractor.conocophillips.com] Sent: Wednesday, August 25, 2010 3:57 PM '~~C~~~~,~ IJ To: Regg, James B (DOA) (T(> ~ 7_ L~ tCl Subject: RE: State MITIA test results for 2N pad on 8/24/10 ~ ~ " Kr~ Z.~J - ~ I L? Follow Up Flag: Follow up Flag Status: Red Attachments: MIT KRU 2N Pad DRAFT.xIs Jim, I apologize for the mix up I am filling in for Brent this week and by mistake I did not double check the form before sending it off. Therefore I did not notice that it was showing 12 water injectors SI. I have attached the correct copy and again I am sorry about this mistake on my part. If you have any more questions please feel free to contact me. Jim Phillips Acting Problem Well Supervisor Email: N1617 @conocophillips.com Office: 659-7224 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, August 25, 2010 2:36 PM To: Phillips, )im (ASRC Energy Services) Subject: RE: State MITIA test results for 2N pad on 8/24/10 Why were all the wells SI except the gas injector? Jim Regg AOGCC r/ r ,~ .~~~~ : ~,,~ ~ t~ !11..1 w , ~ ~~, 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Phillips, Jim (ASRC Energy Services) [mailto:Jim.Phillips@contractor.conocophillips.com] Sent: Wednesday, August 25, 2010 8:57 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: State MITIA test results for 2N pad on 8/24/10 All, Attached is the MITIA tests for 2N pad that were waived by Chuck Shieve on 08/24/10. Jim Phillips Acting Problem Well Supervisor Email: N1617 @conocophillips.com Office: 659-7224 8/26/2010 Email to:jim.regg@alaska.gov; phoebe.brooks(~alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Inc. ~~n JJ ~Q c L' f ~ I/ FIELD /UNIT /PAD: Kuparuk /KRU / 2N DATE: 08/24/10 OPERATOR REP: Ives/Mouser AES AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Packer De th Pretest Initial 15 Min. 30 Min. Well 2N-302 T e In'. W ND 5,185' Tubin 1,860 1,860 1,860 1,860 Interval 4 P.T.D. 2011150 T etest P Test si 1500 Casin 1,210 2,540 2,520 2,520 P/F P Notes: OA 235 265 260 260 Well 2N-306 T e In'. W ND 5,174' Tubin 2,150 2,150 2,150 2,150 Interval 4 P.T.D. 2040620 T etest P Test si 1500 Casin 1,245 2,820 2,760 2,760 P/F P Notes: OA 375 550 520 520 Well 2N-307 T e In'. W ND 5,141' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 1990170 T etest P Test si 1500 Casin 810 2,180 2,150 2,150 P/F P Notes: OA 250 350 300 300 Well 2N-309 T e In'. W ND 5,042' Tubin 1,600 1,600 1,600 1,600 Interval 4 P.T.D. 1990210 T etest P Test si 1500 Casin 775 2,225 2,100 2,080 P/F P Notes: OA 300 365 340 340 Well 2N-310 T e In'. W ND 5,004' Tubin 1,550 1,550 1,550 1,550 Interval 4 P.T.D. 2070900 T e test P Test si 1500 Casin 440 2,30 2,25 2,250 PIF P Notes: OA 270 390 350 350 Well 2N-314 T e In'. W ND 5,046' Tubin 1,600 1,600 1,600 1,600 Interval 4 P.T.D. 2001930 T e test P Test si 1500 Casin 600 2,300 2,270 2,270 P/F P Notes: OA 225 240 240 240 Well 2N-321A T e In'. W ND 4,915' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 1981730 T e test P Test si 1500 Casin 575 2,280 2,250 2,250 P/F P Notes: OA 250 450 450 450 Well 2N-326 T e In'. W ND 4,821' Tubin 1,860 1,860 1,860 1,860 Interval 4 P.T.D. 2001550 T etest P Test si 1500 Casin 1,150 2,760 2,720 2,710 P/F P Notes: OA 360 460 460 460 Well 2N-331 T e In'. W ND 4,770' Tubin 1,460 1,460 1,460 1,460 Interval 4 P.T.D. 1981170 T etest P Test si 1500 Casin 460 2,200 2,150 2,150 P/F P Notes: OA 300 480 480 480 Well 2N-335 T e In'. W ND 4,966' Tubin 1,950 1,950 1,950 1,950 Interval 4 P.T.D. 1982040 T e test P Test si 1500 Casin 560 2,800 2,600 2,590 P/F P Notes: OA 200 430 430 430 Well 2N-343 T e In'. G ND 4,937' Tubin 3,350 3,350 3,350 3,350 Interval 4 P.T.D. 1980920 T e test P Test si 1500 Casin 850 2,780 2,630 2,620 P/F P Notes: OA 400 420 420 420 Well 2N-348 T e In'. W ND 4,374' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 2011420 T e test P Test si 1500 Casin 630 2,280 2,240 2,240 P/F P Notes: OA 190 320 320 320 Well 2N-349A T e In'. G ND 5,078' Tubin 1,625 1,625 1,625 1,625 Interval 4 P.T.D. 2001390 T e test P Test si 1500 Casin 280 2,320 2,250 2,250 PIF P Notes: OA 150 250 250 250 Well 2N-325 T e In'. W ND 5015' Tubin 1,975 1,975 1,975 1,975 Interval 4 P.T.D. 1981630 T e test P Test si 1500 Casin 750 2,675 2,630 2,630 P/F P Notes: OA 220 250 240 240 TYPEINJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Intemal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 2N Pad 08-24-10 Revisedl.xls ~ i ~~ -.. ,~ ~k •~~ ~ `_ ,l ,F _'~~ ,r~,~° 'e- ~r ~, i ~ ,~~- ~ 49 ~ h: ,. Nt,~ C --~ is-, MICROFILMED 6/30!2010 DO NOT PLACE. ANY NEW. MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc I ? !~ ~` ~~ DATA SUBMITTAL COMPLIANCE REPORT 9/24/2009 Permit to Drill 2070900 Well Name/No. KUPARUK RIV U TARN 2N-310 Operator CONOCOPHILLIPS ALASKA INC MD 11840 TVD 6036 Completion Date 11!17/2007 Completion Status 1-OIL REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res/Dens/Neutron, CBL, USIT Well Log Information: Log/ Electr Data Digital Dataset Log Log Run (data taken from Logs Portion of Master Well Data Maint interval OH / meamrmi rvumuer ryame Jt,a~c mcwa rv0 Sonic 2 Col 1 15567 Report: Final Well R >g Sonic 5 Col 1 D C 15567 See Notes 2 Col D C 15567 See Notes 2 Col D C 15567 See Notes 2 Col D C 15567 See Notes 2 Col D C 15567 See Notes 2 Col D C 15567 See Notes 2 Col D C 15567 See Notes 2 Col D C 15567 See Notes 2 Col i ~o Cement Evaluation 5 Col 1 JLdR JtUrJ ~+n Rcacwcu ~.vnuuc~~w 10800 11800 Open 10/19/2007 Sonic Scanner, MSIP, FMI, PPC, GR 16-Sept-2007 Open 10/23/2007 Final Well Report, Table of ~, Contents, Equip & Crew, Well Details, Geo Data, Pres/Form Strength, Drilling Data, Daily Reports , w/ LAS, PDF, DML graphics and data 10800 11800 Open 10/19/2007 Sonic Scanner, MSIP, FMI, PPC, GR 16-Sept-2007 80 11840 Open 10/23/2007 MD Formation Log 80 11840 Open 10/23/2007 TVD Formation Log 80 11840 Open 10/23/2007 MD LWD Conbo Log 80 11840 Open 10/23/2007 TVD LWD Conbo Log ~i 80 11840 Open 10/23/2007 MD Gas Ratio Log i 80 11840 Open 10/23/2007 TVD Gas Ratio Log 80 11840 Open 10/23/2007 MD Drilling Dynamics Log 80 11840 Open 10/23/2007 TVD Drilling Dynamics Log '~, 10490 11718 Case 11/9/2007 MCBL, GR, CCL, VDL 4- Nov-2007 Current Status WAGIN API No. 50-103-20549-00-00 DATA SUBMITTAL COMPLIANCE REPORT 9/24/2009 Permit to Drill 2070900 Well Name/No. KUPARUK RIV U TARN 2N-310 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20549-00-00 MD 11840 TVD 6036 Completion Date 11/17/2007 Completion Status 1-OIL Current Status WAGIN UIC Y ' og Pressure 2 Blu 1 10400 11738 Case 1119!2007 DDL, Pres, Temp, GR, CCL 30-Oct-2007 I ~ •!Lo g Perforation 5 Blu 11300 11680 Case 11/27/2007 Perf, SBHPS 17-Nov-2007 'i ~ trED D Asc Directional Survey 30 11840 Open 12/3/2007 .~pt Directional Survey 30 11840 Open 12/3/2007 ~I Rpt 15806 LIS Verification 171 11840 Open 12/28/2007 Lis Veri, RPD, RPS, FET, GR< ROP, NPHI, NCNT, RHOB,DRHO,FCNT C Lis 15806 Induction/Resistivity 171 11840 Open 12!28/2007 Lis Veri, RPD, RPS, FET, GR< ROP, NPHI, NCNT, ~ RHOB,DRHO,FCNT I ~g Sonic 5 Col 1 10800 11800 Open 1/22/2008 I Sonic Scanner, FMI, MSIP, PPC, GR 16-Sep-2007 ~ C Lis 15889 Formation Micro Ima 179 11808 Open 1/22/2008 LIS Veri, MAS, FMI ~~ Injection Profile 2 Blu 11000 11500 Case 4/9/2009 Injection Pro, Spin, Pres, ~ Temp, Gradio, WFL 21- Mar-2009 C Pds 17822 Injection Profile 11000 11500 Case 4/9/2009 Injection Pro, Spin, Pres, Temp, Gradio, WFL 21- Mar-2009 D C 18049 See Notes 0 0 Open 5/21/2009 EWR Logs in CGM, EMF ! and PDS grpahics ~~ Induction/Resistivity 25 Col 223 11840 Open 5/21/2009 MD DGR, EWR, CTN, ALD Log Induction/Resistivity 25 Col 223 6036 Open 5/21/2009 TVD DGR, EWR, CTN, ALD og 15567 See Notes 2 Col 80 11840 Open 10/23/2007 MD Formation Log Log 15567 See Notes 2 Col 80 11840 Open 10/23/2007 TVD Formation Log og 15567 See Notes 2 Col 80 11840 Open 10/23/2007 MD LWD Conbo Log Log 15567 See Notes 2 Col 80 11840 Open 10/23/2007 TVD LWD Conbo Log Log 15567 See Notes 2 Col 80 11840 Open 10/23/2007 MD Gas Ratio Log i~og 15567 See Notes 2 Col 80 11840 Open 10/23/2007 TVD Gas Ratio Log DATA SUBMITTAL COMPLIANCE REPORT 9/24/2009 Permit to Drill 2070900 Well Name/No. KUPARUK RIV U TARN 2N-310 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20549-00-00 MD 11840 TVD 6036 Completion Date 11/17/2007 Completion Status 1-OIL Current Status WAGIN UIC Y '~ 15567 See Notes 2 Col 80 11840 Open 10/23/2007 MD Drilling Dynamics Log ~ (/Log 15567 See Notes 2 Col 80 11840 Open 10/23/2007 TVD Drilling Dynamics Log Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? Y !1V' Analysis ~"1">"I~ Received? Daily History Received? l'~""' Formation Tops Comments: Date: Compliance Reviewed By: l 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: 2N-310 May 18, 2009 AK-MW-5033959 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 2N-310 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 50-103-20549-00 2" x 5" TVD TRIPLE COMBO Logs: 1 Color Log 50-103-20549-00 Digital Log Images 1 CD Rom 50-103-20549-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax:907-273-3535 Bryan Burinda@halliburton.com BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 b Date:~c~ ~~~~~ ~~st fir, (~~~ des. K~o~~r.~i~sicE~:~ l~~c~r Signed: ~~ ~ ~~,~~ ~~ ~ `~ a~g ~J 04/06/09 NO. 5151 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 36-02 AYS4-00050 INJECTION PROFILE ~ 03/23/09 1 1 1L-16 AYS4-00048 INJECTION PROFILE / t 03/21/09 1 1 1F-13 AYS4-00046 INJECTION PROFILE / - ~/ 03/19/09 1 1 2N-310 6148-00018 INJECTION PROFILE ~-v 03/21/09 1 1 2D-13 B14B-00017 PRODUCTION PROFILE / - 012 7~- 03/20/09 1 1 3B-05 AZCM-00013 INJECTION PROFILE ~ "~- p`~~ (~ ~ 03/29/09 1 1 2U-01 AYS4-00051 PRODUCTION PROFILE - p(~ aj 03/24/09 1 1 iC-131 AYS4-00047 INJECTION PROFILE ~ e _ ~' ~- 03/20/09 1 1 R Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. o ®. ~ ~ n ~ ems„ w~ !~- aw ~~~ ~~YJ~ °" `°" MAR ~ 3 2009 ~,/ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION~8Sk8 Oii c~ Gas COn~. ~ofrlfrl6ssiAr, REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Other Q ~~~~., Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ `~j~~F; Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: i{ ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 207-090 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20549-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 149' 2N-310 8. Property Designation: 10. Field/Pool(s): ADL 380053 Kuparuk River Field / Tarn. Oil Pool 11. Present Well Condition Summary: Total Depth measured 11840' feet true vertical 6036' feet Plugs (measured) 11530 Effective Depth measured 11530 feet Junk (measured) true vertical 5744 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 20" 110 110' SURFACE 3521' 9-5/8" 3521 2394' INTERMEDIATE 10828' 7" 10828 5152' LINER 1223' 4-1/2" 11840 6036' Perforation depth: Measured depth: 11185' - 11446'; 11670' - 11690' ~ ~ true vertical depth: 5432' - 5665'; 5876' - 5895' b1 ~~ ~- ~r ~~s - > ~~~~ Tubing (size, grade, and measured depth) 4-1/2", L-80, 10627.3' MD. ~~~ `~e~\~~~C,OU [ '~~ " ' y ~ ~1 v~ Packers &SSSV (type & measured depth) Packer = "HRD ZXP Pkr = 10633 SSSV = TRM-4PE-CF SSSV = 2202' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation Subsequent to operation 2301 1160 872 14. Attachments 15. Weil Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil^ Gas^ WAG^~ GINJ^ WINJ ^ WDSPL^ 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: 308-285 contact Bob Christensen/Darrell Humphrey Printed Name Ro . Ch ' Title NSK Prod Eng Specialist Signature hone: 659-7535 Date ~~~, ~~®~ Z ~Fl a~~ o ~ 2000 ll`~ Form 10-404 Revised Q4/~QO¢ •„ ~ Submit Original Only '~ ~ 2N-310 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/07/08 SET 4.5" WEATHERFORD ER PACKER AT 11208'. TAG TO VERIFY. 11 SET 4 1/2" WEATHERFORD ER PKR SPACER PIPE WITH SNAP LATCH ASSY (OAL=28' 8".MIN ID 2.25") ACROSS CAIRN PERFORATIONS. TOP OF UPPER PKR @ 11175' RKB 11/24/08 SET 4 1/2" ER TESTTOOL ON ER PKR @ 11175' RKB.T X I COMMUNICATING APPEARS CAIRN FORMATION ISOLATED.SET BAITED GR PULLING TOOL AS CATCHER ON ON TEST TOOL.PULL STA #4 OV.CIRCULATE INHIBITED SW WITH T X 1 F.P.CMIT FAILED. IN PROGRES 11/25/08 PERFORMED 30 MIN CMIT.PASSED.SET 1" DV @STA #4.PERFORMED 30 MIN MIT PASSED.30 MIN MITIA PASSED.PULLED ER PKR TESTTOOL.READY FOR BERMUDA INJECTION GAUGED TBG TO 3.84" TO 2202' RKB. SET DMY FRAC SLEEVE (3.79" OD/ 3.84" NO-GO/ MIN ID= 3.18"/ OAL= 123.5") @ 2202' RKB. DRIFTED SSSV WITH 2.82" SWAGE. NO PROBLEMS. READY FOR E-LINE. 01/26/09 BROUGHT WELL UP ON PRODUCED WATER INJECTION 02/02/09 PRE STATE WITNESSED MITIA -PASSED (ISW) 02/03/09 INITIAL STATE WITNESSED (JOHN CRISP) MITIA -PASSED (ISW) KUP 0 2N -310 ! ConocoPUllips Well Attributes Max Angle & MD TD In WeIIDOro API /UWI Fisld Name Well Status ProdAnJ Typo Incl ( ") MD (MB) Act Bit. (tti(S) 501032054900 TARN PARTICIPATING AREA PROD 11,840.0 ' Comment 1423 (ppm) Dab An notation End Date KB Grd (fl) Rig Release Date •• W.II Cont :DEVIAE - 1 1o.5e.42 AM SSSV: TROP 0 711/2008 Last WO: 35.81 9/25/2007 Well Ckinfa. DEVA Annotation Depth (flKB) End Dab Annotation End Date 4H ANG-� - Z Last Tag: 11495.0 9/15/2008 Rev Reason: SET FRAC SLEEVE 12/28/2008 Casin Strin s Casing Description String 0... String ID ... Top (flKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd _ _ _ _ _ _ CONDUCTOR 20 18.730 0.0 110.0 133.00 J - 55 asing Description String 0... String ID ... Top (flKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.835 0.0 3,520.9 2,393.7 40.00 L-80 Buttress Thread Casing Description String 0... String ID ... Top [III Set Depth if... Set Depth (TVD) ... String Wt... String ... String Top Thrd INTERMEDIATE 7 6.276 0.0 10,828.0 5,151.9 26.00 L-80 BTC 0 -110 Casing Description String 0... String ID ... Top (11I Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 4 1/2 3.958 10,616.5 11,840.0 12.60 L -80 IBT MOD Liner Details Top Depth (TVD) Top Incl Top (flKa) (flKB) V) Item Description Comment ID (in) 10,616.5 4,992.3 44.19 SBE 80-40 seal bore extention 5.000 10,632.7 5,004.1 43.70 PACKER "HRD" ZXP Packer 3.875 10,642.3 5,011.2 43.42 HANGER 4.5" 801 hanger pinned @ 2500 psi 3.958 10,660.7 5,024.5 42.87 NIPPLE 41/2" OB-6 nipple 3.750" profile 3.750 11,736.7 COLLAR Landing collar (BOT Type I w/ ceramic Insert) 3.958 11,768.5 5,968.7 19.28 COLLAR Float collar (Single Valve) 3.958 SSSV, 2,202 11,800.3 5,998.7 19.28 XO XO (41/2" IBTM B x 4 1/7' BTCM P) 3.958 SLEEVE, 2,202 1 1 Tubing Strings Tubing Description String 0... String ID -. Top (flKB) Set Depth (f... Sat Oepth (TVD) ... String Wt... String ... String Top Thrd TUBING 41/2 3.958 26.0 10,627.3 5,000.2 12.60 L-80 IBT Completion Details j Top Deptn { S !TVD) Top Incl Top JMKB) INKB) ( ") ibm Description Comment ID (In) 26.0 26.01 0.00 HANGER FMC Tubing Hanger w/ 2.66' Pup 3.958 2,201.6 1,918.4 61.68 SSSV 4.5" TRM-4PE -CF SSSV 3.813" DBProfile 1/4' SS line "BROKEN 3.813 FLAPPER 9/4/2008° GAS LIFT. 10,526.9 4,929.8 46.06 SLEEVE "CMD" Sliding sleeve w/ 3.813" X -Profile 3.958 3.504 10,611.9 4,989.0 44.32 BAKER NO GO BAKER NO GO 3.958 su u C J 10,612.9 4,989.7 44.29 SEAL ASS/ Baker G-22 Locator seal assembly OD 4.94 ID 3.93 3.930 er In Hole Wireline retrievable plugs, valves pumps, fish etc. Top Depth JTVD) Top III Top (INKS) tftKB) 19 Description Comment Run Date ID (In) 2,201.6 1,918.4 61.68 SLEEVE DMY FRAC SLEEVE NO-GO (DAL 123.5') 12/27/2008 3.180 11,175.0 PATCH WEATHERFORD ER PACKER, DAL 21 FR 11/23/2008 2.250 PACKER, SPACER PIPE SNAP LATCH ASSY SET ON BOTTOM PACKER (OAL 61') 11,530.0 CEMENT CEMENT PLUG, PT TBING TO 3000 psi 2/28/2008 0.000 PLUG 11,541.ul 1 SAND PLUG ISAND PLUG 2127 /2008 1 0.000 Perforations Shot GAS LIFT Top (TVD) Blm (TVD) Dan. 5,565 Top (MKS) Stm(flKS) (flKB) (flKB) Zone Data ph... Type Comment 11,185.0 11,205.0 CAIRN, 2N- 310 4/4/2008 6.0 APERF 2 -7/8" HSD 2906160 deg random 11,272.0 11,348.0 BERMUDA, 3111/2008 6.0 APERF 2 -7/8" HSD 2906160 deg random 214-310 11,358.0 11,410.0 BERMUDA, 3/9/2008 6.0 APERF 2 -7/8" HSD 290160 deg random 214-310 11,436.0 11,446.0 BERMUDA, 319/2008 6.0 APERF 2 -7/8" HSD 2906PJ, 60 deg random 214-310 11,670.0 11,690.0 ESKER, 214-310 11/17/2007 6.0 (PERF 2.88" HSD PJ 2906 HMK, 60 Deg GASLIFT, phase 9,185 - -- Stimulations & Treatments Bosom Min Top Max Btm � T.p..pl! I Depth GAS LIFT, Depth Depth (TVD) (TVD) 10 - (flKB) tftKB) (flKB) lflKBl Type Dab Comment 11,185.0 11,205.0 1 FRAC 4/6/2008 CAIRN FRAC, PUMP 44,115# CARBOLITE w/8 ppa SLEEVE, ON FORMATION 10.527 11,670.0 11,690.01 1 JFRAC 11/25 ESKER FRAC 158748# 16/20 CARBOLITE BAKER NO Notes: General & Safe G0. 10,612 End Data Annotation SEAL ASSY 7/27/2008 NOTE: VIEW SCHEMATIC w/9.0 10,613 Mandrel Details Top Depth Top Pont TERMEDIATE, (TVD) Incl OD Valw Latch Size TRO Run APERRF Stn Top(fll(B) lflKBl (`) Make Model (in Sery Type Type Ilnl (P-i) Run Data 11,1 11&11,205 1 3,503.6 2,387.9 70.36 CAMCO KBG -2 -1R 1 Gas Lift DMY BK -5 0 0.0 12/27/2007 FRAC, 11,105 PATCH, 11,175 2 6,664.6 3,487.6 70.13 CAMCO KBG2 -1 R 1 Gas Lift DMY BK -5 0 0.0 12/27/2008 11 ,272-11,340 • 3 9,185.2 4,357.0 69.84 CAMCO KBG -2 -1R 1 Gas Lift DMY BK -5 0 0.0 924/2007 11,36&ii 410 4 10,446.5 4,875.9 49.53 CAMCO KBG2 -1 R 1 Gas Lift OV BK 5116 0.0 4/13 APERF, 11,13&11,446 CEMENT PLUG, 11,530 SAID PLUG, 11,547 (PERF, 11,67D-11,I130 FRAC, 11,57D , LINER, 10,616 -11,"D TD, 111340 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 09, 2009 12:11 PM To: Guy Schwartz Subject: RE: KRU 2N -310 (207 -090) — AGAIN Guy, Has any injection occurred into the well? Our production report does not indicate so at least through the end of 2008. Thanks in advance. Tom From: Maunder, Thomas E (DOA) Sent: Monday, February 09, 2009 11:52 AM To: Guy Schwartz Subject: RE: KRU 2N -310 (207 -090) Guy, Thanks for the call. I checked the file. So far, there isn't anything regarding the "injection survey ". Not sure if you said it was still to be run. Enjoy the sun. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Monday, February 09, 2009 8:14 AM To: Guy Schwartz Subject: KRU 2N -310 (207 -090) Guy, I am belated reviewing the 404 submitted for the work accomplished on this well from late 2007 through late 2008. In the operations report, all which is reported when the various intervals are being tested is "FLOWBACK IN PROGRESS ". This is not sufficient information. Please submit more complete information regarding the testing of the specific intervals. Email is acceptable. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 2/9/2009 '= INTEGRITY 'REPORT ' � D_ F OPER 1ELD N _ C q1DC—ONZ �F_LL NUMBER. - LL DAT 2 - eTE TD: %V% BTD - Casing: Shoe WVC MD &S3 TVD; DV: 1?'M -_VD -7- A' (a Shoe '-a) 603(a T`Jr C P Q AkHD ner: Packer "M TVD; Set at: ko -Ole S e 5_0f and Perfs to X\at}S C'r'.A?� =CST 7 1NTEGRTTY - PART 11 Annulus Press Test: 7P 15 min 30 min Comments: �ECH.Alq7C, �L T-IqTEGRITY - PART 12 Cement Volumes Amt. _!.:;.ner Csz DV CmC - ,rol to cover perfs c_q_vNA�r_,A_ UWZ-%,S -1heoret TOC SIC It LA 10 Cement Bond Log (Yes or No) In AOGCC 'Wile CBL Evaluation, zone above perfs Production Log: Type Evaluation CONC.LUSTIONS ar t: art: 1 4': STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑✓ ; Other Alter Casing ❑ Pull Tubing ❑ Perforate New Pool Q Waiver ❑ Time Extension ❑ \h Change Approved Program ❑ Operat. Shutdown❑ Perforate ❑ Re -enter Suspended Well ❑ l 2. Operator Name: 4. Well Class Before W c t 5. Permit to Drill Number: ConocoPhlllipsAlaska, Inc. Development Exploratory ❑ 207 -090! 3. Address: Stratigraphic ` ❑ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20549 - 00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 30', 149' AMSL 2N -310 8. Property Designation: 10. Field /Pool(s): ADL 380053 Kuparuk River Field / Tarn Oil Pool 11. Present Well Condition Summary: Total Depth measured 11840' • feet true vertical 6036' feet Plugs (measured) 11530', 11541' Effective Depth measured 11737' feet Junk (measured) patch @ 11176- 11206' (� true vertical 5939' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 20" 110' 110' SURFACE 3491' 9 -5/8" 3521' 2394' INTERMEDIATE 10798' 7" 10828' 5152' LINER 1223' 4.5" 11840' 6036' Perforation depth: Measured depth: 11185'- 11205', 11272'- 11348', 11358'- 11410', 11436'- 11446', 11670'- 11690' true vertical depth: 5432'- 5449', 5507'- 5574', 5583'- 5631', 5655'- 5665', 5876' -5895' Tubing (size, grade, and measured depth) 4.5 ", L -80, 10627' MD. 4 Packers & SSSV (type & measured depth) BaKer HRD ZXP liner top pkr @ 10633 Camco TRM- 4PE -CF SSSV @ 2202' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 11185' 41205', 11670'- 11690' Cairn frac pumped 44115# carbolite w/8 ppa on formation, Treatment descriptions including volumes used and final pressure: Esker frac 158748# 16/20 carbolite 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure I Tu ing Pressure Prior to well operation SI -- Subsequent to operation SI -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ❑ Development ❑ Service 0 Daily P P Report of Well Operations _X 16. Well Status after work: Oil❑ Gas❑ WAGE . GINJ❑ WINJ ❑ WDSPL❑ 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. Exem � -ate Contact Guy Schwartz Printed Name Guy § Title Wells Group Engineer Signature Phone: 265 -6958 Date /.2-4- PreDared bv Sharon All i Drake 263 -4612 IGINAL Form 10- 4 Revised 04/2006 `� Stabmit Original Only Aa-� / ��` �, KUP • 2N -310 Conoc(?Pf Iiip5 Well Attribute -__ M ax Angl@& MD TO i�(8". (& W.,I,t a APVU WI Near. Nee well Status Prod /Inj Type Inel ( MD (flKB) Act Btm (HKB) 501032054900 ITARN PARTICIPATING AREA (PROD _ 11,840.0 4 9 C nt H2S (ppm) ;Date Annotation End Date KB -Grtl (H) Rig Release Data well C--`9: D wA Eo. - zN 310 1va2 osfi4o 3a PM... _ SSSV. IRDP I 0 7/1/2008 (Last WO. 3581 9/ 25/2007_ Schematc Actual Annotation !Depth(HKB) End Date jAnnotation End Date 1 Last I 11,495.0 1 9/15/2008 jRev Reason: SET TOP PACKER _ 1 2/4/20 0 8 4 - � CaSln� - Strings Casing Descnpt on String 0... String ID ... Top (HKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Third C. _._. __CONDUCTOR 20 18.730 0.0 110.0 133.00 J55 Casin - g Descri ption String 0... String ID ... 7op (HKB) Sat Depth (f... Set D pth (ND) ... String Wt... String ... SMng Top Thrd SURFACE 95/8 8.835 0.0 3,520.9 2,393.7 40.00 L - 80 Buttress Thread Casing Description String 0... String ID ... Top (111<13) Set Depifi (f... Set Depth (ND) .. String Wt... String ... String Top Thrd INTERMEDIATE 7 6.276 0.0 10,828.0 5,1519 26.00 L-80 BTC 0 -110 Casing Description String 0... String ID ... Top (ftKB) Set Depth if Set Depth (ND) .. String Wt_. String ... String Top Thi LINER 41/2 3.958 10,616.5 11,840.0 12.60 L -80 IBT MOD Liner Details Top Depth (ND) Top Inc/ 'i To lftKe) ( °I Item Description Comment ID in 10,616.5 4,992.3 44.19 SBE 8040 seal bore a #ention 5.000 10,632.7 5,004.1 43.70 PACKER "HRD" ZXP Packer 3.875 10,642.3 5,011.2 43.42 HANGER 45" 80 KSI hanger pinned @ 2500 psi -- 3.958 _ - - 10,660.7 5,024.5 42.87 NIPPLE 41/2" DB -6 nipple 3.750" profile 1750 11,736.7 COLLAR Landing collar (BOT Type I w/ ceramic insert) 3.958 11,768 -5 5,968.7 19.28 COLLAR Float collar (Single Valve) 3.958 -- SSSV, 2,202 - -- 11,800.3 5,998.7 19.28 XO XO (4 112" IBTM 8 x 4 112" BTCM P) -.. - 3.958 ! Tubing Strings Tubing Description I String 0... String ID ... Top (flKB) SN Depth (f... Set Depth (ND) ... String Wt... String ... String Top Third TUBING 41/2 3.958 26.0 10,627.3 5,000.2 12.60 L -80 IBT Completion Details Top Depth ..- _.,.__. (TVD) Top Inc/ Top (HKB) (�B) CI Nerri Daulplbn Commerd ID (in) 26.0 26.0 0.00 HANGER FMC Tiding Hanger w/ 2.66 Pup 3.958 2,201.6 1,918.4 61.68 SSSV 4.5" TRM4PE -CF SSSV 3.813" DBProfile 1/4" SS line - BROKEN 3.813 FLAPPER 91412008° GAS LIFT, _ _ _ _ _ 3 . 51 M 10,526.9 4,929.8 46.06 S LEEVE "CMD" Sliding sleeve w/ 3.813" X- Profile 3.958 SURFACE, 10,61179 4,989.0 44.32., BAKER NO GO BAKER NO GO 3.958 0 -3,821 _ 10,612.9 4,989.7 44 29 SEAL ASSY Baker G -22 Locator seal assembly OD 4.94 ID 3.93 3.930 Other In Hole flillifirell ne retrievable plugs, valves, pumps, fish etc. Top Depth i - • LrvOj Top Inel T ittKBI R ( °) _. -. Description_ _ Comment Run Date ID in 11.175.0 PATCH WEATHERFORD ER PACKER, OAL 28.1',4.5 FR 11123/2008 2.250 PACKER, SPACER PIPE SNAP LATCH ASSY SET ON BOTTOM PACKER (DAL 61') 11,530.0 CEMENT CEMENT PLUG, PT TBING TO 3000 psi =812008 0.000 PLUG 11,541.0 SAND PLUG S AND PLUG 2127/2008 0.000 Perforations _ Shot Top (TVD) Btm (ND) Dens GAS LIFT, T flKB Bhn -B (flKB) (HKB) Zone Data (sh... Comneat _ -. e _.. 11,185.0 11,205.0 CAIRN, 2N -310 M42008 6.0 APERF 2 -7/8" 8 HSD d 2906PJ, 60 deg random 11,272.0 11,348.0 BERMUDA 3/11 /2008 6.0 APERF 2 -7/8" HSD 2906PJ, 60 deg random 2N -310 11,358.0 11,410.0 BERMUDA 3FJ2008 6.0 APERF 2 -7/8" HSD 2906PJ, 60 deg random 2N -310 11,436.0 11,446.0 BERMUDA 3!9/2008 . - - 6.0 APERF 2 -71W HSO 2906PJ, 60 deg random 2N-310 11,670.0 11,690.0 ESKER, 2N -310 11/17/2007 - 6.0 IPERF 2.88" HSD PJ 2906 HMK, 60 Deg ! phase 9 - Stimulations saes Bottom Min Top Max Btm ToP Depth Depth Depth Depth (ND) (ND) (HKB) TWO nd GASLIFT, (flKB) (RKB) (flKB) _ __fie_....,___..____.._ Comm tows 11,785.0 11,205.0 FRAC 4/6/2008 CAIRN FRAC, PUMP 44,115 #CARBOUTE w/8 ppa ON FORMATION SLEEVE. "- 11,670.0 11,690.0 FRAC 11/25/2007 ESKER FRAC 158748# 16120 CAiWLITE 10,827 _ --__ -- _ Notes:_Ceneral Safety End Date AKER NO BA B 1 NO 7/27/2008 NOTE: VIEW SCHEMATIC w /9.0 SEAL ABBY, 10,613 Mandrel Details_ Top Depth Top NTERMEDIATE, (TVD) Incl OD Valve Latch Size TRO Run P10,828 Stn To KB (flKB) ( °) Make_ Model__ (in) Slim Typ Type ( °) (PS Run D Comm... APERF. -___ a6s11,2os 7 3,503.6 2,387.9 70.36 CAMCO KBG - 2 - 1R 1 Gas LIR DMY BK - 5 0 0.0 12127/2007 FRAC, 11,188 PATCH, 11,178 - ! 2 6,664.6 3,487.6 70.13 CAMCO KBG -2 -1R 1 Gas UR DMY BK -5 0 0.0 12/27!2008 APERF, - 11,272- 11,348 � - 3 9,185.2T 4,357.0 69.84 CAMCO KBG2 - 1R 1 Gas Lift DMY BK - 5 - 0 0.0 92412007 APERF, -- 4 1 ,446.5 4,875.9 49.53 CAMCO KBG•2 -1R 1 Gas Lift OV iBK 5/16 0.04!132008 11,358 - 11,410 APERF, CEMENT PLUG, 11,531, SAND PLUG, 1,541 11.690 FRAC, 11,650 FRAC, 11,870 uNER, 10.616 -118G0 \ TJ. 1900 DATE SUMMARY 2N -310 Well Work Summary • 10/11/07 TAGGED @ 11715' SLM. PULLED DCK @ 10447' RKB. IN PROGRESS. 10/12/07 SET DV @ 10447' RKB. MITIA 3500 PSI, GOOD. DRIFTED WITH 21'x 3.45" DUMMY GUN TO 11715' SLM (1250# P/U WGT). 10/20/07 HARD TAG AT 11753' CTMD, CIRCULATED CLEAN SEAWATER FROM TD TO 4000' CTMD, LEAVING WELL FREEZE PROTECTED FROM 4000' CTMD ( 2600' TVD) TO SURFACE WITH 60 BBLS OF 60/40 METH, TURN WELL OVER TO DSO ((IN PROGRESS)) 10/30/07 CBL ATTEMPTED TOOLS UNABLE TO FALL PAST 2350' MADE THREE DIFFERENT ATTEMPTS, RAN DEPTH DETERMINATION AND TAGGED TD AT 11740' (2552 PSIA / 153 DEGF) 11/4/07 JETTED TURING DOWN TO 4325 'CTMD TMD RETURNING GRAY COLORED MATERIAL LOGGED CEMENT BOND LOG USING SCHLUMBERGER MEMORY TOOLS. LOGGED 3 PASSES FROM 11737' UP TO 10500' CTMD. HELD 2800# ON TUBING WHEN LOGGING 2 OF THE 3 PASSES. MEMORY TOOLSTRING IN GOOD CONDITION AND RETURNED GOOD DATA. WELL FREEZE PROTECTED DOWN TO 4400' CTMD. 11/16/07 ATTEMPTED TO PERFORATE ESKER SAND_ TOOLS FELL TO 5100'- ABORTED SECOND ATTEMPT TO FALL DUE TO WORSENING WEATHER. PLANS INCLUDE SECURING MULTIPLE +2 -7/8" ROLLERS AND PERFORMING JOB TOMORROW. ((IN PROGRESS)) 11/17/07 PERFORATED ESKER SAND FROM 11670'- 11690' MD WITH 2.88" HSD, PJ2906, HMX, 6 SPF, 60 DEGREE PHASING (120 HOLES) WHP DROPPED TO 2000 PSI IN 5 MINUTES - WHP 600 PSI BACK AT SURFACE > STATIC BOTTOM HOLE PRESSURE SURVEY - 11680': 2578.1 PSIA / 154.3 DEGF, 10452': 2013.7 PSIA, 126.2 DEGF 11/18/07 TAGGED AT 11697' SLM. IN PROGRESS. 11/19/07 PULLED DV FROM 10447' RKB AND REPLACED WITH HES SIDE POCKET GAUGE. TESTED IA TO 3500 PSI, GOOD. ATTEMPTED SET FRAC SLEEVE IN SCSSSV. UNABLE TO WORK PAST RESTRICTION AT 299' SLM. GAUGED TBG TO 3.83" TO SCSSSV. IN PROGRESS. 11/20/07 BRUSH TUBING DOWN TO AND INCLUDING 2.81" PROFILE IN SCSSSV AT 2202' RKB. SET FRAC SLEEVE AT 2202' RKB. TIGHT SPOTS IN TUBING AT 299'. 395', 639', 1407 1560' 1687' AND 2081' SLM. JOB COMPLETE 11/25/07 FLOWBACK IN PROGRESS 11/25/07 Frac Stim Esker formation with a total of 158748# of 16/20 Carbolite 1122# left in WB 12 ' PPA on formation 2361 BBL of SW, with an average pressure of 4632 psi Frac pumped to completion. I SIP= 2074 psi, 5 min pressure = 1940 psi Antimony, Iridium, Scandium RA Tracer Pump during propped stages and B F. ( 75 Diesel FP in flush ) EST BHP =2291 PSI .38 psi /ftr JOB COMPLETED 11/26/07 FLOWBACK IN PROGRESS 11/26/07 Perform post frac fill clean out, Tagged fill @ 11379 CTMD, Cleaned out to hard tag of 11708 CTMD. Freeze protected well, Left S /I. 11/27/07 FLOWBACK IN PROGRESS 11/28/07 FLOWBACK IN PROGRESS 11/29/07 FLOWBACK IN PROGRESS 11/29/07 PULLED FRAC SLEEVE (ED 2202' RKB, RAN 3.65" CENT., MADE IT TO 9053' SLM, BAILER FULL OF FRAC SAND, IN PROGRESS. 11/30/07 FLOWBACK IN PROGRESS 12/1/07 FLOWBACK IN PROGRESS 12/1/07 BAILED ON FRAC SAND PLUG @ 9053' SLM, CLEANED OUT TO 9103' SLM, IN PROGRESS. 12/2/07 FLOWBACK IN PROGRESS 12/2/07 COSTS ONLY, UNIT(s) STBY ON LOCATION FOR WEATHER. 12/3/07 FLOWBACK IN PROGRESS 12/3/07 BAILED CARBOLITE (a7 9097' SLM TO 9125' SLM_EE i j0 936ZLSj M LDFN DUE TO WEATHER. IN PROGRESS. 12/4/07 FLOWBACK IN PROGRESS 12/5/07 FLOWBACK IN PROGRESS 12/5/07 JAILED HARD FRAC SAND f/ 9375' TO 9379' SLM JOB SUSPENDED FOR FCO 12/6/07 FLOWBACK IN PROGRESS . 2N -310 Well Work Summary 0 12/6/07 UTILIZED SLICK DIESEL AND DIESEL GEL TO CLEANOUT LIGHT FRAC AND FORMATION SAND FROM 9,395' TO PBTD 0- 11.730' CTMD MAINTAINED 1:1 RETURNS THROUGHOUT JOB. WELL LEFT FULL OF DIESEL. 12/7/07 FLOWBACK IN PROGRESS 12/8/07 FLOWBACK IN PROGRESS 12/9/07 FLOWBACK IN PROGRESS 12/9/07 BAILED FRAC SAND BRIDGE f/ 9106' TO 9126' SLM. PULLED DV @ 6665' RKB. CIRCULATED 135 BBL DSL DOWN TBG AND UP IA. SET OV @ 6665' RKB. NEED FLOW WELL TO CLEAN UP. 12/10/07 FLOWBACK IN PROGRESS 12/11/07 FLOWBACK IN PROGRESS 12/11/07 ATTEMPTED PULL OV @ 6665' RKB, NO SUCCESS. TOOLS FOULED WITH FINE FORMATION SAND. PULLED DV @ 3504' RKB. CIRCULATED 60 BBL DSL DOWN IA UP TBG. ATTEMPTED SET OV @ 3504' RKB, NO SUCCESS. IN PROGRESS. 12/12/07 FLOWBACK IN PROGRESS 12/12/07 VERIFIED OV SET @ 3504' RKB. COMPLETE. 12/13/07 FLOWBACK IN PROGRESS 12/14/07 FLOWBACK IN PROGRESS 12/15/07 FLOWBACK IN PROGRESS 12/16/07 FLOWBACK IN PROGRESS 12/17/07 FLOWBACK IN PROGRESS 12/18/07 FLOWBACK IN PROGRESS 12/19/07 FLOWBACK IN PROGRESS 12/19/07 CREW ARRIVED TO 1Y PAD TO MOVE UNIT TO 2N, WALK AROUND INSPECTION SHOWED TRAILER AXLE PROBLEMS RESULTING IN UNPLANNED MAINTENANCE 12/20/07 FLOWBACK IN PROGRESS 12/21/07 FLOWBACK IN PROGRESS 12/22/07 FLOWBACK IN PROGRESS 12/22/07 CTU 4 REMOVED ICE PLUG FROM TBG, 700' CTMD TO 2000' CTMD. PUMPED ADDITIONAL 40BBLS DIESEL DOWM TBG TO 3500' TVD, RETURN IN THE AM FOR FCO 12/23/07 FLOWBACK IN PROGRESS 12/23/07 REVERSE FCO DOWN TO 10500' CTMD MAKING RECIP PASSES ACROSS ALL GLM UTILIZING 50 BBLS DUOVIS AND 580 BBLS SLICK DIESEL, AVG. PUMP /RETURN RATE WAS 1.9 BBLS /MIN. WELL LEFT LOADED WITH DIESEL TO 10500' CTMD. TURN WELL OVER TO DSO TO REMAIN SHUT IN. READY FOR SLICKLINE 12/24/07 FLOWBACK IN PROGRESS 12/24/07 GAUGED TBG TO 3.80" & TAGGED CMU NIP (7 10661' RKB. SET 3.81" X -LOCK CATCHER SUB (X- LOCK,EQ SUB,EQ SUB & CAP/ OAL= 31.5 ") @ 10527' RKB. ( TO PUMP DWN TBG/ PERFS PLUGGED JOB IN PROGRESS. 12/25/07 FLOWBACK IN PROGRESS 12/25/07 PULLED SPG @ 10447' RKB. ATTEMPT TO SET 5/16" ORIFICE @ 10447. JOB IN PROGRESS. 12/26/07 FLOWBACK IN PROGRESS 12/26/07 ATTEMPT TO SET ORIFICE VLV @ 10447' RKB. JOB IN PROGRESS. 12/27/07 FLOWBACK IN PROGRESS 12/27/07 SET 5/6" ORIFICE VLV (a)- 10447' RK B. PULLED ORIFICE VLV'S FROM 6665' & 3504' RKB'S. REPLACED WITH DMY VLV'S. JOB IN PROGRESS. 12/28/07 FLOWBACK IN PROGRESS 12/28/0 PULLED CATCHER (D- 10527' RKB. TAG FILL @ 11430' SLM. EST 240' FILL ABOVE TOP PERFS. RECOVERED SAMPLE. JOB COMPLETE. 12/29/07 FLOWBACK IN PROGRESS 12/30/07 FLOWBACK IN PROGRESS 12/31/07 FLOWBACK IN PROGRESS 1/1/08 FLOWBACK IN PROGRESS 1/2/08 FLOWBACK IN PROGRESS 1/3/08 FLOWBACK IN PROGRESS 1/4/08 FLOWBACK IN PROGRESS 1/5/08 FLOWBACK IN PROGRESS • 2N -310 Well Work Summary • 1/6/08 FLOWBACK IN PROGRESS 1/6/08 Due to excessive snow in secondary containment compiled with -38 DEG cold weather prepared for restart in the AM after finally raising derrick at 1400 hours. 1/7/08 FLOWBACK IN PROGRESS 1/7/08 Cleaned heavy sand to 11,736.8' CTMD, (PBTD). Lifted well from 6,000' while POOH with 1,000 SCFPM. Pumped 521 BBLS enhanced with nitrogen. 480 BBLS returned. Well currently flowing through PTS for sample rates. 1/8/08 FLOWBACK IN PROGRESS 1/9/08 FLOWBACK IN PROGRESS 1/10/08 FLOWBACK IN PROGRESS 1/11/08 FLOWBACK IN PROGRESS 1/12/08 FLOWBACK IN PROGRESS 1/13/08 FLOWBACK IN PROGRESS 2/4/08 TAGGED @ 11700' SLM. LOGGED POST -FRAC TRACER SURVEY FROM 11700' TO 11170' SLM. VERIFIED GOOD DATA. COMPLETE. 2/26/08 SPENT HALF THE DAY GETTING ALL EQUIPMENT NEEDED TO LOCATION. REMAINDER OF DAY SPENT PRESSURE TESTING ASRC SURFACE EQUIPMENT TO 4000 PSI. FINALLY GOT TEST AT 17:30. DECIDE TO PUMP SAND PLUG IN AM. 2/27/08 LAY IN SAND PLUG WITH COIL FROM 11,715' TO 11,548'MD. TOTAL OF 1510# OF 6 PPG 20/40 SAND PUMPED. FREEZE PROTECT TUBING WITH DIESEL FROM 3000'CTM. NOTIFIED DSO OF WELL STATUS. READY FOR SLICKLINE TAG/ CEMENT DUMP. 2/28/08 T AGGED SAND PLUG 0 EST. 11541' RKB. MADE 3 RUNS WITH DUMP BAILER O CEMENT. COMPLETE., 3/3/08 TAGGED CMT TOP @ 11530' RKB; EST 9' CMT. TESTED TBG 3000 PSI, PASS DRIFTED TBG WITH 10' x 2 -1/8" WITH 2.865" CENT. READY FOR PERFs. 3/8/08 ROUNDTRIP TO /FROM DEADHORSE TO SECURE FIVE 20', FOUR 5', ONE 10', AND ONE T PERFORATING GUNS. GUNS ARE 2 -7/8" HSD LOADED 6 -SPF, 60 -DEG PHASING WITH POWERJET CHARGES. ((JOB IN PROGRESS)) 3/9/08 PERFORATED BERMUDA ZONE FROM 11436- 11446' MD, AND FROM 11384'- 11410' MD, WITH 2 -7/8" HSD, POWERJET 2906, HMX, 6 SPF, 60 DEGREE PHASING. ((JOB IN PROGRESS)) 3/10/08 PERFORATED BERMUDA ZONE FROM 11358'- 11384' MD, AND FROM 11322'- 11348 MD, WITH 2 -7/8" HSD, POWERJET 2906, HMX, 6 SPF, 60 DEGREE PHASING. ((JOB IN PROGRESS)) 3/11/08 PERFORATED BERMUDA ZONE FROM 11296- 11322' MD, AND FROM 11272'- 11296 MD, WITH 2 -7/8" HSD, POWERJET 2906, HMX, 6 SPF, 60 DEGREE PHASING. SHOT SECOND GUN AND LOGGED OFF. WHILE POOH AT 9000' EMERGENCY RELEASE SUB RELEASED- NO OVERPULL. THIRD GUN RUN ON ERS AND SUSPECT SOLDER BOBBIN DAMAGED AFTER SHOOTING AND BROKE WHILE POOH, RELEASING COLLETS. 1 -3/8" FISHING NECK OTIS #2 LOOKING UP. TOOLSTRING LENGTH 39.1'. 3/13/08 RETRIEVED COMPLETE 39.1'E-LINE TOOL STRING & PERF GUNS Cad 11483' SLM ** *ALL PARTS ACCOUNTED FOR * * *. JOB IN PROGRESS. 3/14/08 MEASURED BHP @ 11359' RKB 3162 psi (MID BERMUDA PERF'S). GRADIENT 3073 psi ESTABLISHED INJECTION RATE OF 1 BPM @ 1600 #. 2 BPM @ 1650 #. 10 BBLS DIESEL FOR EACH TEST. JOB COMPLETE. 3/18/08 GAUGED TO 3.725" TO 11,515' SLM, ATTEMPT TO SET GAUGES ON SLIP STOP @ 11,260' RKB, IN PROGRESS. 3/23/08 ATTEMPT TO SET GAUGES ON SLIP STOP, SET DOWN IN 3.75" DB -6 NIPPLE @ 10,661' RKB, LDFN, IN PROGRESS. 3/24/08 ATTEMPT TO SET HES GAUGES ON 4 1/2 SLIP STOP, SET DOWN IN DB NIPPLE @ 10,661 RKB AGAIN, RDMO TO REGROUP 3/25/08 SET HES QUARTZ GAUGES ON SLIPSTOP Q 11296' RKB. READY FOR WRP. 3/27/08 SET 3.69" WRP @ 11260' RKB. TESTED 3000 / 250 PSI, GOOD. DUMP BAILED_ LIME STONE ON WRP Cad 11260' RKB. IN PROGRESS. 3/28/08 DUMP BAILED 11' CaCO3 ON WRP AT 11260 RKB. READY FOR E -LINE. 3/30/08 CHASED CATCHER SUB TO 10540' SLM PULLED OV @ 10447' RKB. IN PROGRESS. 3/31/08 LOADED TBG & CSG WITH 280 BBL INHIB SW & DSL CAP. IN PROGRESS. . 2N -310 Well Work Summary • 4/1/08 SET DV AT 10447' RKB. TESTED TBG AND IA TO 3500 PSI FOR 15 MIN EACH, GOOD. DRIFT FOR E -LINE PERF TO 11300' SLM. READY FOR PERFORATING. 4/4/08 PERFORATED CAIRN INTERVAL 11185'- 11205 with 2 -7/8" HSD LOADED 6SPF, 60 DEGREE PHASING, PJ2906 OMEGA CHARGES (API PEN: 36 ", API ENT HOLE: 0.34 ") 4/5/08 SET 3.813" FRAC SLEEVE (OAL =70 ", MIN ID =2.5 ") IN SSSV @ 2202' RKB. GAUGED TREE / HANGER TO 2.90" FOR TREESAVER. READY FOR FRAC. 4/6/08 Pumped Cairn sand frac with 44115 #, 16/20 carbolite sand wit 8 PPA on formation using 578 bbls YF125ST Sea Water gel. Flushed to completion w/ 130 bbls SW and 40 bbls of diesel for freeze protect. 4/9/08 PERFORM N2 FCO, CLEANED OUT TO PLUG @ 11282 CTMD, GOOD RTNS THROUGHOUT. WELL IS FREEZE PROTECTED. 4/10/08 FLOWBACK IN PROGRESS 4/11/08 FLOWBACK IN PROGRESS 4/11/08 PULLED 3.813" FRAC SLEEVE FROM 2202' RKB.T POSSIBLE SAND BRIDGE @ 7013' SLM WITH 3" BAILER FULL OF FRAC AND FORMATION SAN 4/12/08 FLOWBACK IN PROGRESS 4/12/08 WORKED 3" BAILER TO 7350' SLM AND ABLE TO WORK 3.735" GAUGERING TO 7850' SLM WITH PUMP ASSIS. 4/13/08 FLOWBACK IN PROGRESS 4/13/08 WORK THROUGH SAND BRIDGES WITH 3.735" GAUGE RING TAG @ EST. 11221 RKB.PULLED DV F/ 10447' RKB, DISPLACED IA WITH 200 BBL'S DEISEL. SET 1" X 5/16" OV @ 10447' RKB BUT UNABLE TO BLEED IA. IN PROGRESS. 4/14/08 FLOWBACK IN PROGRESS 4/14/08 REPLACED 1" X 5/16" ORFICE VLV @ 10447' RKB W /SAME. DRAW DOWN IA GOOD READY FOR FLOWBACK TEST. 4/15/08 FLOWBACK IN PROGRESS 4/16/08 FLOWBACK IN PROGRESS 4/17/08 FLOWBACK IN PROGRESS 4/18/08 FLOWBACK IN PROGRESS 4/19/08 FLOWBACK IN PROGRESS 4/20/08 FLOWBACK IN PROGRESS 4/21/08 FLOWBACK IN PROGRESS 4/22/08 FLOWBACK IN PROGRESS 4/23/08 FLOWBACK IN PROGRESS 4/24/08 FLOWBACK IN PROGRESS 4/25/08 FLOWBACK IN PROGRESS 4/26/08 FLOWBACK IN PROGRESS 4/27/08 FLOWBACK IN PROGRESS 5/12/08 GUAGED TBG W/ 2.82" TO 10661' RKB, TAGGED @ 11217' SLM, SAMPLE OBTAINED, JOB COMPLETE. 6/9/08 June standby charges for 4 -1/2" DHSIT. 7/4/08 BEGIN FLOWBACK 7/4/08 TAGGED @ 11222' SLM, RECOVERED SAMPLE, OBTAIN SBHPS @ ( 11230', 2544 PSI) ( 11200', 2535 PSI ) ( 11100', 2509 PSI ) ( 10700', 9500', 2416 PSI ) ( 8250', 2237 PSI) 5250', 2102 PSI ) ( 2400', 1999 PSI) ( 1000', 1939 PSI ) RKB, JOB COMPLETE. 7/5/08 FLOWBACK IN PROGRESS 7/6/08 FLOWBACK IN PROGRESS 7/7/08 FLOWBACK IN PROGRESS 7/8/08 FLOWBACK IN PROGRESS 7/9/08 FLOWBACK IN PROGRESS 7/10/08 FLOWBACK IN PROGRESS 7/11/08 FLOWBACK IN PROGRESS 7/12/08 FLOWBACK IN PROGRESS 7/13/08 FLOWBACK IN PROGRESS 2N -310 Well Work Summary 7/13/08 GAUGE TBG TO 3.79" TO 10� RKB SET DHSIT ASSY (3.75" DB- LOCeb,X -EQ SUB (MIN ID= 2.10 "), & 4.5" DHSIT & GAUGES/ OAL OF LOCK & ASSY= 172 ') @ 10661' RKB ** *SIT WILL CLOSE @ 15:45 ON 7/25/08 & ATTEMPT TO OPEN @ 11:45 ON 8/12/08 * * *.` EQ PRONG @ Y -PAD. MIN LENGTH FROM LOCK TO WATERMELON= 21 ". JOB COMPLETE. 7/14/08 FLOWBACK IN PROGRESS 7/15/08 FLOWBACK IN PROGRESS 7/16/08 FLOWBACK IN PROGRESS 7/17/08 FLOWBACK IN PROGRESS 7/18/08 FLOWBACK IN PROGRESS 7/19/08 FLOWBACK IN PROGRESS 7/20/08 FLOWBACK IN PROGRESS 7/21/08 FLOWBACK IN PROGRESS 7/22/08 FLOWBACK IN PROGRESS 7/23/08 FLOWBACK IN PROGRESS 7/24/08 FLOWBACK IN PROGRESS 7/25/08 FLOWBACK IN PROGRESS 7/26/08 FLOWBACK IN PROGRESS 8/10/08 TAG ICE PL 7 2' LM. GAUGED TB T 2 " DOWN T ABLE TO PLUG @ 6 S G UG G O .85 O O 1223' SLM. PUMP DOWN TBG TAKING RETURNS UP IA. * *POSSIBLE BAD CHECK IN ORIFICE VLF[ 0 10446' RKB * *. JOB IN PROGRESS. 8/11/08 REMOVED HYDRATES FROM 1324' SLM. SCRAPED LIGHT PARAFFIN FROM 2338' SLM TO 2700' SLM. ENCOUNTERED OBSTRUCTION @ 2700' SLM. ABLE TO PUMP DOWN HOLE (POSSIBLY DHSIT). UNABLE TO GET CLEAR PICTURE WITH 2.79" OR 2.24" LIB. ATTEMPT TO RECOVER SAMPLE. OBSTRUCTION LEFT @ 3324' SLM. JOB IN PROGRESS. 8/13/08 PULLED EST & GAUGES @ 10661' RKB. TAGGED @ 11238' RKB, EST. 24' OF FILL ON WRP. BAILED FRAC SAND FROM 11238' TO 11246' RKB. IN PROGRESS 8/14/08 BAILED FRAC SAND FROM 11244' TO 11259' RKB. IN PROGRESS. 8/15/08 BAILED FRAC SAND FROM 11263' TO 11275' RKB. IN PROGRESS. 8/16/08 BAILED MINIMAL FILL OFF WRP @ 11275' RKB. CONFIRMED WRP WITH 3.60 LIB. PULLING TOOL PRESENTLY UNAVAILABLE. JOB SUSPENDED. 8/31/08 BAILED ON WRP @ 11260' RKB. IN PROGRESS 9/1/08 BAILED ON WRP @ 1260' RKB, HUNG UP UNDER SSSV @ 2202' RKB. CAME FREE WITH PUMP ASST. IN PROGRESS 9/2/08 DRIFTED TBG & TAGGED NO -GO W/ 3.832" DRIFT, EXERSIZED SSSV @ 2202' RKB W/ Z -5 (LOST CONTROLINE PRESSURE) UNABLE TO CATCH FLAPPER W/ BRUSH. IN PROGRESS 9/4/08 RAN SEVERAL FLAPPER CHECKERS DOWN TO TRSSSV @ 2202' RKB AND DETERMINED FLAPPER IS PARTIALLY CLOSED RAN 4.5 SLOT PERM TOOL IN ATTEMPT TO LOCK OPEN TRSSSV (NO CLEAR INDICATION TRSSSV LOCKED OPEN ). RAN FLAPPER CHECKER AND APPEARED TO BE OPEN. ATTEMPTED TO DRIFT THROUGH TRSSSV W/ 3.70 CENT AND SAT DOWN @ FLAPPER @ 2207' RKB. RAN TWO IMPRESSION BLOCKS W/ INCONCLUSIVE RESULTS. 9/9/08 FILMED DAMAGED TRM -4PE a- 2201' RKB WITH EXPRO MEMORY CAMERA__ 9/11/08 REVIEWED VIDEO OF BROKEN SSSV FLAPPER. TROUBLE SHOOT SSSV @ 2201' RKB WITH Z -5. RAN FULL BORE BRAIDED LINE BRUSH WHILE PUMPING TO MOVE FLAPPER. DRIFTED THROUGH SSSV WITH 3.67 SWAGE; TAPPED 3.76 SWAGE THROUGH THREE TIMES,THEN UNABLE TO GET BACK THROUGH. BRUSHED AGAIN AND BAILED FILL @ 11262' SLM. IN PROGRESS. 9/12/08 BAILED FILL @ 11263' SLM; MARKS ON BAILER CONFIRMED CONTACT WITH WRP. POSITIONED FLAPPER WITH TANDEM 3.67 SWAGES AND FULL BORE BRUSH. RAN 4• 1/2 WRP EQUALIZING SLEEVE TO 11263' SLM. TATTLE TAIL PINS BENT, NO PRESSURE CHANGES. IN PROGRESS. 9/13/08 MADE MULTIPLE RUNS WITH 3.221 MULE SHOE BELL GUIDE WITH TATTLE TAIL TO EQUALZE WRP @ 11263' SLM. TATTLE TAIL INDICATES WRP EQUALIZED IN PROGRESS. 9/14/08 CONFIRMED WRP @ 11263' SLM EQUALIZED. LATCHED WRP WITH MULESHOE PULLING TOOL; MOVED WRP UPHOLE TO 10640' SLM BEFORE GR SHEARED. WRP FELL BACK DOWNHOLE. IN PROGRESS. l 2N -310 Well Work Summary 9115/08 PULLED WRP (aD- 11280' SLMO-COVERED ALL PARTS). PULLED SLI &OP WITH GAUGES (a)- 11286' SLM. TAGGED FILL Q 11495' SLM. COMPLETE, 11/7/08 SET 4.5" WEATHERFORD ER PACKER AT 11208'. TAG TO VERIFY 11/23/08 SET 4 1/2" WEATHERFORD ER PKR SPACER PIPE WITH SNAP LATCH ASSY (OAL =28' 8 ",MIN ID 2.25 ") ACROSS CAIRN PERFORATIONS. TOP OF UPPER PKR @ 11 175' RKB 11/24/08 SET 4 1/2" ER TESTTOOL ON ER PKR @ 11175' RKB.T X I COMMUNICATIN APPEARS CAIRN FORMATION ISOLATED. BAITED GR PULLING TOOL AS CATCHER ON ON TEST TOOL.PULL STA #4 OV.CIRCULATE INHIBITED SW WITH T X I F.P.CMIT FAILED. IN PROGRESS. 11/25/08 PERFORMED 30 MIN CMIT.PASSED.SET 1" DV @ STA #4.PERFORMED 30 MIN MIT PASSED.30 MIN MITIA PASSED.PULLED ER PKR TESTTOOL FOR BERMUDA INJECTION Page 1 of/ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, October 23, 2008 10:26 AM To: 'Braun, Michael' Cc: Jackson, Darron B.; Schwartz, Guy L; CPF2 Prod Engrs; Rodgers, James T Subject: RE: Tarn 2N -310 (207 -090) Attachments: 1Y 05_RST_TEMP_OVERVIEW.pdf Thanks Michael. We will look forward to the logging information. FYI, I am including a copy of the document we received for a water flow log recently run in 1Y -05. This package presents the results neatly and cleanly. It is your /CPAIs choice how the information is presented, however there needs to be a statement assessing the isolation. Call or message with any questions. Tom Maunder, PE AOGCC From: Braun, Michael [mailto: Michael. Braun@conocophillips.com] Sent: Wednesday, October 22, 2008 4:46 PM To: Maunder, Thomas E (DOA) Cc: Jackson, Darron B.; Schwartz, Guy L; CPF2 Prod Engrs; Rodgers, James T Subject: Tarn 2N -310 (207 -090) Tom, ConocoPhillips as completed the analysis of the pressure data from the gauges below the mechanical plug that isolated the Cairn perforations from the Bermuda (a.k.a. "Tarn ") perforations. We are confident that the relatively small Cairn frac did not propagate down into the Bermuda nor establish communication between the two sands. I Our plan forward is to isolate the 20ft of Cairn perforations with a casing patch. We will run a leak detection log (LDL) and a water flow log (WFL) once water injection into the Bermuda starts to check the patch integrity and to check for out of zone injection. Please call or e-mail me if you have any questions. Michael Braun Drillsite Petroleum Engineer, Tarn Development ConocoPhillips Alaska ATO 1136 phone (907) 263 -4185 fax (907) 263 -4486 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, August 14, 2008 9:43 AM To: NSK Prod Engr Tech; Jackson, Darron B. Subject: Tarn 2N -310 (207 -090) 10/23/2008 2N -310 status • • Page 1 of 1 Maunder, Thomas E (DOA) From: Schwartz, Guy L [ Guy .L.Schwartz @conocophillips.com} Sent: Thursday, September 11, 2008 2:01 PM To: Maunder, Thomas E (DOA) Subject: 2N -310 status Tom, Couple of things: Item 1 - 2N -301 status.... We are fighting a SSSV flapper in this well in order to finish the conversion to water injection. Looks like the hinge broke so we are trying to push it aside in order to get our full ID drift back. Still have to pull a WRP plug and gauges, then check the pressure data and hopefully set a patch over the Caim perfs. Finally, then ready for injection in to Bermuda formation. Guy Schwartz Drilling and Wells Engineer office: 907 - 265-6958 Cell: 240 -5696 ATO -1512 guy.1.schwartz@conocophillips.com 9/11/2008 a Lj SARAH PAL/N, GOVERNOR ALASKA OIL A1VD GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Robert Christensen ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, 2N -310 Sundry Number: 308 -285 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by A may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cathy P. Foerster L Commissioner DATED this 'I day of August, 2008 Encl. �-4 - 0 4 Zj Robert Christensen Production Engineering Tech. Greater Kuparuk Unit, NSK -69 PO Box 196105 ConocoPhilfips Anchorage, 6 99519 -6105 Phone: (907)659 -7535 Fax: 659 -7314 August 12, 2008 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7 Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Maunder, ConocoPhillips Alaska, Inc. is requesting approval to covert Tarn 2N -310 (PTD 207 -090) from Oil production to Water Alternating Injection service. Enclosed you will find 10 -403 Application for Sundry Approval. If you have any questions regarding this matter, please contact Darron Jackson at 263- 4526. Sincerely, Robert D. Christensen Attachments � I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL to 20 AAC 25.280 1. Type of Request: Abandon ❑ Suspend ❑ Operational Shutdown ❑ Perforate ❑ Waiver ❑ Other ❑ Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ e approved program Oil to WAG Chan 9 pp p 9 ❑ Pull Tubing ❑ Perforate New Pool ❑ Re -enter Suspended Well ❑ Conversion 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ❑ 207 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20549 - 00' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑✓ 2N -310 - 9. Property Designation: it//� 10. KB Elevation (ft): 11. Field / Pool(s): ADL 380053 � 03�S0 i RKB 149' Kuparuk River Field / Tarn Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11840' - 6036' 11530' 5744' Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 20" 110' 110' SURFACE 3521' 9 -5/8" 3521' 2394' INTERMEDIATE 10828' 7" 10828' 5152' LINER 1223' 4-1/2" 11840' 6036' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11185' - 11446' 5432' 5665' 4 L - 80 10627.3' Packers and SSSV Type: Packers and SSSV MD (ft) Packer = "HRD" ZXP Pkr = 10633' SSSV = TRM- 4PE -CF SSSV = 2202' 13. Attachments: Description Summary of Proposal 1-11 14. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑� 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: August 31, 2008 Oil ❑ Gas ❑ Plugged ❑ Abandoned ❑ 17. Verbal Approval: Date: WAG ❑✓ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Darron Jackson Printed Name R ert D. g Njstensen Title: Supervisor DPE CPF2 Signature Phone: 263 -4526 Date < i� ©c ZS Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness L>/,O Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: Subsequent Form Required: � S SK AUG 2 iy 2008 APPROVED BY Q� Approved by: COMMISSIONER THE COMMISSION Date: .0 v U Form 11046 Revise 06/200 } 171� I rN ( t Submit in Duplicate ��AI 2N -310 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Tarn Well 2N -310 from an Oil Producer to a Water Alternating Gas Injection service well. 2N -310 was originally completed as a Tarn Oil Pool development well with exploration perforations in the underlying Esker and above Cairn formations. ConocoPhillips has completed its evaluation of the Cairn and Esker formations and has decided to, at this time, focus on Tarn Oil Pool injection service. The 10 -3/4" Surface casing ( 3521' and / 2394' tvd) was cemented with 571 sx AS Lite followed by 260 sx LiteCRETE. The 7 -5/8" Intermediate casing ( 10828' and / 5152' tvd) was cemented with 235 sx Class G. A CBL was obtained on November 4, 2007. The top of Tarn T -7 sand was found at 10678' and / 5037' tvd. The top of Esker sand was found at 11646' and / 5852' tvd. The Esker perforations ( 11670' - 11690' and / 5876' - 5895' tvd) have been plugged back as follows: 02/27/08 LAY IN SAND PLUG WITH COIL FROM 11,715' TO 11,548'MD. TOTAL OF 1510# OF 6 PPG 20/40 SAND PUMPED. FREEZE PROTECT TUBING WITH DIESEL FROM 3000'CTM. NOTIFIED DSO OF WELL STATUS. READY FOR SLICKLINE TAG/ CEMENT DUMP. 02/28108 TAGGED SAND PLUG @ EST. 11541' RKB. MADE 3 RUNS WITH DUMP BAILER OF CEMENT. COMPLETE. 03/03/08 TAGGED CMT TOP @ 11530' RKB; EST 9' CMT. TESTED TBG 3000 PSI, PASS. DRIFTED TBG WITH 10' x 2 -1/8" WITH 2.865" CENT. READY FOR PERFs. Prior to converting the well to injection service, a permanent straddle patch is planned to be run to isolate the Cairn perforations ( 11185'- 11205' and / 5432'- 5449' tvd ). KUP , 2N -310 ConocoP11ll1p5 Well Attributes ., API / UW I Field Name Well Statue Maximum Inclination ( °) Total Depth (ftKB) 5010320549 TARN PARTICIPATING PROD 71.19 11,840.0 Comment H2S (Ppm) Date Annotati... End Date KB -Ground Distance (ft) Rig Release Date 5 : DEVIATED - 214.310 8520061290OPM TRDP Last WO: 35.81 9/2512007 Schamatk -Adw Annotation Depth (RKB) End Date Annotation End Date - -- - - - - - - - -- - - - - Last Tag: 11,222.0 7/4/2008 Rev Reason: SHOW SAND PLUG, CEMENT PLUG 8/9/2008 HANGER, 26 Casing Strings Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ft... Set Depth (TVD) (ft... Wt (tha /... Grade Top Connection _________ _____ ---- _ __ CONDUCTOR 20 18.730 0.0 110.0 133.00 J -55 Casing Description OD (In) ID (in) Top (ftKB) Set Depth (ft... Set Depth (TVD) (R... Wt (lbsl... Grade Top Connection SURFACE 9 5/8 8.835 0.0 3,520.9 2,393.7 40.00 L-80 Buttress Thread Casing Description OD (In) ID (in) Top (RKB) Set Depth (R... Set Depth (TVD) (ft... Wt (lbs/... Grade Top Connection CONDUCTOR, INTERMEDIATE 7 6.276 0.0 10,828.0 5,151.9 26.00 L -80 BTC 0.110 Casing Description OD (In) ID (In) Tap (ftKB) Set Depth (ft... Set Depth (TVD) (ft... Wt (that... Grade Top Connection LINER 4 1l2 3.958 10,616.5 11,840.0 12.60 L -80 IBT MOD Liner Details Tap(ftKB) Item Description I Comment ID (in) 10,616.5 SEE 80-40 seal bore extention 3.958 10,632.7 PACKER "HRD" ZXP Packer 3.958 10,642.3 HANGER 4.5"80 KSI hanger pinned @ 2500 psi 3.958 10,660.7 NIPPLE 4 12" DB-6 nipple 3.750" profile 3.958 11,736.7 COLLAR Landing collar (BOT Type I w/ ceramic insert) 3.958 11,768.5 COLLAR Float collar (Single Valve) 3.958 11,800.3 XO XO (4 12" IBTM B x 4 12" BTCM P) 3.958 SSSV .2202 Tubing Strings Tubing Description 1 013(i n) 10 (in) Top (R... Set Depth (ftK... Set Depth (ND) (ftKB) Wt pbs /ft) Grade Top Connection TUBING 41/2 3.958 26.0 10,627.3 5,000.2 12.60 L-80 IBT Completion Details To RKB Item Description Comment ID In 26.0 HANGER FMC Tubing Hanger w/ 2.66' Pup 3.958 2,201.6 SSSV 4.5" TRM- 4PE-CF SSSV 3.813" DBProfile 1/4" SS line 3.813 10,526.9 SLEEVE "CMD" Sliding sleeve wl 3.813'X-Profile 3.958 10,611.9 BAKER NO GO BAKER NO GO 3.958 GAS LIFT, 10,612.9 SEAL ASSY Baker G-22 Locator seal assembly OD 4.94 ID 3.93 3.930 3,50/ Other In Hole (plugs eulp., Fish etc. SURFACE, L To (ftKB) Description Comment Run Date ID (In) x3.521 10,661.0 GAUGES 3.75" D &LOCK 8 DHSIT ASSY (DAL -172 ") 71122008 1.000 11,260.0 PLUG 3.69" WRP set 3282008 3/272008 11,296.0 GAUGES 4.5" SLIPSTOP w /HES GAUGES set 325/08 FOR 90 DAYS 3/25/2008 1.000 11,530.0 CEMENT PLUG CEMENT PLUG, PT TBING TO 3000 psi 228/2008 0.000 11,541.0 SAND PLUG SAND PLUG 2/272008 0.000 Perforations Top St. Shot Top Btm (TVD) (TVD) Dens _ (ftKB) _ (ftKB) I (ftKB) (ftKB) T Zone (alto- Date Comment 11,185.0 11,205.0 APERF CAIRN, 2N-310 6.0 414/2008 2 -7/8" HSO 2906PJ, 60 deg random 11,272.0 11,348.0 APERF BERMUDA, 6.0 3/11/2008 2 -7/8" HSD 2906PJ, 60 deg random T 2N -310 11,358.0 11,410.0 APERF BERMUDA, 6.0 3/9/2008 2 -7/8" HSD 2906PJ, 60 deg random GAS LIFT, 2N-310 6,665 11,436.0 11,446.0 APERF BERMUDA, 6.0 3/9/2008 2 -7/8" HSD 2906PJ, 60 deg random 2N-310 �-- \ ^\•�J�\ 11,670.0 11,690.0 IPERF ESKER, 214-310 6.0 111172007 2.88" HSD PJ 2906 HMK, 60 Deg phase Stimulations 8 Treatments Min Top Max Btm Depth (RKB) Depth (ftKB) Data i Type Comment v 11,670.0 11,690.0 11252007 FRAC ESKER FRAC 158748# 16120 CARBOLITE (( ,,�� v 11,185.0 11,205.0 4/62008 FRAC CAIRN FRAC, PUMP 44,115# CARBOLITE w/8 ppa ON FORMATION ut G V1'o f'k GAG LIFT, 1 9185 Notes: General & Safe End Date Annotation 71272008 NOTE: VIEW SCHEMATIC w /9.0 GAS LIFT, 10,446 SLEEVE, e 10,527 BAKER NO GO, 10,612 SEAL ASSY, 10,613 GAUGES, 10,661 TERMEOIATE, 0- 10,628 APERF, 11,1&5.11,205 P z6 ® Mandrel Details GAUGES, Set Depth Port 11,296 Top (TVD) Valve Latch Size TRO Run 11.2721,348 Stn (ftKB) (ftKB) Make Model OD in TYPe Type (In) (Psi) Run Date Comment APERF, 1 3,503.6 5,000.2 CAMCO KBG -2 -1R 1 DMY BKS 0 0.0 12/272007 11,35841,410 APERF, 2 6,664.6 5,000.2 CAMCO KBG -2 -1R 1 DMY BK -5 0 0.0 12/27/2008 11,43&11,446 CEMENT 3 9,185.2 5,000.2 CAMCO KBG -2 -1R i DMY BKS 0 0.0 9124/2007 PLUG, 11,530 SAND PLUG, 4 10 ,446.5 5,000.2 CAMCO KBG -2 -1 R 1 OV BK 5116 0.0 4113/2008 11,541 IPERF, 11.M11,690 -, FRAC, 11,670 LINER, 10,61&11,840 TD, 11,840 -+ I , C INTEGRITY REPORT' 4 UD ;�'. =� : �\ O� OPER � FIELD "C r 5�5� 5� ;;:_LL NUMBER 77J 7 W - ELL DAT L TD: �� . ?�.. � D ; = BTD Casing Shoe-. \4`6D!�S 5�� TVD j DV - T4-i in er . L A Shoe: =uoi_:g L '^\ k � Packer *� T Set at :Ole S�Le 45"' and (� ; Perfs to ECRA?q _C A-1. INTEGRITY - PART 1 nnulus Press Test: =? 15 min 5U min A Co =eats r ECHANICAL - INTEGRITY - PART # 2 � 3�y�5 �""�. W,. ' Cement Volumes- Amt. Liner ; Csg DV Cmt -rot to cover per =s a eoret:;.cal TOC CD Cement Bond Log (Yes or No) "\-- - ' In AOGCC Fil CBL Evaluation zone above perfs .. n T "'V8 Lat._O P Log- e i � 1 i I ' 3 CONC US I ONS : Part :l ?art T2: Page 1 of 2 • Maunder, Th E (DOA) From: Maunder Thomas E DOA Sent: Thursday, August 21, 2008 11:19 AM To: 'Schwartz, Guy L; Jackson, Darron B. Cc: Braun, Michael Subject: RE: Tarn 2N -310 (207 -090) Thanks Guy. As you know, Darron had sent me a summary of recent activity. I did not understand that the Bermuda perfs were already there, so I do understand why an internal pressure test will not be possible. It appears that you plan sufficient evaluations to determine that any injected fluids are confined to the intended zone. I will continue my review of the application. With regard to the 404, plan to only send 1 and include all the activities conducted in the well since completion. Call or message with any questions. Tom Maunder, PE AOGCC From: Schwartz, Guy L (mailto: Guy .L.Schwartz @conocophillips.com] Sent: Thursday, August 21, 2008 11:07 AM To: Jackson, Darron B.; Maunder, Thomas E (DOA) Cc: Braun, Michael Subject: RE: Tarn 2N -310 (207 -090) Tom, I made a hand sketch of what the well will look like when we are done... A Bermuda only injector. There is still a WRP and gauges (not shown) set between the Cairn and Bermuda. Once pulled we can determine if the Cairn frac breached down to the Tarn Bermuda Zone below it... We don't think it did but if so we would do cement squeeze before setting the permanent patch over the Cairn. As far as zonal isolation I think a standard IPROF will tell us if the patch is holding.... It would be hard to pressure test the patch unless we set an IBP below it temporarily (always some risk with those!!) . We still owe you a 10-404 once we get the Permanent Patch set too!! Take care, Guy Guy Schwartz Drilling and Wells Engineer office: 907 - 265 -6958 Cell: 240 -5696 ATO -1512 guy. l.schwartz@conocophillips.com From: Jackson, Darron B. Sent: Thursday, August 21, 2008 10:04 AM To: 'Maunder, Thomas E (DOA); NSK Prod Engr Tech 8/21/2008 Page 2 of 2 Cc: Braun, Michael; Schwartz, Guy L; Rodgers, James T; Targac, Gary Subject: RE: Tarn 2N -310 (207 -090) Mr. Maunder, As per our phone conversation, the attached file contains a more detailed history of the subject well as well as ConocoPhillips' plans are for the well. Please feel free to contact me if you have any additional questions or need additional information. Thanks for your help in this matter, Darron Jackson CPF2 DPE Supervisor North Slope Operations and Development ATO -1708 (907) 263 -4526 (w) (907) 632 -4434 (c) From: Maunder, Thomas E (DOA) (mailto:tom.maunder @alaska.gov] Sent: Thursday, August 14, 2008 9 :43 AM To: NSK Prod Engr Tech; Jackson, Darron B. Subject: Tarn 2N -310 (207 -090) Robert and Darron, I am reviewing the sundry application to convert this well to WAG. What will the Tam perforated interval be? Is it intended to conduct a wellbore pressure test after the straddle is placed over the Cairn perforations? Also, if there has been work conducted in the well since 5/12/08 a daily summary of those operations should be submitted. I look forward to your response. Call or message with any questions. Tom Maunder, PE AOGCC 8/21/2008 Conocc illips A61ska Calculations Chart Sub W Sheet nufter ;Z 310 taill� He Date L - 6 fie 4� ic 10 J b 4 4t - 4 - 14 1 —4-4 iY7 L 22 21 qq LL 5 6, 26 10 -- j L —4— z ------------ --- ---- --- A. 1� rt- Jp 7,6 �j 4 i'; Maunder, Thomas E (DOA) Ref.: Tarn 2N -310 (270 -090) MWAG Bermuda Sand Injector Well history overview: The Tarn well 2N -310 was drilled as a Bermuda Sand injector, but also tested 2 ILX targets: the older (deeper) Esker and the younger (shallower) Cairn. The Esker formation was tested dry in January 2008 and was isolated with a sand plug from bottom to 11541' MD and a cement plug up to 11530' MD. 3/3/2008: Tested cement plug with 3,000 psi. 3/9/2008: Perforated Bermuda zone from 11436- 11446' MD, and from 11384'- 11410' MD, with 2 -7/8" HSD, POWERJET 2906, HMX, 6 SPF, 60 deg phasing 3/14/2008: Measured Bermuda SBHP @ 11359' MD (mid perforations): 3,162 psis 3/25/2008: Set HES gauges on slipstop @ 11296' MD. (See comment on Cairn Frac 4/4/2008) 3/27/2008: Set 3.69" Wireline Retrievable Plug (WRP) @ 11260' MD (to isolate Bermuda perforations), tested with 3,000 psi + dump bailed 11' of CaCO3 on WRP 4/4/2008: Perforated Cairn zone from 11185'- 11205' with 2 -7/8" HSD 6SPF, 60 deg phasing, PJ2906 OMEGA charges. (The gauges set in front of the now isolated Bermuda perforations were set to record any possible crossflow between the Cairn and Bermuda. This includes any accidental frac'ing down into the Bermuda (frac communication). 4/6/2008: Hydraulic Fracture (Cairn) with 44115#, 16/20 Carbolite sand with 8 PPA on formation using 578 bbis YF125ST Sea Water gel. Flushed to completion w/ 130 bbls SW and 40 bbls of diesel for freeze protect. 4/9/2008: N2 assisted proppant cleanout + approx. 8 day Cairn Flowback (clean -up) 7/4/2008: Tagged fill @ 11222' MD (clean Cann perforations) + ran Static Pressure + Temperature Gradient: 2,536 psia 7/13/2008: Set Downhole Shut -In Tool (DHSIT) + 2 quartz gauges @ 10661' MD to record downlole pressure and temperature during Flow- After -Flow + Pressure Buildup. 7/15/2008: Initiated Flow- After -Flow test taking oil /condensate and gas samples at separator. 7125/2008: 10 day Pressure Build -Up starts. 8/11/2008: Cleaned hydrates in tubing 8/13/2008: Pulled DHSIT and gauges (the ones used to record the Cairn Flow -After -Flow + PBU test. The Bermuda gauges are still to be pulled and data analyzed). As of today (8/1912008): Waiting for tool to pull WRP that isolates the Bermuda. Then pull gauges and analyze i Plan forward: 1) Pull WRP + "Bermuda" gauges + analyze data. If the gauge data shows that the Cairn Frac hydraulically connected both (Cairn & Bermuda) reservoirs, then a cement squeeze (or better isolation technique) will be performed. 2) Set permanent Patch across the Cairn perforations 3) Begin injection into Bermuda and run Injection Profile (or Leak Detect Log) to ensure well integrity (no injection other than Bermuda Perfs), 2N -310 to INJ Page 1 of 1 Maunder, T E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, August 01, 2008 8:34 AM To: 'NSK Prod Engr Tech' Subject: RE: 2N -310 to INJ Yes Bob, you will need a 403. So many injection wells are pre - produced. Since the well will ultimately be an injector, it is important that the construction requirements for an injector be satisfied (bond log and MIT) but there isn't a problem completing the well as a producer. For longer pre - production periods, this helps make sure the production information is captured in the correct data base. Now that it is time to change to injector, the process requires a 403. 1 will look forward to receiving it. Tom From: NSK Prod Engr Tech [ mailto :n1139 @conocophillips.com] Sent: Friday, August 01, 2008 7:31 AM To: Maunder, Thomas E (DOA) Subject: 2N -310 to INJ Tom, I got word 2N -310 will be converted to injection well. Do we need to do a 10403 Sundry? I see the 401 has the "Service" box checked, but the 407 has it as an oil- development well class. Bob Buchholz / Bob Christensen Greater Kuparuk Area Production Engineering Technician Office (907) 659 -7535 NSK -69 Pager (907) 659 -7000 (924) 8/1/2008 2N -310 update Page 1 of 5 Maund Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, June 19, 2008 10:55 AM To: 'Schwartz, Guy L' Cc: Braun, Michael Subject: RE: 2N -310 update�� Thanks Guy. I will look forward to reviewing the testing /operations information on the work. Regards, Tom Maunder, PE AOGCC From: Schwartz, Guy L [mailto: Guy .L.Schwartz @conocophillips.com] Sent: Thursday, June 19, 2008 10:53 AM To: Maunder, Thomas E (DOA) Cc: Braun, Michael Subject: 2N -310 update Tom, I wanted to update you the status of this well. Seems like it is taking forever to finish the exploration testing of this well (Cairn zone is still left) . Lots of facility issues with flowing back the Cairn gas till some other projects are completed at CPF2. We finished testing the Esker, plugged it off and are now testing the Cairn. The Bermuda is perforated but is isolated from the Esker and Cairn. We have a pressure gauge hung off monitoring any interference from the other zones. Been holding off on the 10-404 till we actually finish the scope of the well and get in to it's final configuration as a Bermuda only injector. Summary: Cairn - perfed and fraced, some flowback data. ( still need to do a PBU with flowtest ... using a downhole shutin tool) Bermuda - perforated but haven't' injected or produced anything. Gauges on slipstop are hung to monitor pressure. Esker -perfed and frac'd. Flowtest is complete. Sanded back with a cement cap over it. Call me if you need some more info.... Have a good day. Guy I 6/19/2008 2N -310 update • 0 Page 2 of 5 Well History (2 year) 2N -310: 501032054900: 6/19/2008 Date Event 06/09/2008 June standby charges for 4 -1/2" DHSIT. 05/12/2008 GUAGED TBG W/ 2.82" TO 10661' RKB, TAGGED @ 11217' SLM, SAMPLE OBTAINED, JOB COMPLETE. 04/14/2008 REPLACED 1" X 5/16" ORFICE VLV @ 10447' RKB W /SAME. DRAW DOWN IA GOOD. READY FOR FLOWBACK TEST. 04/13/2008 WORK THROUGH SAND BRIDGES WITH 3.735" GAUGE RING TAG @ EST. 11221' RKB.PULLED DV F/ 10447' RKB, DISPLACED IA WITH 200 BBL'S DEISEL. SET 1" X 5/16" OV @ 10447' RKB BUT UNABLE TO BLEED IA. IN PROGRESS. 04/12/2008 WORKED 3" BAILER TO 7350' SLM AND ABLE TO WORK 3.735" GAUGERING TO 7850' SLM WITH PUMP ASSIS. 04/11/2008 PULLED 3.813" FRAC SLEEVE FROM 2202' RKB.TAGGED POSSIBLE SAND BRIDGE @ 7013' SLM WITH 3" BAILER FULL OF FRAC AND FORMATION SAND 04/09/2008 PERFORM N2 FCO, CLEANED OUT TO PLUG @ 11282 CTMD, GOOD RTNS THROUGHOUT. WELL IS FREEZE PROTECTED. 04/06/2008 Pumped Cairn sand frac with 44115 #, 16/20 carbolite sand with 8 PPA on formation using 578 bbls YF125ST Sea Water gel. Flushed to completion w/ 130 bbls SW and 40 bbls of diesel for freeze protect. 04/05/2008 SET 3.813" FRAC SLEEVE (OAL =70 ", MIN ID =2.5 ") IN SSSV @ 2202' RKB. GAUGED TREE / HANGER TO 2.90" FOR TREESAVER. READY FOR FRAC. 04/04/2008 PERFORATED CAIRN INTERVAL 11185' - 11205' with 2 -7/8" HSD LOADED 6SPF, 60 DEGREE PHASING, PJ2906 OMEGA CHARGES (API PEN: 36 ", API ENT HOLE: 0.34 ") 04/01/2008 SET DV AT 10447' RKB. TESTED TBG AND IA TO 3500 PSI FOR 15 MIN EACH, GOOD. DRIFT FOR E -LINE PERF TO 11 300' SLM. READY FOR PERFORATING. 03/31/2008 LOADED TBG & CSG WITH 280 BBL INHIB SW & DSL CAP. IN PROGRESS. 03/30/2008 CHASED CATCHER SUB TO 10540' SLM. PULLED OV @ 10447' RKB. IN PROGRESS. 03/28/2008 DUMP BAILED l l' CaCO3 ON WRP AT 11260 RKB. READY FOR E -LINE. 03/27/2008 SET 3.69" WRP @ 11260' RKB. TESTED 3000 / 250 PSI, GOOD. DUMP BAILED LIME STONE ON WRP @ 11260' RKB. IN PROGRESS. 03/25/2008 SET HES QUARTZ GAUGES ON SLIPSTOP @ 11296' RKB. READY FOR WRP. 03/24/2008 ATTEMPT TO SET HES GAUGES ON 4 1/2 SLIP STOP, SET DOWN IN DB NIPPLE @ 10,661 RKB AGAIN, RDMO TO REGROUP 03/23/2008 ATTEMPT TO SET GAUGES ON SLIP STOP, SET DOWN IN 3.75" DB -6 NIPPLE @ 10,661' RKB, LDFN, IN PROGRESS. 6/19/2008 2N -310 update Page 3 of 5 03/18/2008 GAUGED TO 3.725" TO 11,515' SLM, ATTEMPT TO SET GAUGES ON SLIP STOP @ 11,260' RKB, IN PROGRESS. 03/14/2008 MEASURED BHP @ 11359' RKB 3162 psi (MID BERMUDA PERF'S). GRADIENT 3073 psi ESTABLISHED INJECTION RATE OF 1BPM @ 1600#. 2 BPM @ 1650#. 10 BBLS DIESEL FOR EACH TEST. JOB COMPLETE. 03/13/2008 RETRIEVED COMPLETE 39.1'E-LINE TOOL STRING & PERF GUNS @ 11483' SLM. ** *ALL PARTS ACCOUNTED FOR * * *. JOB IN PROGRESS. 03/11/2008 PERFORATED BERMUDA ZONE FROM 11296' - 11322' MD, AND FROM 11272'- 11296' MD, WITH 2 -7/8" HSD, POWERJET 2906, HMX, 6 SPF, 60 DEGREE PHASING. SHOT SECOND GUN AND LOGGED OFF. WHILE POOH AT 9000' EMERGENCY RELEASE SUB RELEASED- NO OVERPULL. THIRD GUN RUN ON ERS AND SUSPECT SOLDER BOBBIN DAMAGED AFTER SHOOTING AND BROKE WHILE POOH, RELEASING COLLETS. 1 -3/8" FISHING NECK OTIS #2 LOOKING UP. TOOLSTRING LENGTH 39.1'. 03/10/2008 PERFORATED BERMUDA ZONE FROM 11358' - 11384' MD, AND FROM 11322'- 11348' MD, WITH 2 -7/8" HSD, POWERJET 2906, HMX, 6 SPF, 60 DEGREE PHASING. ((JOB IN PROGRESS)) 03/09/2008 PERFORATED BERMUDA ZONE FROM 11436' - 11446' MD, AND FROM 11384'- 11410' MD, WITH 2 -7/8" HSD, POWERJET 2906, HMX, 6 SPF, 60 DEGREE PHASING. ((JOB IN PROGRESS)) 03/08/2008 ROUNDTRIP TO/FROM DEADHORSE TO SECURE FIVE 20', FOUR 5', ONE 10', AND ONE 3' PERFORATING GUNS. GUNS ARE 2 -7/8" HSD LOADED 6 -SPF, 60 -DEG PHASING WITH POWERJET CHARGES. ((JOB IN PROGRESS)) 03/03/2008 TAGGED CMT TOP @ 11530' RKB; EST 9' CMT. TESTED TBG 3000 PSI, PASS. DRIFTED TBG WITH 10'x 2 -1/8" WITH 2.865" CENT. READY FOR PERFs. 02/28/2008 TAGGED SAND PLUG @ EST. 11541' RKB. MADE 3 RUNS WITH DUMP BAILER OF CEMENT. COMPLETE. 02/27/2008 LAY IN SAND PLUG WITH COIL FROM 11,715' TO 11,548'MD. TOTAL OF 1510# OF 6 PPG 20/40 SAND PUMPED. FREEZE PROTECT TUBING WITH DIESEL FROM 3000'CTM. NOTIFIED DSO OF WELL STATUS. READY FOR SLICKLINE TAG/ CEMENT DUMP. 02/26/2008 SPENT HALF THE DAY GETTING ALL EQUIPMENT NEEDED TO LOCATION. REMAINDER OF DAY SPENT PRESSURE TESTING ASRC SURFACE EQUIPMENT TO 4000 PSI. FINALLY GOT TEST AT 17:30. DECIDE TO PUMP SAND PLUG IN AM. 02/04/2008 TAGGED @ 11700' SLM. LOGGED POST -FRAC TRACER SURVEY FROM 11700' TO 11 170' SLM. VERIFIED GOOD DATA. COMPLETE. 01/07/2008 Cleaned heavy sand to 11,736.8' CTMD, (PBTD). Lifted well from 6,000' while POOH with 1,000 SCFPM. Pumped 521 BBLS enhanced with nitrogen. 480 BBLS returned. Well currently flowing through PTS for sample rates. 01/06/2008 Due to excessive snow in secondary containment compiled with -38 DEG cold weather prepared for restart in the AM after finally raising derrick at 1400 hours. 12/28/2007 PULLED CATCHER @ 10527' RKB. TAG FILL @ 11430' SLM. EST 240' FILL ABOVE TOP PERFS. RECOVERED SAMPLE. JOB COMPLETE. 12/27/2007 SET 5/6" ORIFICE VLV @ 10447' RKB. PULLED ORIFICE VLV'S FROM 6665'& 3504' RKB'S. REPLACED WITH DMY VLV'S. JOB IN PROGRESS. 6/19/2008 2N -310 update • • Page 4 of 5 12/26/2007 ATTEMPT TO SET ORIFICE VLV @ 10447' RKB. JOB IN PROGRESS. 12/25/2007 PULLED SPG @ 10447' RKB. ATTEMPT TO SET 5/16" ORIFICE @ 10447. JOB IN PROGRESS. 12/24/2007 GAUGED TBG TO 3.80" & TAGGED CMU NIP @ 10661' RKB. SET 3.81" X -LOCK CATCHER SUB (X- LOCK,EQ SUB,EQ SUB & CAP/ OAL= 31.5 ") @ 10527' RKB. ( ** *UNABLE TO PUMP DWN TBG/ PERFS PLUGGED * * *). JOB IN PROGRESS. 12/23/2007 REVERSE FCO DOWN TO 10500' CTMD MAKING RECIP PASSES ACROSS ALL GLM UTILIZING 50 BBLS DUOVIS AND 580 BBLS SLICK DIESEL, AVG. PUMP/RETURN RATE WAS 1.9 BBLS/MIN. WELL LEFT LOADED WITH DIESEL TO 10500' CTMD. TURN WELL OVER TO DSO TO REMAIN SHUT IN. READY FOR SLICKLINE 12/22/2007 CTU 4 REMOVED ICE PLUG FROM TBG, 700' CTMD TO 2000' CTMD, PUMPED ADDITIONAL 40BBLS DIESEL DOWM TBG TO 3500' TVD, RETURN IN THE AM FOR FCO 12/19/2007 CREW ARRIVED TO lY PAD TO MOVE UNIT TO 2N, WALK AROUND INSPECTION SHOWED TRAILER AXLE PROBLEMS RESULTING IN UNPLANNED MAINTENANCE 12/12/2007 VERIFIED OV SET @ 3504' RKB. COMPLETE. 12/11/2007 ATTEMPTED PULL OV @ 6665' RKB, NO SUCCESS. TOOLS FOULED WITH FINE FORMATION SAND. PULLED DV @ 3504' RKB. CIRCULATED 60 BBL DSL DOWN IA UP TBG. ATTEMPTED SET OV @ 3504' RKB, NO SUCCESS. IN PROGRESS. 12/09/2007 BAILED FRAC SAND BRIDGE f/ 9106' TO 9126' SLM. PULLED DV @ 6665' RKB. CIRCULATED 135 BBL DSL DOWN TBG AND UP IA. SET OV @ 6665' RKB. NEED FLOW WELL TO CLEAN UP. 12/06/2007 UTILIZED SLICK DIESEL AND DIESEL GEL TO CLEANOUT LIGHT FRAC AND FORMATION SAND FROM 9,395' TO PBTD @ 11,730' CTMD. MAINTAINED 1:1 RETURNS THROUGHOUT JOB. WELL LEFT FULL OF DIESEL. 12/05/2007 BAILED HARD FRAC SAND f/ 9375' TO 9379' SLM. JOB SUSPENDED FOR FCO. 12/03/2007 BAILED CARBOLITE @ 9097' SLM TO 9125' SLM, FELL TO 9367' SLM. LDFN DUE TO WEATHER. IN PROGRESS. 12/02/2007 COSTS ONLY, UNIT(s) STBY ON LOCATION FOR WEATHER. 12/01/2007 BAILED ON FRAC SAND PLUG @ 9053' SLM, CLEANED OUT TO 9103' SLM, IN PROGRESS. 11/29/2007 PULLED FRAC SLEEVE @ 2202' RKB, RAN 3.65" CENT., MADE IT TO 9053' SLM, BAILER FULL OF FRAC SAND, IN PROGRESS. 11/26/2007 Perform post frac fill clean out, Tagged fill @ 11379 CTMD, Cleaned out to hard tag of 11708 CTMD. Freeze protected well, Left S/I. 11/25/2007 Frac Stim Esker formation with a total of 158748# of 16/20 Carbolite 1122# left in WB 12 PPA on formation 2361 BBL of SW, with an average pressure of 4632 psi. Frac pumped to completion. ISIP= 2074 psi, 5 min pressure =1940 psi. Antimony, Iridium, Scandium RA Tracer Pump during propped stages and BF. ( 75 Diesel FP in flush) EST BHP =2291 PSI .38 psi/ftr JOB COMPLETED 11/20/2007 BRUSH TUBING DOWN TO AND INCLUDING 2.81" PROFILE IN SCSSSV AT 2202' RKB. SET FRAC SLEEVE AT 2202' RKB. TIGHT SPOTS IN TUBING AT 299', 395', 639, 1407', 1560', 1687' AND 2081' SLM. JOB COMPLETE. 6/19/2008 2N -310 update i i Page 5 of 5 11/19/2007 PULLED DV FROM 10447' RKB AND REPLACED WITH HES SIDE POCKET GAUGE. TESTED IA TO 3500 PSI, GOOD. ATTEMPTED SET FRAC SLEEVE IN SCSSSV. UNABLE TO WORK PAST RESTRICTION AT 299' SLM. GAUGED TBG TO 3.83" TO SCSSSV. IN PROGRESS. 11/18/2007 TAGGED AT 11697' SLM. IN PROGRESS. 11/17/2007 PERFORATED ESKER SAND FROM 11670' - 11690' MD WITH 2.88 HSD, PJ2906, HMX, 6 SPF, 60 DEGREE PHASING (120 HOLES) WHP DROPPED TO 2000 PSI IN 5 MINUTES - WHP 600 PSI BACK AT SURFACE > STATIC BOTTOM HOLE PRESSURE SURVEY - 11680 2578.1 PSIA / 154.3 DEGF , 10452': 2013.7 PSIA, 126.2 DEGF 11/16/2007 ATTEMPTED TO PERFORATE ESKER SAND, TOOLS FELL TO 5100'- ABORTED SECOND ATTEMPT TO FALL DUE TO WORSENING WEATHER. PLANS INCLUDE SECURING MULTIPLE +2 -7/8" ROLLERS AND PERFORMING JOB TOMORROW. ((IN PROGRESS)) 11/04/2007 JETTED TUBING DOWN TO 4325' CTMD RETURNING GRAY COLORED MATERIAL. LOGGED CEMENT BOND LOG USING SCHLUMBERGER MEMORY TOOLS. LOGGED 3 PASSES FROM 11737 UP TO 10500' CTMD. HELD 2800# ON TUBING WHEN LOGGING 2 OF THE 3 PASSES. MEMORY TOOLSTRING IN GOOD CONDITION AND RETURNED GOOD DATA. WELL FREEZE PROTECTED DOWN TO 4400' CTMD. 10/30/2007 CBL ATTEMPTED, TOOLS UNABLE TO FALL PAST 2350' - MADE THREE DIFFERENT ATTEMPTS, RAN DEPTH DETERMINATION AND TAGGED TD AT 11740'(2552 PSIA / 153 DEGF) 10/20/2007 HARD TAG AT 11753' CTMD,CIRCULATED CLEAN SEAWATER FROM TD TO 4000' CTMD, LEAVING WELL FREEZE PROTECTED FROM 4000' CTMD ( 2600' TVD) TO SURFACE WITH 60 BBLS OF 60/40 METH. TURN WELL OVER TO DSO ((IN PROGRESS)) 10/12/2007 SET DV @ 10447' RKB. MITIA 3500 PSI, GOOD. DRIFTED WITH 21'x 3.45" DUMMY GUN TO 11715' SLM (1250# P/U WGT). 10/11/2007 TAGGED @ 11715' SLM. PULLED DCK @ 10447' RKB. IN PROGRESS. 09/14/2007 LOG FMI/SONIC SCANNER ON DRILL PIPE FROM 11810' TO 10840'. HAVE DIFFICULTY GETTING THROUGH TIGHT SPOT AT 11670'. 09/10/2007 RAN MSCT AND TOOK CORES AT 11142.5', 11144', 11161', 11166`, 11167.5', 11172', 11182.5', 11193', 11213', 11226', 11281', AND 11307'. RAN FMI AND SONIC SCANNER AND TAGGED UP AT 11315'. LOGGED FROM 11315' TO CASING SHOE WITH FMI AND SONIC SCANNER. PULLED OUT OF HOLE WITH ELINE TOOLS AND RIG BEGAN WIPER TRIP. JOB IN PROGRESS. 63 records retrieved for Well History (2 year) Guy Schwartz Drilling and Wells Engineer office: 907 - 265 -6958 Cell: 240 -5696 ATO -1512 guy. I. schwartz@conocophillips.com 6/19/2008 2N -310 update i 9 Page 1 of 1 ' Maunder, Thomas E (DOA) From: Schwartz, Guy L [ Guy .L.Schwartz @conocophillips.com] Sent: Tuesday, April 22, 2008 1:37 PM To: Maunder, Thomas E (DOA) Cc: Braun, Michael Subject: 2N -310 update Tom, Just wanted to update you on this well. Very long process which is ongoing. These zones are all part of the Tarn pool. Outline of work to date is: 1) Perfed and frac'd Esker fm. (Nov. 2007) 2) Flowtested Esker and plugged back. (made water) 3) Perfed Bermuda zone ( March 2008) 4) Set plug top of Bermuda zone with long running BHP gauges 5) Perfed and frac'd Cairn Zone (April 2008) 6) Currently in process of flowtesting Cairn zone (Gas with Condensate) 7) Plan is to pull downhole gauges and set permanent patch over the Cairn. Then convert well to injection into Bermuda only. Been holding off on 10-404 till we finish the well completion completely. The well was permitted as a pre - produced injector so will have to submit a 403 to convert to injection once we are ready for that too. Very much a " one off' well here. Feel free to give me a shout with any comments or Q's.... Guy Schwartz Drilling and Wells Engineer office: 907 - 265 -6958 Cell: 240 -5696 ATO -1512 guy.1.schwartz@conocophillips.com 10/23/2008 • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510 -0360 ConocoPhilli Phone: 907 - 265 -6830 P b January 29, 2008 Commissioner State of Alaska RECEIVED Alaska Oil & Gas Conservation Commission 333 West 7 th Avenue Suite 100 JAN 3 1 zoos Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission Subject: Well Completion Report for 2N -310 Ancharep Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 2N -310. If you have any questions regarding this matter, please contact me at 265 -6830 or Jason Brink at 265 -6419. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT /skad STATE OF ALASKA ie RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 3 12008 WELL COMPLETION OR RECOMPLETION REPORT AN L G . 1a. Well Status: Oil ❑ Gas Li Plugged Abandoned 0 Suspended 20AAC 25.105 20AAC 25.110 Developm&Ct` Exploratory ❑ GINJ ❑ WINJ ❑ WDSPL ❑ WAG ❑ Other ❑ No. of Completions: Service ❑ Stratigraphic Test❑ 2. Operator Name: 5. Date Comp., Sus ., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: Septomha 2F, - 2007 207-090/ 3. Address: 6. Date Spudded: y.v 13. API Number: P. O. Box 100360, Anchorage, AK 99510 -0360 August 21, 2007 50- 103 - 20549 -00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number. Surface: 24' FNL, 602' FEL, Sec. 3, T9N, R7E, UM September 9, 2007 2N -310 - Top of Productive Horizon: 8. KB (ft above MSL): 30' RKB 15. Field /Pool(s): 1447' FNL, 2172' FWL, Sec. 36, T1 ON, R7E, UM Ground (ft MSL): 149' AMSL • Kuparuk River Field Total Depth: 7 Plug Back Depth (MD + TVD): Tam Oil Pool 1352' FNL, 2405' FWL, Sec. 36, T1 ON, R7E, UM 11737' MD / 5939' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 460991 y - 5911983 ' Zone- 4 - 11840' MD / 6036' TVD ADL 380053 TPI: x-469059 y - 5915802 Zone- 4 11, SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 469292 - - 5915896 Zone- 4 SSSV @ 2202' MD / 1919' TVD 4601 18. Directional Survey: Yes ❑✓ No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1150' TVD - 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/Res /Dens /Neutron, CBL, USIT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 20" 154# API 5L X65LP 30' 110' 30' 110' 42" 122 sx AS 1 9.625" 40# L -80 30' 3521' 30' 2394' 12.25" 571 sx AS Lite, 260 sx LiteCRETE 7" 26# L -80 30' 10828' 30' 5152' 8.75" 235 sx Class G 4.5" 12.6# L -80 10617' 11840' 4993' 6036' 1 6.125" 1204 sx Class G 23. Open to production or injection? Yes ✓ NoH If Yes, list each 24. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 10604' 10633' 11670'- 11690' MD 5876' -5895' TVD 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 11670'- 11690' 158748# of 16/20 carbolite 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) December 4, 2007 pre - produced injector - flowback in progress Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS -OIL RATIO Test Period -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) press. psi 24 -Hour Rate -> 27. CORE DATA Conventional Core(s) Acquired? Yes No zi Sidewall Cores Acquired? Yes Q No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. jl yl :2 SEE ATTACHMENT ` 0 -4 CONTINUED N REVERSE SIDE Form 1 07 Revised 2/2007 CON U O EVERS 28. GEOLOGIC MARKERS (List all formations and maW encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ✓ No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1332' 1150' needed, and submit detailed test information per 20 AAC 25.071. T-7 10678' 5037' T -4 11079' 5345' T -3 11270' 5504' T -2 11353' 5577' C -35 11484' 5700' Esker Top 11646' 5852' Esker Base 11707' 5910' N/A Formation at total depth: T -3 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Cement detail sheet 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Brink @ 265 - 6419 Printed Na Ra as� Title: Drillino Team Leader s D ate, Signature ne Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 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 ConocoPhillips Time Log Summary We!lv7ew Web Reporting Well Name: 2N -310 Job Type: DRILLING ORIGINAL Time L ogs Data F E."Death Phrase Code Subcode T COM 08/14/2007 07:00 08:00 1.00 MIRU MOVE MOB P Move rig from 2N -327 to 2N -310. Spot & level rig. Release rig for summer rig maintenance. 08/20/2007 00:00 06:00 6.00 MIRU MOVE RURD P Finish 2007 Summer Rig Maintenance /Accept Rig for Operations on 2N -310 @ 00:01 hrs, 8/20/07. NU divert line to Diverter. Load pits with spud mud. 06:00 08:00 2.00 MIRU MOVE OTHR P Rack & tally 100 joints of 5' DP. Function test Diverter @ 0800 - witnessing of test waived by Chuck Scheve, AOGCC Field Inspector. 08:00 09:00 1.00 MIRU MOVE OTHR P Rack & tally BHA. 09:00 14:30 5.50 MIRU MOVE OTHR P PU, MU, & stand back 5' DP. 14:30 16:30 2.00 MIRU MOVE OTHR P Rack & tally 20 joints of 5' HWDP and jars. PU, MU, & stand back 5' HWDP. 16:30 17:30 1.00 MIRU MOVE OTHR P Start loading 9 -5/8" casing in shed. Drift & strap same. 17:30 18:30 1.00 MIRU MOVE SFTY P Suspend rig operations. Hold Pre -Spud meeting in camp with rig crew, Directional Drillers, MWD, MI Mud Men, Safety Reps, Tool Pushers, & Co. Rep. 18:30 19:30 1.00 MIRU MOVE OTHR P PJSM. RU crane & hoist 9 =5/8" casing tools onto rig floor. 19:30 00:00 4.50 MIRU MOVE OTHR P Continue Rack & tally 9 -5/8" casing. 08/21/2007 00:00 01:00 1.00 0 0 MIRU DRILL RURD P PJSM, RU sheaves for Gyro line. 01:00 02:30 1.50 0 0 SURFAC DRILL PULD P MU BHA #1, RIH same. 02:30 04:30 2.00 0 223 SURFAC DRILL DDRL P Spud well, drill ahead dretnl 0 - 223 ft. 04:30 08:00 3.50 223 223 SURFAC DRILL PULD P Rack HWDP to mast, PU MWD, upload, surface test. 08:00 09:30 1.50 223 341 SURFAC DRILL DDRL P Drill ahead 12 -1/4 hole dretnl 223 - 341 ft. Auger packed off in pits. Cease drl . 09:30 10:30 1.00 341 341 SURFAC DRILL TRIP P PJSM, POH for auger. Auger clean-up completed while POH. 10:30 11:00 0.50 341 341 SURFAC DRILL TRIP P PJSM, flow check, RIH to 341 ft. No fill. 11:00 14:00 3.00 341 541 SURFAC DRILL DDRL P Drill ahead 12 -1/4 hole dretnl 341 - 541 ft. Can not build angle. 14:00 15:00 1.00 541 541 SURFAC DRILL TRIP T PJSM, POH for BHA inspection. Page 1 of 17 Tinter L ogs Date From To Dur S. Dwth E. Denth Phase Code Subc 08/21/2007 15:00 16:00 1.00 541 541 SURFAC DRILL WOOR T PJSM, inspect dretnl assy for orientation / failed equip. No problems / defects found All operational. Confir with CPAI Anchorage. 16:00 17:00 1.00 541 541 SURFAC DRILL PULD T Adjust BHA, remove MWD, reduce bit to sensor distance. 17:00 17:30 0.50 541 541 SURFAC DRILL PULD T PU UBHO sub, orient w/ motor. Cont. MU BHA #2. 17:30 18:00 0.50 541 541 SURFAC DRILL TRIP T RIH to 500'. 18:00 18:30 0.50 541 541 SURFAC DRILL REAM T Wash f/ 500'- 541'. 18:30 20:00 1.50 541 541 SURFAC DRILL SRVY T Break connection, RIH w/ GYRO, survey well, obtain results, consult w/ office on plan forward. 20:00 21:30 1.50 541 541 SURFAC DRILL TRIP T POOH to adjust/ increase motor bend to 2.12 deg. 21:30 23:00 1.50 541 541 SURFAC DRILL TRIP T RIH to 530', orient BHA to drill ahead. 23:00 23:30 0.50 541 563 SURFAC DRILL DDRL P Dir Drill f/ 541'- 563'. Run Gyro survey to determine effectiveness of build attempt. Consult w/ office on/ plan forward. Unable to build due to soft formation. 23:30 00:00 0.50 563 563 SURFAC DRILL CIRC NP Circulate w/ discuss drilling close approach options w/ office. 08/22/2007 00:00 00:30 0.50 563 563 SURFAC DRILL CIRC NP Circulate while develop plan forward w/ town concerning pending close approach issues and BHA p erformance. 00:30 04:00 3.50 563 653 SURFAC DRILL DDRL P Dir Drill ahead w/ taking Gyro surveys at 30 ft intervals f/ 563'- 653'. BHA response improvement, now able to correct dir tendency. Review well path and develop plan forward w/ DD's. 04:00 06:00 2.00 653 653 SURFAC DRILL TRIP P POOH to C/O BHA. Will PU MWD, reduce motor bend angle to 1.83 deg, re- orient and run back in to drill ahead. 06:00 09:00 3.00 653 653 SURFAC DRILL PULD P Flow check at BHA, adjust motor angle. PU MWD, orient, upload, RIH, surface test. 09:00 09:30 0.50 653 653 SURFA RIGMN SVRG P PJSM, service top drive. 09:30 10:00 0.50 653 653 SURFAC DRILL TRIP P Flow check, RIH to 653 ft, no fill. 10:00 12:00 2.00 653 780 SURFAC DRILL DDRL P Drill ahead 12 -1/4 hole dretnl 653 - 780 ft MD (778' TVD). PU 70 klbs, SO 70 klbs, ROW 70 klbs. OB Torq 2300 ft -Ibs, OFB Torg 1910 ft -Ibs. 12:00 00:00 12.00 780 1,658 SURFAC DRILL DDRL P Drill ahead f/ 780'- 1658' MD ( 1622' TVD). Encountered gas hydrates f/ 1200'- 1350' MD w/ max sas 3942 units. PU 97 klbs, SO 85 klbs, RotWt 93 klbs. OB Torq 3800 ft -Ibs, OFB Torg 3000 ft -Ibs. Page 2ofI I - - Tim IL D ate From To Dur S. Depth E Deoth Phus Code Sub 08/23/2007 00:00 03:30 3.50 1,658 2,020 SURFAC DRILL DDRL P Drill ahead w/ 12 1/4" bit f/ 1658'- 2020' MD. PU to circulate when develop problem w/ #2 pump. 03:30 04:00 0.50 2,020 2,020 SURFAC RIGMN RGRP T Circulate w/ diagnose and repair problem w/ #2 pump. Found washed out valve & seat in center pod. Replace both. 04:00 08:30 4.50 2,020 2,364 SURFAC DRILL DDRL P Drill ahead 12 -1/4 hole dretnl 2020'- 1 2364 ft. 08:30 09:00 0.50 2,364 2,364 SURFAC RIGMN' RGRP T Repair cuttings auger while circ. 09:00 10:30 1.50 2,364 2,506 SURFAC DRILL DDRL P Drill ahead 12 -1/4 hole dretnl 2364 - 2506 ft. 10:30 11:00 0.50 2,506 2,506 SURFAC DRILL CIRC P CBU for trip. No gain / loss. Max gas 550 units. 11:00 13:30 2.50 2,506 2,506 SURFAC DRILL TRIP P PJSM, flow check, POH for BHA angle adjustment. Normal updrag, no swab / gain / loss. 13:30 15:30 2.00 2,506 2,506 SURFAC DRILL PULD P Flow check at BHA, download MWD, break / grade bit. 15:30 17:30 2.00 2,506 2,506 ISURFACDRILL PULD P MU bit, adjust motor angle to 1.50 deg. La out UBHO, orient, RIH same. 17:30 19:00 1.50 2,506 2,506 SURFAC DRILL TRIP P Flow check, follow BHA with 5" DP to 1500'. 19:00 19:30 0.50 2,506 2,506 SURFAC DRILL CIRC P Work pipe through 8 deg DL interval in wellbore at 1500 ft to reduce severety. Circulate out thick mud. 19:30 21:00 1.50 2,506 2,506 SURFAC DRILL TRIP P Continue TIH f/ 1600'- 2450'. Break circulation, CBU to remove clobbered mud w/ wash to bottom. 21:00 23:30 2.50 2,506 2,787 SURFAC DRILL DRLG P Drilling ahead f/ 2506'- 2787' 23:30 00:00 0.50 2,787 2,787 SURFAC RIGMN' OTHR P Service Rig 08/24/2007 00:00 01:00 1.00 2,787 2,787 SURFAC RIGMN RGRP T Change out valve and seat on pump. 01:00 03:00 2.00 2,787 2,976 SURFAI DRILL DDRL P Drill f/ 2787'- 2976'. 03:00 03:30 0.50 2,976 2,976 SURFAC DRILL CIRC T Circulate and recip w/ repairing stroke counters f/ MWD. 03:30 08:30 5.00 2,976 3,530 SURFAC DRILL DDRL P Drill f/ 2976'- 3530 ft. (TD 9 -5/8 interval 08:30 11:00 2.50 3,530 3,530 SURFAC DRILL CIRC P C/C mud for wiper trip. 11:00 11:30 0.50 3,530 3,530 SURFAC WELCT OWFF P Flow check, well static. 11:30 14:00 2.50 3,530 3,530 SURFAC DRILL WPRT P POH wiper trip in prep for 9 -5/8 csg to BHA. No drag / swab / gain / loss. 14:00 15:30 1.50 3,530 3,530 SURFAC DRILL WPRT P Flow check, RIH wiper trip to 3530 ft. No fill. 15:30 19:00 3.50 3,530 3,530 SURFAC DRILL CIRC P C/C drlg fluids for 9/5/8 csg. 19:00 22:00 3.00 3,530 3,530 SURFAC DRILL TRIP P POOH f/ 3530'- 2970'. Observe well, pump dry job, continue POOH f/ 2970' 22:00 22:30 0.50 3,530 3,530 S DRILL PULD I P I Lay down 5" non -mag flex collars page 3of17 Time L ogs Date From To Dur S. Deoth E. Dwth Phase Code Suibcode T COM 08/24/2007 22:30 23:00 0.50 3,530 3,530 SURFAC DRILL OTHR P Download MWD data. 23:00 00:00 1.00 3,530 3,530 SURFAC DRILL PULD P Continue UD BHA. 08/25/2007 00:00 01:00 1.00 3,530 3,530 SURFAC DRILL PULD P Finish UD MWD & Motor 01:00 02:00 1.00 3,530 3,530 ISURFACDRILL OTHR P Clear / clean floor work area, prepare for running casing. 02:00 05:00 3.00 3,530 3,530 SURFAC CASIN( RURD P Rig up casing running equipment. 05:00 14:30 9.50 3,530 3,530 SURFAC CASIN( RNCS P PJSM, MU shoe, 2 jts 9 -5/8, float collar. Thread lock all connections. RIH shoe track. Fill and check floats. Follow shoe track with 81jts 40 #, L80, BTC 9 -5/8 csg. TAM port collar installed at 994 ft. Fill / break circ at 1000 ft. Attempt circ at 1500 ft. 30% returns. Cont. RIH breaking circ in 500 ft intervals. Partial returns. Normal drag at circ intervals. 100% returns on displacement while RIH. Cont RIH to 3478 ft. MU csg hgr. Wash 40 ft to btm. 25% returns. Re -c_ ip csU Idle pump on do stroke, slow descent. Increase rate to 6 bpm with fast ascent. Cont in this manner until a chieve 100°/ Final depths: Shoe 3521 ft, Float collar 3433 ft, Tam collar 995 ft. 14:30 17:00 2.50 3,530 3,530 SURFAC CASIN( CIRC P C/C drlg fluids, prepare D -29 / Cem Net LCM pills in prep for cmt 'ob. 17:00 17:30 0.50 3,530 3,530 SURFAC CASIN( RURD P RD Franks Fill -up Tool. Install and RU cement head. 17:30 18:30 1.00 3,530 3,530 SURFAC CEMEI\ CIRC P Cont circ @ 2 bpm. Pump LCM pill. After stop t/ install cmt head, noted full circulation capability but unable to recip pi e. 18:30 23:30 5.00 3,530 3,530 SURFAC CEMEN DISP P Cement casing into place. PJSM, Pumped 5 bbls H2O, 50 bbls Chem wash, 50 bbls 10.5 ppg mudpush, dropped bottom plug, pumped 452 bbls 10.7 ppg ASL, 60 bbls 12# LiteCrete, drop top plug, displace w/ 20 bbls H2O and 240 bbls mud using rig. Bumped plug at calculated displacement, bumped at 500 psi over (970 psi). Hold 15 minutes, bleed and check floats. OK. Noted full returns while cementing and 95 % while displacing, Est total cmt returns at surface 300 bbls. Surface casing cemented and in place at 2330 hrs. 23:30 00:00 0.50 3,530 3,530 SURFAC CEMEN RURD P Rig down spiders, landing jt and cmt head. 08/26/2007 00:00 08:00 8.00 3,530 3,530 SURFAC WELCT NUND P Wash and flush out diverter, nipple down diverter, clean / clear csg & cmtg eg f/ floor.0 Page 4 of 17 Mnw L ogs Date From " To Dur S.Debth E:DenthPhase Code 08/26/2007 08:00 10:30 2.50 3,530 3,530 SURFAC WELCT WOP P Load pipe shed w/ 5" DP while waiting on wellhead hand. FMC tied up on WES installing wellhead so rig can move. 10:30 14:00 3.50 3,530 3,530 SURFAC WELCT NUND P Install/ nipple up wellhead. Alignment verified /witnessed by pad operator Leanord Suiter. 14:00 18:00 4.00 3,530 3,530 SURFAC WELCT NUND P Nipple up BOPE. 18:00 21:00 3.00 3,530 3,530 SURFAC WELCI BOPE P Test BOPE. Test witnessed by AOGCC inspector Bob Noble. Test all 250 / 3500 psi, all OK, no failures. 21:00 21:30 0.50 3,530 3,530 SURFAC CASIN RURD P Install wear bushing, RILD. 21:30 23:00 1.50 3,530 3,530 ISURFACDRILL OTHR P Rabbit and tally 5" DP. 23:00 00:00 1.00 3,530 3,530 S DRILL PULD P PU and RIH w/ 5" DP singles t/ 982'. 08/27/2007 00:00 11:00 11.00 3,530 3,530 SURFAC DRILL PULD P PJSM, commence PU 5" DP fro pipe rack ins Is, stand bk to mast. 11:00 13:30 2.50 3,530 3,530 SURFAC DRILL PULD P PJSM, PU BHA #6, 8 -3/4 dretni drlg / LWD ass y. 13:30 16:30 3.00 3,530 3,530 SURFAC DRILL DHEQ T Attempt upload MWD / LWD equip. Failed test. LD tools. MU new assy. RIH same. 16:30 17:30 1.00 3,530 3,530 SURFAC DRILL PULD P Upload MWD, surface test same. Test successful. 17:30 18:30 1.00 3,530 3,530 SURFAC DRILL PULD P Resume PU remainder BHA #6. 18:30 22:00 3.50 3,530 3,530 SURFAC DRILL PULD P RIH w/ picking up 5" DP singles t / 3026' MD. PU 65klbs, SO 110kibs. 22:00 00:00 2.00 3,530 3,530 SURFAC RIGMN OTHR P PJSM, slip & cut drill line. 08/28/2007 00:00 00:30 0.50 3,530 3,530 SURFAC DRILL TRIP P Continue RIH f/ 3026'- 3250', encounter cement stringers. 00:30 02:00 1.50 3,530 3,530 SURFAC CEMEN COCF P Wash ream f/ 3250'- 3374', CBU. 02:00 03:30 1.50 3,530 3,530 SURFAC DRILL OTHR P BDTD, RU f/ csg test. Pressure inte rit test 9 5/8 surface casing 3000 Dsi / 30 m inutes. Test good. 03:30 06:30 3.00 3,530 3,530 SURFAC CEMEIS DRLG P C/O & tag top of FC @ 3433' Drlr Depth. Drilll shoe track. Track free of voids. Drill cmt to 3530 ft. 06:30 07:00 0.50 3,530 3,560 SURFAC DRILL DDRL P Drill ahead 8 -3/4 hole 3530 - 3560 ft for LOT 07:00 08:30 1.50 3,560 3,560 SURFAC DRILL CIRC P PJSM, flow check, C/C drlg fluids. Displace with LSND mud. Cont circ shaker clean for LOT. 08:30 10:00 1.50 3,560 3,560 SURFAC DRILL LOT P PJSM, Perform LOT at 3560 MD / 2397 TVD (9 -5/8 shoe) 9.6 ppg. No breakover. Bled to 663 psi. Results:797 psi surface = 16 EMW 10:00 10:30 0.50 3,560 3,560 ISURFACDRILL DHEQ P Baseline parameters MWD / LWD equi 10:30 11:00 0.50 3,560 3,560 ISURFACDRILL WOSP NP Off load drag. Mud. Page 5 of 17 Time Lo Date From To Dur Deoth E. Dooth Phase Code Subcode 08/28/2007 11:00 00:00 13.00 3,560 4,785 INTRM1 DRILL DDRL P Drlg. 8 3/4" directional hole from3560' to 4785 MD 2834' TVD. Up wt. 135k do 75k Rot 90k rpm 100 wob 10 -15k max gas 40 units ecd 11.26 pp 2150 psi 220 spur 650 gpm tq on 8400 off 7500. art-7.51 ast .78 08/29/2007 00:00 01:45 1.75 4,785 4,888 INTRM1 DRILL DDRL P Drlg. 8 3/4" directional hole from 4785' to 4888' MD. 01:45 02:00 0.25 4,888 4,888 INTRM1 DRILL OTHR P Rig service & fix grabber. 02:00 08:00 6.00 4,888 5,458 INTRM1 DRILL DDRL P Drlg. 8 3/4" directional hole from 4888' to 5458' MD 3068' TVD. 08:00 09:30 1.50 5,458 5,458 INTRM1 RIGMN RGRP T Circ. @ 290 gpm & replace valves & seats in #1 & 2 pumps. 09:30 19:30 10.00 5,458 6,351 INTRM1 DRILL DDRL P Drlg. 8 3/4" Directional hole from 5458' to 6351' MD. 3329' TVD. 19:30 22:00 2.50 6,351 6,351 INTRM1 DRILL CIRC T Circ. cond mud - lubricant was plugging off screens -circ. slow & change shaker screens. Attempting to get mud flowing thru screens. 22:00 00:00 2.00 6,351 6,385 INTRM1 DRILL DDRL P Drlg. @ slower rate while working on mud from 6351' to 6385'. MD Up wt. 135k do 90k rot 100k tq on 8000 off 7000 rpm 100 wob 10 -15k max gas 40 units pp 2500 psi 220 spm 650 gpm ecd 10.9 art 11.03 hrs. ast .77 hrs. 08/30/2007 00:00 09:30 9.50 6,385 7,158 INTRM1 DRILL DDRL P Drlg. 8 3/4" directional hole from 6385' MD to 7158 ft. Cease drlg ahead. Possible cracked fluid end Pump #1. 09:30 10:30 1.00 7,158 7,158 INTRM1 RIGMN RGRP T PJSM, flow check, circ / troubleshoot pump. Discover cracked pot at fluid end. 10:30 14:00 3.50 7,158 7,158 INTRM1 DRILL TRIP T PJSM, POH to 9 -5/8 csg shoe while repair pump. Wellbore exc condition. No abnormal drag, no swab / gain / loss. Correct hole fill. 14:00 16:30 2.50 7,158 7,158 INTRM1 RIGMN RGRP T Change out pot on pump #1. Test / run in same. Test good. 16:30 18:00 1.50 7,158 7,158 INTRM1 DRILL TRIP T Flow check, RIH 5" DP to 7090 ft. Precaution wash to btm. No fill. 18:00 00:00 6.00 7,158 7,726 INTRM1 DRILL DDRL P Drill ahead 8 -3/4 hole dretnl, 7158 to 7726'MD 3853' TVD. Up wt 185k do 85k rot 107k rpm 96 wob 10 -15k pp 2800 psi 620 gpm 212 spm tq on 13500 off 10500. 08/31/2007 00:00 00:00 24.00 7,726 9,746 INTRM1 DRILL DDRL P Drlg. 8 3/4" directional hole from 7726' MD to 9746' MD 4550' TVD. Up wt 225k do 90k rot 120k pp 2800 psi 588 gpm 197 spm rpm 95 wob 10 -15k tq 15550 on 13000 off max gas 180 units art 13.63 ast 1.63 max ecd,s 11.69 09/01/2007 00:00 19:00 19.00 9,746 10,840 INTRM1 DRILL DDRL P Drlg. 8 3/4" directional hole from 9746' to 10,840' MD 5158' TVD. Up wt 240k do 95k rot 130k wob 10 -15k rpm 98 pp 2800 psi 197 spm tq 17660 on 16000 off art 5.08 ast 5.53 ecd 11.16 max as 707 units. Page 6 of 17 71me Loge Date From To Dur S, De to E: ' Phne Code Subcode T COM 09/01/2007 19:00 22:00 3.00 10,840 10,840 INTRMI DRILL CIRC P Pump sweep & CBU X 4 @ 198 spm. 22:00 00:00 2.00 10,840 8,199 INTRMI DRILL TRIP P Monitor well & wiper trip to 9 5/8" shoe. 09/02/2007 00:00 03:30 3.50 8,199 3,489 INTRM1 DRILL WPRT P Wiper trip to shoe from 8199' to 3489'. Hole in good condition. No tight spots. 03:30 04:30 1.00 3,489 3,489 INTRM1 RIGMN SVRG P Slip & cut drig. line & service top drive -crown & blocks. 04:30 11:00 6.50 3,489 10,840 INTRM1 DRILL WPRT P Resume RI wiper trip, precaution wash 90 ft to btm at 10840 ft. no fill. Wellbore exc cond. No Dn drag. Correct displacement. 11:00 16:00 5.00 10,840 10,840 INTRM1 DRILL CIRC P C/C drig fluids. Treat for 7" csg run. Fluid caliper = 10% washout. Cont circ shaker clean. 16:00 00:00 8.00 10,840 4,228 INTRM1 DRILL TRIP P PJSM, flow check, POH laying do 5" DP for 7" csg run. 09/03/2007 00:00 06:30 6.50 4,228 950 INTRM1 DRILL PULD P Laying down 5" DP 06:30 11:30 5.00 950 0 INTRMI DRILL PULD P LD BHA, download MWD, LD dretnl ass / bit. Remove from pipe shed.. 11:30 15:00 3.50 0 0 INTRMI WELCT BOPE P PJSM, install 7" rams. Test same. Test successful. 15:00 17:30 2.50 0 0 INTRMI CASIN( RURD P PJSM, RU for 7" csg run. 17:30 22:00 4.50 0 3,484 INTRM1 CASIN RNCS P Commence Run 7" csg. to 3484'. MD Up wt. 85k do 50k. 22:00 00:00 2.00 3,484 3,484 INTRM1 CASINO CIRC P Circ. & condition while finish loading 7" in pipe shed. 75 spm 300 psi. 09/04/2007 00:00 02:00 2.00 3,484 3,484 INTRM1 CASIN CIRC P Circ. & cond. @ 3484' while loading - tallying & drifting 7" csg. in pipe shed. 02:00 03:30 1.50 3,484 4,467 INTRM1 CASIN RNCS P Run 7" csg. from 3484' to 4467'. Up wt 118k do 76k. 03:30 04:00 0.50 4,467 4,467 INTRM1 CASIN( CIRC P I CBU @ 65 spm 330 psi. 04:00 06:00 2.00 4,467 6,000 INTRMI CASIN( RNCS P Run 7" csg. from 4467' to 6000'. MD Up wt. 135k do 78k. 06:00 07:00 1.00 6,000 6,000 INTRMI CASIN( CIRC P CBU @ 77 spm 460 psi. 07:00 09:30 2.50 6,000 8,035 INTRM1 CASIN( RNCS P Run 7" csg. from 6000' to 8035' MD. 09:30 10:30 1.00 8,035 8,035 INTRM1 CASIN CIRC P CBU @ 70 spm 560 psi. 10:30 12:30 2.00 8,035 10,000 INTRMI CASIN( RNCS P Run 7" csg. from 8035' to 10000' MD. 12:30 14:30 2.00 10,000 10,000 INTRMI CASIN CIRC P CBU @ 64 spm 330 psi. 14:30 15:30 1.00 10,000 10,828 INTRMI CASIN( RNCS P Run 7" csg. from 10000' to 10828' MD. Up wt 275k do 85k. 15:30 18:30 3.00 10,828 10,828 INTRM1 CASIN( CIRC P CBU X 2 85 spm 560 psi. Page 7 of 1 7 . Oqs Date f rom To r se Code Sub 09/04/2007 18:30 19:30 1.00 10,828 10,828 INTRM1 CASIN CIRC P Make up cement head & circ. @ 77 spm 440 psi. (7" stuck with hander landed whi laying down fill up tool & installing cement headj Possibly make up cement head prior to conditioning mud for cementing. (Was reciprocating pipe 10' to 15' prior to changing tools. 19:30 22:00 2.50 10,828 10,828 INTRM1 CEMEIN DISP P PJSM= Pump cement as per program. Bump plug on calculated strokes.) 22:00 23:00 1.00 10,828 10,828 INTRM1 CEMEIN OTHR P Bumped plug w/ 1700# check floats. OK rig down csg. equipment. Lay down landing 't. 23:00 00:00 1.00 10,828 10,828 INTRM1 WELCT BOPE P Drain stack -set packoff- RILDS- test ackoff 5000# 15 mins. OK. 09/05/2007 00:00 02:00 2.00 10,828 0 INTRM1 WELCT EQRP P PJSM =Chan a out upper & lower i 9 PP e P P rams to 4 ". 02:00 04:00 2.00 0 0 INTRM1 DRILL PULD P Change out floor equipment to 4" drill p ipe handling tools. 04:00 06:00 2.00 0 0 INTRM1 DRILL OTHR P Unload pipe shed & rig of casing equipment. 06:00 07:00 1.00 0 0 INTRM1 WELC7 BOPE P Test 4" rams 350 -3500 psi. OK 07:00 08:00 1.00 0 0 INTRM1 CEMEh OTHR P Load pipe shed with 4" drill pipe. (Freeze protected 9 5/8" X 7" annulus w/ 130 bbls. diesel while loading pipe shed. 08:00 09:30 1.50 0 0 INTRM1 RIGMN SVRG P Change out grabber dies, guid bell & adjust top drive torque values. 09:30 16:00 6.50 0 3,515 INTRM1 DRILL PULD P Pick up 4" drill pipe to 3515'. Perform stripping drill. 16:00 18:00 2.00 3,515 0 INTRM1 DRILL TRIP P POH from 3515' 18:00 22:00 4.00 0 0 INTRM1 DRILL OTHR P Continue loading pipe shed with 4" drill pipe while changing liners in mud p ump from 5.5" to 5 ". 22:00 22:30 0.50 0 0 INTRM1 RIGMN SVRG P Service top drive. 22:30 00:00 1.50 0 0 INTRM1 DRILL PULD P PJSM =Make up Sperry BHA. 09/06/2007 00:00 01:00 1.00 0 0 INTRM1 DRILL PULD P Continue making up BHA V. 01:00 02:30 1.50 397 397 INTRM1 DRILL PULD P Up load MWD 02:30 03:00 0.50 397 397 INTRM1 DRILL DHEQ P Shallow test MWD 5 bpm 1000 psi. 03:00 03:30 0.50 397 397 INTRM1 DRILL PULD P PJSM= Loading Nuclear Sourses. 03:30 15:30 12.00 397 10,556 INTRM1 DRILL TRIP P Run in hole picking up 4" dp from 397' to 10556' M D 15:30 17:30 2.00 10,556 10,650 INTRM1 DRILL CIRC P Establish paremeters & wash from 10556' to 10650'. Circ. & condition mud for csg. test. 80 s m 1800 psi. 17:30 18:30 1.00 10,650 10,650 INTRM1 DRILL OTHR P Blow down top drive, rig up & test 7" csg. to 3000 psi 30 mins. & chart - -s same. Page 8 of 17' TIM L ogs Date , From To Dur Deoth E. Derith Phne Code T COM 09/06/2007 18:30 21:00 2.50 10,650 10,840 INTRM1 CEMEIS DRLG P Make up top drive. Wash from 10650' to 10740'. Tag top of plugs. Drill plugs -float equipment - cement. shoe & clean out to 10840'. 85 spm 2200 psi. 21:00 22:00 1.00 10,840 10,840 INTRM1 DRILL CIRC P Displace well to new mud @ 90 spm 2800 psi. 22:00 22:30 0.50 10,840 10,860 INTRM1 DRILL DDRL P Drill new hole from 10840' to 10860'. MD TVD 5175'. 22:30 23:00 0.50 10,860 10,860 INTRM1 DRILL CIRC P Circ. hole clean 90 spm 2800 psi. 23:00 00:00 1.00 10,860 10,860 INTRM1 DRILL LOT P Perform leak off test. Equivalent 14.8# w w/ new mud wt. 9.5. 09/07/2007 00:00 01:00 1.00 10,860 10,860 PROD1 DRILL OTHR P Set parameters for ecd,s & mwd 90 spm 220 gpm pp 2840 psi ecd 12.4 01:00 00:00 23.00 10,860 11,175 PROD1 DRILL DDRL P Drlg. 6 1/8" directional hole from 10860' to 11 175' MD 5420 TVD. PP 3000 psi 102 spm rpm 60 -70 wob 5 -10k tq on 12500 off 11000. Up wt 150k do 75k rot 100k max gas 120 units. Adding to torque to reduce hanging u while sliding. 09/08/2007 00:00 03:00 3.00 11,175 11,215 PROD1 DRILL DDRL P Drilling 6 1/8" directional hole from 11175' to 11215' MD. 03:00 03:30 0.50 11,215 11,215 PROD1 DRILL OWFF P Flow check w/ pumps off. No Flow. 03:30 08:30 5.00 11,215 11,312 PROD1 DRILL DDRL P Drilling 6 1/8" directional hole from 11215' to 11312' M D. 08:30 09:00 0.50 11,312 11,312 PROD1 DRILL OWFF P Flow check w/ pumps off. No Flow 09:00 00:00 15.00 11,312 11,545 PROD1 DRILL DDRL P Drilling 6 1/8" directional hole from 11312' to 11545'. MD. 5761' TVD. Up wt 145k do 87k Rot 112k wob5 -7k rpm 80 pp 2900 102 spm 250 gpm max gas 75 units ecd 12.11 tq on 6500 off 5900. ART 6.37 AST 8.8 Jar hrs. 40.38 09/09/2007 00:00 10 :00 10.00 11,545 11,840 PROD1 DRILL DDRL P Drlg. 6 1/8" directional hole from 11545' MD to 11840' MD.6036' TVD. Up wt 153k do 100k rot 125k tq on 7420 off 5780 wob 5 -10k rpm 80 pp 2900 97 spm ecd 11.93. art 5.92 ast 1.75. 10:00 13:00 3.00 11,840 11,840 PROD1 DRILL CIRC P Pump hi vis sweep -circ. & condition hole for logs. 13:00 13:30 0.50 11,840 11,840 PROD1 DRILL OWFF P Monitor well. Small flow. 13 :30 18:00 4.50 11,840 11,840 PROD1 DRILL CIRC P Circ. & cond. Build mud wt. to 10# 18:00 18:30 0.50 11,840 11,840 PROD1 DRILL OWFF P Monitor well. Well static. 18:30 19:30 1.00 11,840 10,744 PROD1 DRILL TRIP P POH from 11840' to 10744' MD. 19:30 20:30 1.00 10,744 10,744 PROD1 DRILL OWFF P Monitor well for flow. While monitoring. Service rig. & PJSM on setting storm p acker. Page 9 of 17 Time L ogs ,Date From To Dim 'S. Detith E. Deoth P C 09/09/2007 20:30 22 :30 2.00 10,744 10,744 PROD1 DRILL OTHR P Make up storm packer & set same @ 40'. test 500 psi for 10 mins. Lay down running tool. 22:30 00:00 1.50 10,744 10,744 PROD1 DRILL OTHR P Wash stack & drain. Pull wear ring & set test plug. 09/10/2007 00:00 05:00 5.00 10,744 10,744 PROW DRILL OTHR P Test BOPE 250 -3500 psi. OK Witness test waived by Chuck Sheave AOGCC. 05:00 05:30 0.50 10,744 10,744 PROD1 DRILL OTHR P Pull test plug & set wear ring. 05:30 08:30 3.00 10,744 10,744 PROD1 DRILL OTHR P Rig up storm packer retrieving tool. Screw into storm packer. Make up to top drive. Close annular preventer. Check for pressure. Pull packer to surface & lay down same. 08:30 09:30 1.00 10,744 11,840 PROW DRILL TRIP P RIH from 10744 to 11840' MD. 09:30 11:30 2.00 11,840 11,840 PROW DRILL CIRC P Make up top drive -break circ. pump sweep & circ. condition. 11:30 13:30 2.00 11,840 11,840 PROW DRILL OWFF P Monitor well for gain or loss. 13:30 16:00 2.50 11,840 11,840 PROW DRILL CIRC P Circ. @ 51 spin pp 1440 psi circ. & reci rotate. 16:00 16:30 0.50 11,840 11,840 PROD1 DRILL OWFF P Monitor well for flow or loss. 16:30 18:00 1.50 11,840 10,366 PROD1 DRILL TRIP P POH from 11840' to 10366'. 170k up 95k dn. 18:00 18:30 0.50 10,366 10,366 PROW DRILL CIRC P Pump dry job. 18:30 00:00 5.50 10,366 2,200 PROD1 DRILL TRIP P POH from 10366' to 2200' MD. Drop drill pipe drift prior to pulling pipe. 09/11/2007 00:00 01:00 1.00 11,840 11,840 PROD1 DRILL TRIP P Cont. POOH f/ 2200'- 397'. 01:00 02:00 1.00 11,840 11,840 PROD1 DRILL PULD P PJSM, Lay down HWDP, Jars & NMDC f/ 397'- 153'. 02:00 05:00 3.00 11,840 11,840 PROD1 DRILL PULD P PJSM, remove sources and lay down nuke logging tools. Download PWD and cont LID BHA f/ 153'- bit. Clean floor. 05:00 06:00 1.00 11,840 11,840 COMPZ DRILL WOEQ NP Wait on Schlumberger 06:00 08:30 2.50 11,840 11,840 COMPZP CORING PULD P PJSM, RU and test logging/ sidewall coring tools. 08:30 11:00 2.50 11,840 11,840 COMPZl CORING TRIP P RIH w/ DP and DP conveyed coring /logging tools (TLC system) f/ 0 - 3132'. 11:00 11:30 0.50 11,840 11,840 ICOMPZPCORING CIRC P MU Top drive and circ @ 68 spm, 320 p si. 11:30 17:30 6.00 11,840 11,840 COMPZI CORN TRIP P Cont RIH f/ 3132 - 10630'w/ stops at 6125', 9165' and finally 10630' to break circulation. 17:30 18:30 1.00 11,840 11,840 COMPZI CORIN PULD P PJSM, RU surface equipment for eline ops. RU sheave, install side entry sub., RIH U 10649'. Page 10 of 17 Date From To Dur S. Depth E Depoth Phase Code Subcode T . COM 09/11/2007 18:30 21:30 3.00 11,840 11,840 COMPZP CORIN OTHR P RIH w/ wireline control head, pump m downhole w/ 35 s & 600 si. Latch P p in at 70 spm, 1080 psi. Install wireline dogs, pull test cable U 2000 Ibs tension. Tighten pack -off on side entry sub, prepare to cunt RIH w/ core tools. 21:30 22:00 0.50 11,840 11,840 COMPZI CORING TRIP P Cont RIH w/ DP and wireline f/ 10649'- 11 142.5' f/ first core point. 22:00 00:00 2A0 11,840 11,840 COMPZt CORIN OTHR P C t id wall cores 11142.5', 11161', 11167', 11182.5, 11193, 11194.5', 11213' & 11219'. 09/12/2007 00:00 01:00 1.00 11,840 11,840 COMPZI CORING OTHR P Core 11226', 11281'. 01:00 02:00 1.00 11,840 11,840 COMPZI CORING OTHR T Diagnostics on core tool, unable to continue w/ program due to failure. Decision made to forgo remaining core interval, POOH and PU logging tools. 02:00 03:00 1.00 11,840 11,840 COMPZI CORING TRIP P POOH w/ core and TLC log assy to sidewall entry sub t/ remove eline equip ment. 03:00 04:30 1.50 11,840 11,840 COMPZI CORING PULD P Loosen pack -off, unsting wet connect on eline control head, POOH w/ wireline. LD side-entry sub. 04:30 05:00 0.50 11,840 11,840 COMPZI CORING TRIP P RIH to shoe at 10828, prepare to circulate. 05:00 07:30 2.50 11,840 11,840 COMPZI CORING CIRC P CBU and prepare to TOH w/ cores. Monitor well for gain/loss, stable. 07:30 08:00 0.50 11,840 11,840 COMPZI CORING TRIP P POOH f/ 11200'- 10530' 08:00 09:00 1.00 11,840 11,840 COMPZI CORING CIRC P Pump dry job, blow down top drive. 09:00 10:30 1.50 11,840 11,840 COMPZI RIGMN OTHR P PJSM, slip and cut drill line 10:30 16:00 5.50 11,840 11,840 C CORING TRIP P POOH f/ 10530'- core assy. 16:00 18:00 2.00 11,840 11,840 COMPZI CORING PULD P PJSM, RD / LD core equip. Clean rig floor w/ wait on SLB to reconfigure tool string for logging. 18:00 19:00 1.00 11,840 11,840 COMPZ EVALFI RURD P RU / PU SLB Drill pipe conveyed logging tools, test string. 19:00 00:00 5.00 11,840 11,840 COMPZP EVALF1 TRIP P RIH w/ logging tools on drill -pipe f/ Surf - 8646'. 09/13/2007 00:00 02:30 2.50 11,840 11,840 COMPZP EVALFI TRIP P TIH w/ TLC system and logging tools 02:30 05:30 3.00 11,840 11,840 COMPZ EVALFI PULD P Install side entry sub, RU eline, pump down to top wet connect, latch onto docking head. Lock in cable, tension test same, tighten pack-off, test all. 05:30 07:30 2.00 11,840 11,840 COMPZP EVALFI TRIP P Continue RIH w/ stands DP and loagina tools for OH logging o s. 07:30 09:30 2.00 11,840 11,840 COMPZ EVALF DLOG P TIH w/ logging tool. Tag obstruction @ 11322', unable to work through. Lo f/ 11317'- 10828' 09:30 10:00 0.50 11,840 11,840 COMPZI EVALF WOP NP Wait while c/o logging crews. Page 11 of 17 I Time Logs Date From Tcs 09/13/2007 10:00 11:00 1.00 11,840 11,840 COMPZP EVALFI PULD P Unlatch wet connect, POOH w/ eline 11:00 11:30 0.50 11,840 11,840 COMPZt EVALF1 TRIP P RIH f/ 10482'- 11 13' w/ DP & logging tool. 11:30 14:00 2.50 11,840 11,840 COMPZP EVALFI CIRC P CBU, stage up rate t/ 3 bpm. Well stable w/ no losses. 14:00 20:00 6.00 11,840 11,840 COMPZP EVALFI TRIP P PJSM, Monitor well. POOH f/ 11113'- 11016'. Monitor well, pump dry job. Cont POOH f/ 11016' - 102' (top of logging tool. 20:00 21:00 1.00 11,840 11,840 COMPZP EVALF1 PULD P R/D and L/D logging tool BHA f/ 102'- 0. Clear / Clean rig floor for next task. 21:00 00:00 3.00 11,840 11,840 COMPZP DRILL PULD P PJSM, PU C/O BHA. RIH t/ 2275' 09/14/2007 00:00 03:30 3.50 11,840 11,840 COMPZ1 DRILL TRIP P Continue TIH w/ clean -out BHA. 03:30 05:30 2.00 11,840 11,840 COMPZt DRILL CIRC P Circulate & Condition mud, load cased hole section w/ conditioned mud. 05:30 09:00 3.50 11,840 11,840 COMPZt DRILL CIRC P Treat surface mud volume & prepare to wash to bottom, drop mud wt to 9.8 09:00 13:30 4.50 11,840 11,840 COMPZP DRILL TRIP P RIH f/ 10786'- 11300'. RU and slowly wash /ream f/ 11300' - 11840'. 13:30 22:00 8.50 11,840 11,840 COMPZP DRILL CIRC P Circulate and condition mud, modify properties per program while circulate out 10+ ppg mud from wellbore. Pump LCM pill w/ good returns at shaker. Mud volume stable at 50 spm, lose mud at rate above 50 spm, gain at less, =11 breathing. 22:00 23:00 1.00 11,840 11,840 COMPZP DRILL TRIP P Short trip f/ 11840'- 10805'. Noted � draa 20klbs over from 11800 - 11600'. 23:00 00:00 1.00 11,840 11,840 COMPZP DRILL TRIP P RIH f/ 10805'- 11840'. Noted drag starting at 11654' , 10 -15 klbs under string wt, RU break circulation, ramp up rate and prepare to wash / ream to TD. 09/15/2007 00:00 01:00 1.00 11,840 11,840 COMPZP DRILL REAM P Wash ream f/ 11654' - 11840', 96 spm, 98 rpm. 01:00 02:30 1.50 11,840 11,840 COMPZ DRILL CIRC P Pump 20 bbls weighted sweep, circulate around t/ clean wellbore w/ recip pipe and rotating. 02:30 04:00 1.50 11,840 11,840 COMPZP DRILL CIRC P Reduce pump rate to 56 spm w/ monitor flow back f/ breathing analysis. noted 5 bbls gain 15 min. Reduce rate to 28 spm, noted 1 bbl g ain 20 min, the steady. 04:00 11:00 7.00 11,840 11,840 COMPZP DRILL TRIP P Trip ouf of hole f/ 11840'- surface. Hole conditions good, taking correct fill and no drag. LID C/O BHA and clean floor. 11:00 13:00 2.00 11,840 11,840 COMPZP RIGMN' SVRG P PJSM, slip and cut drill line, adjust brakes and service rig. 13:00 14:30 1.50 11,840 11,840 COMPZP EVALFI PULD P PJSM, RU / MU logging tools and TLC logging assy on drillpipe. Prepare to RIH. Page 12 of 17 Titre L ogs .Date From To . ur Code _ Su 09/15/2007 14:30 20:30 6.00 11,840 11,840 COMPZ EVALFI TRIP P RIH w/ logging tools on DP to 10713'. 20:30 23:00 2.50 11,840 11,840 COMPZ EVALFI RURD P RU Schlumberger, install side -entry sub and xo's. RIH w/ eline cable, pump cable in, latch on wet - connect, test toolstring. Lock in cable, tension test, OK. 23:00 00:00 1.00 11,840 11,840 COMPZ1 EVALFI TRIP P Cont RIH w/ logging tools f/ 10713'- 1 11502' 09/16/2007 00:00 01:00 1.00 11,840 11,840 COMPZ EVALFI TRIP P Continue RIH w/ DP conveyed logs to 11810', drillers depth. Encountered tight s of at 11670', worked through. 01:00 04:00 3.00 11,840 11,840 COMPZ EVALFI DLOG P Log f/ 11810' - 10820'. RIH f/ 10820' - 10920', lose DW ow r. 04:00 04:30 0.50 11,840 11,840 COMPZ1 RIGMN RGRP T Troubleshoot power issue w/ service and lube rig. 04:30 00:00 19.50 11,840 11,840 COMPZP RIGMN RGRP T Rig Down Time: Diagnose RIG SCR system lost draw -works fu nction. Unable to move pipe, DP conveyed logging tools in hole w/ eline connected, DP at shoe, logging tools in OH to 10920'. CBU @ 2100 hrs. 09/17/2007 00:00 00:00 24.00 11,840 11,840 COMPZP RIGMN RGRP T Rig Down Time: Change out U draw -works traction motor. Diagnostics on rig electrical CBU x 1 while working on rig. 09/18/2007 00:00 12:00 12.00 11,840 11,840 COMPZP RIGMN RGRP T Rig Down Time: Shut down while diagnosing rig electrical system. DP conveyed logging tools, TLC system and eline in hole to casing shoe. Unable to pull. Perform temporary repair, test. Drwks will run run in forward mode only. 12:00 13:30 1.50 11,840 11,840 COMPZ EVALFI TRIP P POH 4" DP to SES. 13:30 15:30 2.00 11,840 11,840 COMPZ EVALFI TRIP P POH Eline, RD Schlum, release unit. 15:30 20:30 5.00 11,840 11,840 COMPZ EVALFI TRIP P Flow check, POH 4" DP to top logging tools 20:30 21:30 1.00 11,840 11,840 COMPZ EVALFI PULD P Lay down FMI & Sonic logging tool string. 21:30 22:30 1.00 11,840 11,840 COMPZI DRILL PULD P PU clean -out BHA. 22:30 00:00 1.50 11,840 11,840 COMPZI DRILL TRIP P RIH w/ clean -out BHA t/ 4645'. Fill DP. 09/19/2007 00:00 04:00 4.00 11,840 11,840 COMPZ1 DRILL TRIP P TIH f/ 4645'- 10800. Fill pipe / break circulation. TIH f/ 10800 - 11720', tight hole. 04:00 05:00 1.00 11,840 11,840 COMPZI DRILL REAM P Break circulation, wash and ream to bottom. Repeat wash / ream through interval, wash / ream to TD. @ 55 spur no G /L. @ 95 spm, lose mud at 1 b m. 05:00 05:30 0.50 11,840 11,840 COMPZ DRILL CIRC P Max gas at BU 2260 units, circulate out gas, reduce pump rate U 40spm w/ circ out as. Page 13 of 17 I i lime L O O S - - - - Date Fr To th S bcode T , CO 09/19/2007 05:30 10:00 4.50 11,840 11,840 COMPZP DRILL CIRC P Pump 20 bbl weighted sweep. Circulate / condition mud. Pump addtnl sweep, verify fluid caliper = 7% washout. Cont circ shaker clean, p ump wt pill while ramp do pumps. 10:00 16:30 6.50 11,840 11,840 COMPZ DRILL TRIP P Flow check, PJSM, POH 4" DP for 4 -1/2 liner run. 16:30 17:30 1.00 11,840 11,840 COMPZP DRILL PULD P Flow check at BHA, LD same. 17:30 19:00 1.50 11,840 11,840 COMPZP CASIN RURD P Flow check, secure well, RU for 4 -1/2 liner run. 19:00 22:00 3.00 11,840 11,840 C CASIN( RUNL P PU and RIH w/ liner, check float, OK, flow check, OK. RIH. 22:00 23:30 1.50 11,840 11,840 COMPZP CASIN OTHR P PU / MU hanger, liner running tool, inspect same and load PAL fluid in SBE. Liner consists of: Shoe (1.69'), 2 jts 4 1/2" 12.6# IBT liner (61.45'), Float Collar (1.37'), 1 jt 4 1/2" 12.6# IBT (30.97'), BOT Type 1 landing collar (.83'), 35jts 4 112" 12.6# IBT (1074'), 4 1/2" DB -6 nipple w/ 3.75" profile (1.54'), 1 pup jt 4 1/2" 12.6# IBT (9.65'), BOT 4.5" flex lock hanger w/ HRD ZXP hanger packer ((18.87'), BOT 80 -40 SBE (16.27'). 23:30 00:00 0.50 11,840 11,840 COMPZP CASIN( RUNL P PU 1 std, RIH. Circ @ 3 bpm & 120 psi (1) complete liner volume to insure liner flow path clear. 09/20/2007 00:00 04:00 4.00 11,840 11,840 COMPZP CASIN RUNL P Run liner f/ 180'- 4895' on DP. Stop and break circ @ 20 std intervals. Gather Torque and Drag data through course of run. 04:00 04:30 0.50 11,840 11,840 COMPZP RIGMN SVRG P Service and Tube rig w/ troubleshoot - Top Drive controls. 04:30 06:30 2.00 11,840 11,840 COMPZP CASIN RUNL P Cont RIH w/4 1/2" liner on DP f/4895' - 8386'. 06:30 10:00 3.50 11,840 11,840 COMPZP DRILL OTHR T Wellbore left unattended too long during troubleshoot SCR system. Decision to POH liner/ RIH 4 "DP for wellbore conditioning. 10:00 17:30 7.50 11,840 11,840 COMPZP DRILL TRIP T Flow check, PJSM, POH 4" DP, LD 4 -1/2 liner. 17:30 22:00 4.50 11,840 11,840 COMPZP DRILL TRIP T Flow check, PJSM, MU cleanout BHA, RIH same t/ 10815'. 22:00 00:00 2.00 11,840 11,840 COMPZP RIGMN SVRG T Slip and cut drill line. 09/21/2007 00:00 02:00 2.00 11,840 11,840 COMPZP DRILL TRIP T Continue TIH f/ 10815'- 11500'. Pre are to wash to TD. 02:00 03:00 1.00 11,840 11,840 COMPZP DRILL REAM T Wash ream f/ 11500' - 11842' TD . Max gas 925 units @ BU. 03:00 08:00 5.00 11,840 11,840 COMPZ DRILL CIRC T Pump 25 bbl sweep @ BU, Circulate, condition mud. MW out 10.2 ppg. Treat to drop mud wt. 08:00 15:00 7.00 11,840 11,840 COMPZP DRILL TRIP T Flow check / PJSM, POH 4" DP to BHA. 15:00 15:30 0.50 11,840 11,840 COMPZ DRILL PULD T Flow check, LD BHA. Page 14 of 17 I Time L Date From To Phase T ':C 09/21/2007 15:30 16:30 1.00 11,840 11,840 COMPZP CASIN( RUNL T PJSM, RU for 4 -1/2 liner run. 16:30 19:00 2.50 11,840 11,840 COMPZP CASIN RUNL T Flow check / PJSM, RIH 4 -1/2 liner. Shoe (1.69'), 2 jts 4 1/2" 12.6# IBT liner (61.45'), Float Collar (1.37'), 1 jt 4 1/2" 12.6# IBT (30.97'), BOT Type 1 landing collar (.83'), 35 jts 4 1/2" 12.6# IBT (1074'), 4 1/2" DB -6 nipple w/ 3.75" profile (1.54'), 1 pup jt 4 1/2" 12.6# IBT (9.65'), BOT 4.5" flex lock hanger w/ HRD ZXP hanger packer (( 18.87'), BOT 80-40 SBE (1627'). 19:00 19:30 0.50 11,840 11,840 COMPZ CASIN( CIRC T Circ @ 3 bpm f/ (1) liner volume. 19:30 00:00 4.50 11,840 11,840 COMPZ CASIN( RUNL T RIH w/ liner on 4" DP t/ 8823'. 09/22/2007 00:00 02:00 2.00 11,840 11,840 COMPZ CASIN( RUNL P Continue RIH w/ 4 1/2" liner on DP t / 10815'. Break Circ. 02:00 04:00 2.00 11,840 11,840 COMPZ CASIN( CIRC P Circulate 1 hole volume 3 bpm / 820 psi. PU 138 klbs, SO 68 klbs, RotWt 90 klbs, Torg 6400 ft-lbs. 04:00 05:00 1.00 11,840 11,840 COMPZ CASIN( RUNL P Cont RIH w/ liner f/ 10815'- 11801'. Hole good cond. PU 160 klbs, SO 75 klbs. 05:00 05:30 0.50 11,840 11,840 COMPZP CEMEP PULD P P cmt plug head, install. MU circulating lines. 05:30 10:30 5.00 11,840 11,840 COMPZP CEMEI` CIRC P Break circulation, RIH tag bottom at 11842'. Continue to circulate w / recip pipe. Slowly ramp up circ rate. 650 p si @ 35 s m, 860 psi @ 52 s m. 10:30 13:00 2.50 11,840 11,840 COMPZP CEME SQEZ P PJSM, commence cmt 4 -1/2 liner: Pump 5 bbls H2O, Test lines 4000 psi, Pump .8 bbl Mudpush, Batch / pump 36 bbls ( 174 sks) G cmt, 5 bpm. Drop dart, displace with 114 bbls drlg mud, bump plug correct displacement with 2032 psi. Re -cip /rotate pipe entire 'ob. Build to 3982 psi, release HRD Bleed, floats holding. 13:00 14:00 1.00 11,840 11,840 COMPZP CEMEJ SQEZ P PU, set pkr with 500 psi on tool. Apply 50K do wt. All indicators prove pkr / h r set. 14:00 15:30 1.50 11,840 111,840 COMPZP CEMEN CIRC P Circ excess cmt to surface, 10 bpm 2700 psi. 2 bbls cmt returns. 15:30 16:30 1.00 11,840 11,840 COMPZt CEMEIN RURD P PJSM, RD cmt equip, release unit. 16:30 19:30 3.00 11,840 11,840 COMPZP CEME TRIP P PJSM, POH laying do 4" DP for com letion run t / 7495'. 19:30 20:00 0.50 11,840 11,840 COMPZP CEMEN TRIP P RIH w/ remaining 12 std of DP ou fo derrick t/ 8634'. 20:00 20:30 0.50 11,840 11,840 COMPZP CEMEN TRIP P POOH f/ 8634'- 8150' laying down 4" DP. 20:30 21:00 0.50 11,840 11,840 COMPZ RIGMN SVRG P Service and lube rig. 21:00 00:00 3.00 11,840 11,840 COMPZ CEMEN TRIP P Continue POOH w/ laing down DP f/ 8150'- 3803'. Page 15 of 17 i Tinle L 09/23/2007 00:00 05:00 5.00 11,840 11,840 C CEMEIN TRIP P Cont POOH f/ 3803'- Surf. 05:00 05:30 0.50 11,840 11,840 COMPZP CEMEN PULD P Break -out and LD liner hanger running tool. 05:30 06:00 0.50 11,840 11,840 COMPZP CASIN( RURD P Clear floor, pull wear bushing, wash stack ID. 06:00 08:00 2.00 11,840 11,840 COMPZP RPCOK RURD P PJSM, Place comp. equip to rig floor, RU /prepare for 4 -1/2 comp. 08:00 19:00 11.00 11,840 11,840 COMPZP RPCOK RCST P PJSM, commence RIH 4 -1/2 completion. (Seal assy, No go, pups, tbg, sliding sleeve, tbg, GLMs, SSV). RIH t/ 8410. 19:00 00:00 5.00 11,840 11,840 COMPZ RPCOCV RURD P PJSM, Load SSSV control liner spooler, RU to run control line when SSSV installed in production string. 09/24/2007 00:00 05:00 5.00 11,840 11,840 COMPZP RPCOK RCST P Cont RIH with completion on production string w/ attaching SSSV control line to tubing. 05:00 07:30 2.50 11,840 11,840 COMPZP RPCOK RURD P MU XO's and landing jt U RIH to top of SBE. Attempt stab in SBE. Possible solids at entry. Locate top and line up t/ displace out mud w/ seawater. 07:30 09:00 1.50 11,840 11,840 COMPZI RPCOJ CIRC P Displace well with seawater, 5 BPM - 840 psi. 09:00 10:30 1.50 11,840 11,840 COMPZP RPCON HOSO P Stab in SBE, space out, MU tbg hgr. MU control line. Attempt test same. FMC connection leaking. 10:30 12:30 2.00 11,840 11,840 COMPZP RPCOh WOEQ T Wait on delivery new FMC connection. Nospares. 12:30 13:00 0.50 11,840 11,840 COMPZJ RPCOK DHEQ P MU connection, test control line 5000 p si - 15 min. 13:00 14:30 1.50 11,840 11,840 COMPZI RPCOh HOSO P Stab in SBE, very difficult, re -cip / turn tbg to enter. Sting in, land tbg hgr. Confirm strap / space out. Final = seal assy 10627 ft, No -Go 10612 ft. 14:30 17:30 3.00 11,840 11,840 COMPZP RPCOK DHEQ P PJSM, Test tbg 2500 psi_- 15 min. Blee tbg to 1500 psi. Test 4 -1/2 X 7 ann 2500 psi - 30 min. Bleed tbg, note DKV shear at 2200 psi, cont bleed to "0" psi. Press tbg to 2500 psi, close SV bleed tbg to 200 Psi. SSV holding. Press tbg to 2500 psi, open SSV, bleed tbg / ann to "0" psi. All tests successful, no re- tests. 17:30 21:00 3.50 11,840 11,840 COMPZP RPCOh NUND P PJSM, back out Idg jt, set BPV, nipple do BOPE. 21:00 00:00 3.00 11,840 11,840 COMPZP RPCON NUND P PJSM, clean wellhead. Install tree adapter flange & tree. 09/25/2007 00:00 02:00 2.00 11,840 11,840 COMPZP RPCOh NUND P PJSM, Finish NU tree. Tree orientation witnessed by DSO. 02:00 02:30 0.50 11,840 11,840 COMPZP RPCON DHEQ P Test tbg head adaptere 250/5000 psi f/ 10 min. OK. Holding 5200 psi on SSSV control line. 02:30 04:00 1.50 11,840 11,840 COMPZP RPCOJ SFEQ P Pull BPV, set 2 -way check, test tree 250 / 5000 psi, OK. Pull 2-way check. Page 16 of 17 Time L oss Date From To Dur Code Sub 09/25/2007 04:00 04:30 0.50 11,840 11,840 COMPZIN RPCON RURD P PJSM, RU Little Red Hot Oil. P -test all lines. 04:30 05:30 1.00 11,840 11,840 COMPZIN RPCON CIRC P Pumping 130 bbls diesel freeze rotect. 05:30 06:30 1.00 11,840 11,840 COMPZIN RPCON OTHR P Allow diesel column to equalize in wellbore / tb . 06:30 07:30 1.00 11,840 11,840 COMPZIN RPCOJ OTHR P Set BPV, tag tree BPV set. 07:30 08:00 0.50 11,840 11,840 COMPZP RPCON OTHR P PJSM, move Nordic -3 off 2N -310 wellhead. NORDIC RIG 3 RELEASED THIS DATE 9 -25 -07 0800 HRS. Rage 17 of 17 • 2N -310 Well Events Summary DATE Summary 10111/07 TAGGED @ 11715' SLM. PULLED DCK @ 10447' RKB. IN PROGRESS. 10/12/07 SET DV @ 10447' RKB. MITIA 3500 PSI, GOOD. DRIFTED WITH 21' x 3.45" DUMMY GUN TO 11715' SLM (1250# P/U WGT). 10/20/07 HARD TAG AT 11753' CTMD,CIRCULATED CLEAN SEAWATER FROM TD TO 4000' CTMD, LEAVING WELL FREEZE PROTECTED FROM 4000' CTMD ( 2600' TVD) TO SURFACE WITH 60 BBLS OF 60/40 METH. TURN WELL OVER TO DSO ((IN PROGRESS)) 10/30/07 CBL ATTEMPTED, TOOLS UNABLE TO FALL PAST 2350' MADE THREE DIFFERENT ATTEMPTS, RAN DEPTH DETERMINATION AND TAGGED TD AT 11740'(2552 PSIA / 153 DEGF) 11/4/07 JETTED TUBING DOWN TO 4325' CTMD RETURNING GRAY COLORED MATERIAL. LOGGED CEMENT BOND LOG USING SCHLUMBERGER MEMORY TOOLS. LOGGED 3 PASSES FROM 11737' UP TO 10500' CTMD. HELD 28 BING WHEN LOGGING 2 OF THE 3 PASSES. MEMORY TOOLSTRING IN GOOD CONDITION AND RETURNED GOOD DATA. WELL FREEZE PROTECTED DOWN TO 4400' CTMD. 11/16/07 ATTEMPTED TO PERFORATE ESKER SAND, TOOLS FELL TO 5100' - ABORTED SECOND ATTEMPT TO FALL DUE TO WORSENING WEATHER. PLANS INCLUDE SECURING MULTIPLE +2 -7/8" ROLLERS AND PERFORMING JOB TOMORROW. ((IN PROGRESS)) 11/17/07 PERFORATED ESKER SAND FROM 11670'- 11690' MD WITH 2.88" HSD, PJ2906, HMX, 6 SPF, 60 DEGREE PHASING (120 HOLES) WHP DROPPED TO 2000 PSI IN 5 MINUTES - WHP 600 PSI BACK AT SURFACE > STATIC BOTTOM HOLE PRESSURE SURVEY - 11680': 2578.1 PSIA / 154.3 DEGF , 10452': 2013.7 PSIA, 126.2 DEGF 11/18/07 TAGGED AT 11697' SLM. IN PROGRESS. 11/19/07 PULLED DV FROM 10447' RKB AND REPLACED WITH HES SIDE POCKET GAUGE. TESTED IA TO 3500 PSI, GOOD. ATTEMPTED SET FRAC SLEEVE IN SCSSSV. UNABLE TO WORK PAST RESTRICTION AT 299' SLM. GAUGED TBG TO 3.83" TO SCSSSV. IN PROGRESS. 11/20/07 BRUSH TUBING DOWN TO AND INCLUDING 2.81" PROFILE IN SCSSSV AT 2202' RKB. SET FRAC SLEEVE AT 2202' RKB. TIGHT SPOTS IN TUBING AT 299', 395', 639', 1407', 1560', 1687' AND 2081' SLM. JOB COMPLETE. 11/25/07 Frac Stim Esker formation with a total of 158748# of 16/20 Carbolite 1122# left in WB 12 PPA on formation 2361 BBL of SW, with an average pressure of 4632 psi. Frac pumped to completion. ISIP= 2074 psi, 5 min pressure = 1940 psi. Antimony, Iridium, Scandium RA Tracer Pump druing propped stages and BF. (75 Diesel FP in flush). EST BHP =2291 PAI .38 psi /ftr JOB COMPLETED. 11/26/07 Perform post frac fill clean out, Tagged fill @ 11379 CTMD, Cleaned out to hard tag of 11708 CTMD. Freeze protected well, Left S /I. KRU 2N -310 ConocoPhillips Alaska, Inc. API: 501032054900 Well Type: SVC An le TS: I d TUBING SSSV Type: TRDP Oria Completion: 9/25/2007 Angle TD: 19 den @ 11840 (0- 10604, Annular Fluid: Last W /O: Rev Reason: PERF, FRAC, TAG, ODA.500, GLV C/O ID 3.833) Reference Log: 30' RKB Ref Loa Date: Last U date: 12/9/2007 Last Tag: 11697' SLM TD: 11840 ftKB Last Tag Date: 11/18/2007 Max Hole Angle: 71 de 2997 Casino Strip - ALL STMNW . £ • . :; , Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 110 110 154.00 API 5L WELDED SURFACE X65LP (03530, SURFACE 9.625 0 3530 2397 40.00 L -80 BTC OD.9.625, INTERMEDIATE 7.000 0 10828 5152 26.00 L -80 BTCM Wt40.00) _ LINER 4.500 10617 11840 11840 12.60 L -80 IBTM Tabin Stffl I - T NN Size Top I Botto I TVD Wt Grade Thread TERMEDIATE 4.500 0 10604 4983 12.60 L -80 IBTM (0 10628, Petfor l SU `.. - `t.. _ -- �_ OD:7.000, Interval TVD Zone I Status:T Ft JSPFJ Date I Type Comment Wt:26.00) 11670 - 11690 5876-5895 20 1 6 11/17/2007 1 IPERF 2.88 HSD PJ 2906 HMK, 60 Deq phase . StImuWiftm & Trea tments Interval I Date I Type Comment 11670-11690 1 1/25/2007 FRAC 158748# 16/20 CARBOLITE Gwis Mart 1w9NVa : . St MD TVD Man Mfr Man Type V Mfr V Type VOID Latch Port TRO Date Run Vlv Cmnt 1 3504 2388 CAMCO KBG -2 -1R DMY 1.0 BK -5 0.000 0 9124/2007 2 6665 3488 CAMCO KBG -2 -1R DMY 1.0 BK -5 0.000 0 9/24/2007 3 9185 4357 CAMCO KBG -2 -1R DMY 1.0 BK -5 0.000 0 9/24/2007 4 10447 4877 CAMCO KBG -2 -1R OV 1.0 BK 0.313 0 12/9/2007 Oth#r bWat. soulm. etc.) - COMPLETION Depth TVD Type Description ID 26 26 HANGER FMC TUBING HANGER 3.958 2202 1919 SSSV CAMCO TRM- 4PE -CF SSSV w /DB PROFILE 3.813 SLEEVE 10527 4930 SLEEVE BAKER CMD'X' PROFILE SLIDING SLEEVE 3.813 10527 - 10528, 10613 4990 SEAL BAKER SEAL TIE BACK ASSEMBLY 3.930 013:5.490) 10617 4993 PBR /SBR BAKER PBR/SBR 5.000 10633 5005 PACKER BAKER HRD ZXP LINER TOP PACKER 3.875 10642 5011 HANGER BAKER FLEXLOCK LINER HANGER 3.875 10661 5025 NIP LINER CAMCO DB -6 NIPPLE 3.750 SEAL 10613 - 10614, 013:4.940) PBR/SBR 10617 - 10616, OD:5.790) FRAC 11670 - 11690) Perf 11670 - 11690) LINER 10617 - 11840, 013:4.500, Wt:12.60) II Halliburton Company Survey Report Company; ConocoPhillips Alaska Inc. Date: 10/11/2007 Time: 13:13:37 Page: 1 Field: Kuparuk River Unit Co- ordinate(NE) Reference: Weil 2N -310, True North Site: Kuparuk 2N Pad Vertical (M) Reference: 2N-310:14&6 Weil: 2N -340 Section (VS) Reference: Well (0MN,O.00E,64.47Ati) Wellpatb: 2N-310 Survey Calculation Method: Minimum Curvature Db: O €ade 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: 2N -310 Slot Name: Well Position: +N / -S 13.35 ft Northing: 5911983.24 It Latitude: 70 10 13.727 N +E / -W 59.01 ft Easting : 460991.31 It Longitude: 150 18 50.211 W Position Uncer tainty: 0.00 it Wellpath: 2N -310 Drilled From: Well Ref. Point 50- 103 - 20549 -00 Tie -on Depth: 30.00 It Current Datum: 2N -310: Height • 148.60 It Above System Datum: Mean Sea Level Magnetic Data: 8/20/2007 Declination: 22.78 deg Field Strength: 57576 nT Mag Dip Angle: 80.64 deg Vertical Section: Depth From (TVD) +N / -S +E / -W Direction ft It It deg 30.00 0.00 0.00 64.47 Survey Program for Definitive Wellpath Date: 8/22/2007 Validated: No Version: 6 Actual From To Survey Toolcode Tool Name It ft 79.00 696.00 2N -310 gyro (79.00 - 696.00) CB- GYRO -SS Camera based gyro single shot 740.37 740.37 2N -310 MWD +IIFR +SAG +MS 740MD ( MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 810.00 810.00 2N -310 gyro 810MD (810.00 -810. CB- GYRO -SS Camera based gyro single shot 878.03 11744.19 2N -310 MWD +IIFR +SAG +MS (878.03 MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC Survey I MD Incl Azim TVD Sys TVD- NIS E/W MapN MapE Tool It deg deg ft ft ft It ft........ ft - , . 30.00 0.00 0.00 30.00 - 118.60 0.00 0.00 5911983.24 460991.31 TIE LINE 79.00 0.73 24.69 79.00 -69.60 0.28 0.13 5911983.52 460991.44 CB- GYRO -SS 170.00 0.80 22.73 169.99 21.39 1.40 0.62 5911984.63 460991.94 CB- GYRO -SS 266.00 0.67 335.36 265.98 117.38 2.52 0.64 5911985.76 460991.97 CB- GYRO -SS 351.00 1.30 285.39 350.97 202.37 3.23 -0.49 5911986.47 460990.83 CB- GYRO -SS 444.00 0.65 222.17 443.96 295.36 3.12 -1.87 5911986.37 460989.46 CB- GYRO -SS 477.00 0.70 203.14 476.96 328.36 2.80 -2.07 5911986.05 460989.25 CB- GYRO -SS 505.00 0.81 231.93 504.96 356.36 2.52 -2.29 5911985.77 460989.03 CB- GYRO -SS 536.00 1.61 192.61 535.95 387.35 1.96 -2.56 5911985.21 460988.76 CB- GYRO -SS 565.00 3.18 182.90 564.92 416.32 0.76 -2.69 5911984.01 460988.62 CB- GYRO -SS 597.00 4.84 176.47 596.84 448.24 -1.48 -2.65 5911981.78 460988.65 CB- GYRO -SS 625.00 4.75 166.06 624.75 476.15 -3.78 -2.30 5911979.47 460988.99 CB- GYRO -SS 696.00 5.32 118.83 695.50 546.90 -8.22 1.29 5911975.01 460992.56 CB- GYRO -SS 740.37 6.81 105.96 739.62 591.02 -9.94 5.62 5911973.27 460996.88 MWD +IFR- AK- CAZ -SC 810.00 10.23 101.37 808.48 659.88 -12.29 15.66 5911970.87 461006.90 CB- GYRO -SS 878.03 12.60 93.91 875.16 726.56 -13.99 28.99 5911969.10 461020.22 MWD +IFR- AK- CAZ -SC 927.72 14.81 89.86 923.43 774.83 -14.35 40.75 5911968.69 461031.98 MWD +IFR- AK- CAZ -SC 973.32 16.67 85.70 967.32 818.72 -13.84 53.10 5911969.13 461044.33 MWD +IFR- AK- CAZ -SC 1019.13 18.43 84.15 1011.00 862.40 -12.61 66.85 5911970.29 461058.09 MWD +IFR- AK- CAZ -SC 1113.33 21.69 77.69 1099.48 950.88 -7.38 98.69 5911975.35 461089.95 MWD +IFR- AK- CAZ -SC 1212.43 24.51 75.50 1190.63 1042.03 1.67 136.49 5911984.21 461127.79 MWD +IFR- AK- CAZ -SC 1305.86 25.28 74.61 1275.38 1126.78 11.82 174.49 5911994.16 461165.84 MWD +IFR- AK- CAZ -SC 1397.74 28.21 72.51 1357.42 1208.82 23.56 214.12 5912005.69 461205.53 MWD +IFR- AK- CAZ -SC 1494.00 31.55 70.12 1440.88 1292.28 38.96 259.52 5912020.86 461251.00 MWD +IFR- AK- CAZ -SC 1586.45 39.26 68.79 1516.17 1367.57 57.80 309.61 5912039.44 461301.19 MWD +IFR- AK- CAZ -SC 1678.47 42.73 67.88 1585.62 1437.02 80.10 365.70 5912061.44 461357.38 MWD +IFR- AK- CAZ -SC 1772.25 43.56 67.80 1654.04 1505.44 104.29 425.09 5912085.32 461416.89 MWD +IFR- AK- CAZ -SC Halliburton Company Survey Report Company. ConocoPhiliips Alaska Inc Bate: 10/11/2007 Time: 13:13 :37 Page: 2 Field: Kuparuk River Unit Co- ordinate(NE) Reference: :Well: 2N;310, True North S #e:. Kuparuk 2N Pad Vertical (TVD) Reference: 2N-310:148,6 Well: 2N -310 Section(VS)Reference, - `Well(O.00N,O.00E,$4.47Azi) Welipath: 2N -310 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Ind Aaim TVD Sys TVD N/S FJW MapN MapE Tool it deg deg it It 4 ft ft it 1866.75 45.17 67.01 1721.60 1573.00 129.68 486.09 5912110.40 461478.01 MWD +IFR- AK- CAZ -SC 1961.94 50.67 66.69 1785.37 1636.77 157.45 551.02 5912137.83 461543.08 MWD +IFR- AK- CAZ -SC 2059.50 54.88 65.94 1844.37 1695.77 188.66 622.14 5912168.68 461614.35 MWD +IFR- AK- CAZ -SC 2154.16 59.25 65.63 1895.83 1747.23 221.25 694.58 5912200.88 461686.95 MWD +IFR- AK- CAZ -SC 2247.77 64.05 64.82 1940.26 1791.66 255.77 769.35 5912235.02 461761.89 MWD +IFR- AK- CAZ -SC 2341.70 68.05 63.63 1978.39 1829.79 293.10 846.63 5912271.95 461839.35 MWD +IFR- AK- CAZ -SC I 2435.85 69.11 63.27 2012.77 1864.17 332.28 925.03 5912310.72 461917.95 MWD +IFR- AK- CAZ -SC 2526.25 68.10 63.31 2045.75 1897.15 370.11 1000.22 5912348.16 461993.32 MWD +IFR- AK- CAZ -SC 2620.39 67.18 63.07 2081.56 1932.96 409.38 1077.92 5912387.02 462071.22 MWD +IFR- AK- CAZ -SC 2714.65 68.19 63.18 2117.35 1968.75 448.80 1155.70 5912426.03 462149.20 MWD +IFR- AK- CAZ -SC 2808.16 68.52 63.49 2151.84 2003.24 487.80 1233.38 5912464.63 462227.06 MWD +IFR- AK- CAZ -SC 2901.40 69.96 63.65 2184.89 2036.29 526.61 1311.45 5912503.03 462305.32 MWD +IFR- AK- CAZ -SC 2996.56 71.19 63.41 2216.54 2067.94 566.61 1391.78 5912542.61 462385.86 MWD +IFR- AK- CAZ -SC 3090.86 70.40 63.25 2247.56 2098.96 606.58 1471.36 5912582.17 462465.63 MWD +IFR- AK- CAZ -SC 3184.84 70.09 63.27 2279.32 2130.72 646.38 1550.35 5912621.55 462544.82 MWD +IFR- AK- CAZ -SC 3278.91 69.42 62.46 2311.87 2163.27 686.63 1628.89 5912661.40 462623.56 MWD +IFR- AK- CAZ -SC 3372.96 70.56 63.07 2344.06 2195.46 727.07 1707.46 5912701.43 462702.33 MWD +IFR- AK- CAZ -SC 3458.84 70.30 62.41 2372.82 2224.22 764.13 1779.40 5912738.11 462774.45 MWD +IFR- AK- CAZ -SC 3553.53 70.43 62.80 2404.64 2256.04 805.17 1858.58 5912778.74 462853.83 MWD +IFR- AK- CAZ -SC 3616.17 70.09 62.71 2425.80 2277.20 832.16 1911.00 5912805.45 462906.38 MWD +IFR- AK- CAZ -SC 3710.72 70.15 62.42 2457.95 2309.35 873.12 1989.91 5912846.01 462985.50 MWD +IFR- AK- CAZ -SC 3806.50 70.18 61.81 2490.45 2341.85 915.26 2069.55 5912887.73 463065.34 MWD +IFR- AK- CAZ -SC 3900.07 68.54 63.87 2523.43 2374.83 955.24 2147.44 5912927.30 463143.44 MWD +IFR- AK- CAZ -SC 3994.50 68.06 63.26 2558.35 2409.75 994.30 2226.01 5912965.95 463222.19 MWD +IFR- AK- CAZ -SC 4089.80 67.86 65.00 2594.11 2445.51 1032.84 2305.49 5913004.08 463301.86 MWD +IFR- AK- CAZ -SC 4184.81 67.88 64.68 2629.91 2481.31 1070.26 2385.15 5913041.08 463381.71 MWD +IFR- AK- CAZ -SC 4279.00 69.59 65.50 2664.07 2515.47 1107.22 2464.76 5913077.63 463461.50 MWD +IFR- AK- CAZ -SC 4373.26 69.41 65.27 2697.08 2548.48 1144.00 2545.02 5913113.99 463541.95 MWD +IFR- AK- CAZ -SC i 4469.55 70.41 64.24 2730.15 2581.55 1182.57 2626.81 5913152.13 463623.93 MWD +IFR- AK- CAZ -SC 4563.84 70.51 64.03 2761.69 2613.09 1221.33 2706.77 5913190.48 463704.08 MWD +IFR- AK- CAZ -SC 4659.85 70.74 63.84 2793.54 2644.94 1261.13 2788.13 5913229.86 463785.63 MWD +IFR- AK- CAZ -SC 4755.33 70.18 63.46 2825.47 2676.87 1301.07 2868.77 5913269.37 463866.46 MWD +IFR- AK- CAZ -SC 4847.69 69.94 63.72 2856.97 2708.37 1339.68 2946.53 5913307.59 463944.41 MWD +IFR- AK- CAZ -SC 4942.31 69.84 63.25 2889.51 2740.91 1379.35 3026.03 5913346.84 464024.11 MWD +IFR- AK- CAZ -SC 5038.07 69.98 62.80 2922.40 2773.80 1420.14 3106.18 5913387.22 464104.46 MWD +IFR- AK- CAZ -SC 5133.88 70.08 62.54 2955.12 2806.52 1461.49 3186.18 5913428.14 464184.67 MWD +IFR- AK- CAZ -SC 5228.60 70.09 61.85 2987.39 2838.79 1503.03 3264.95 5913469.27 464263.64 MWD +IFR- AK- CAZ -SC 5323.32 69.21 63.94 3020.33 2871.73 1543.49 3344.00 5913509.32 464342.89 MWD +IFR- AK- CAZ -SC i 5417.72 69.02 63.36 3053.98 2905.38 1582.64 3423.03 5913548.06 464422.12 MWD +IFR- AK- CAZ -SC 5512.74 68.84 64.90 3088.14 2939.54 1621.32 3502.81 5913586.33 464502.09 MWD +IFR- AK- CAZ -SC 5605.98 68.53 64.40 3122.04 2973.44 1658.51 3581.31 5913623.11 464580.77 MWD +IFR- AK- CAZ -SC 5699.38 70.44 65.84 3154.77 3006.17 1695.31 3660.66 5913659.49 464660.30 MWD +IFR- AK- CAZ -SC 5794.53 70.22 65.15 3186.80 3038.20 1732.47 3742.19 5913696.23 464742.01 MWD +IFR- AK- CAZ -SC 5888.72 69.93 64.43 3218.89 3070.29 1770.19 3822.31 5913733.53 464822.31 MWD +IFR- AK- CAZ -SC 5982.85 69.91 64.10 3251.21 3102.61 1808.57 3901.94 5913771.50 464902.14 MWD +IFR- AK- CAZ -SC 6077.10 69.81 63.49 3283.66 3135.06 1847.65 3981.34 5913810.16 464981.73 MWD +IFR- AK- CAZ -SC 6171.82 69.61 63.09 3316.51 3167.91 1887.58 4060.70 5913849.68 465061.28 MWD +IFR- AK- CAZ -SC 6267.62 69.28 62.56 3350.15 3201.55 1928.55 4140.50 5913890.23 465141.29 MWD +IFR- AK- CAZ -SC I ' 6362.50 69.79 63.42 3383.32 3234.72 1968.92 4219.69 5913930.19 465220.68 MWD +IFR- AK- CAZ -SC 6457.04 68.99 63.19 3416.60 3268.00 2008.67 4298.75 5913969.53 465299.93 MWD +IFR- AK- CAZ -SC 6551.07 70.45 64.53 3449.19 3300.59 2047.52 4377.93 5914007.97 465379.30 MWD +IFR- AK- CAZ -SC 6645.27 70.09 64.36 3480.99 3332.39 2085.77 4457.92 5914045.80 465459.49 MWD +IFR- AK- CAZ -SC 6739.06 70.27 64.13 3512.79 3364.19 2124.11 4537.39 5914083.73 465539.14 MWD +IFR- AK- CAZ -SC • 0 Halliburton Company Survey Report Company: ConowPhillips Alaska Inc. Date, 10/11/2007 Time: 13.13:37 Page: 3 Field: Kuparuk River unit Co- ordinate(NE) Reference: Well- 2N-310, True North Site: Kuparuk 2N Pad Vertical (TVD) Reference: 2N -310: 148.6 '1'F'en; 2N -310 section (V$) Reference: Well (O.00N,O.00E,64.47Azi) Wellpath: 2N -310 Survey Calculation Method: Minim Curvature Db: Oracle Survey MD incl Azim TVD Sys TVD N/S E/W MapN MapE Tool It deg deg ft ft ft It ft ft 6834.25 70.20 63.66 3544.98 3396.38 2163.53 4617.84 5914122.72 465619.78 MWD +IFR- AK- CAZ -SC 6930.32 69.92 63.28 3577.75 3429.15 2203.87 4698.64 5914162.64 465700.78 MWD +IFR- AK- CAZ -SC 7024.18 69.69 62.65 3610.15 3461.55 2243.90 4777.10 5914202.27 465779.44 MWD +IFR- AK- CAZ -SC 7118.15 70.11 64.13 3642.44 3493.84 2283.43 4856.00 5914241.39 465858.53 MWD +IFR- AK- CAZ -SC 7211.78 69.91 63.28 3674.45 3525.85 2322.41 4934.88 5914279.95 465937.61 MWD +IFR- AK- CAZ -SC 7306.33 69.74 62.62 3707.06 3558.46 2362.77 5013.92 5914319.90 466016.85 MWD +IFR- AK- CAZ -SC 7402.49 69.62 62.30 3740.45 3591.85 2404.46 5093.88 5914361.18 466097.01 MWD +IFR- AK- CAZ -SC 7497.16 69.98 64.07 3773.15 3624.55 2444.54 5173.17 5914400.84 466176.50 MWD +IFR- AK- CAZ -SC 7590.85 70.21 63.82 3805.04 3656.44 2483.23 5252.31 5914439.12 466255.83 MWD +IFR- AK- CAZ -SC 7686.09 70.05 63.51 3837.42 3688.82 2522.96 5332.58 5914478.44 466336.30 MWD +IFR- AK- CAZ -SC 7779.23 69.85 63.42 3869.35 3720.75 2562.05 5410.86 5914517.12 466414.77 MWD +IFR- AK- CAZ -SC 7872.36 69.60 63.17 3901.62 3753.02 2601.31 5488.90 5914555.97 466493.01 MWD +IFR- AK- CAZ -SC 7966.78 69.57 62.74 3934.55 3785.95 2641.55 5567.71 5914595.80 466572.02 MWD +IFR- AK- CAZ -SC 8062.03 70.37 64.37 3967.18 3818.58 2681.39 5647.84 5914635.23 466652.34 MWD +IFR- AK- CAZ -SC 8156.93 70.27 64.25 3999.14 3850.54 2720.13 5728.36 5914673.54 466733.05 MWD +IFR- AK- CAZ -SC 8250.22 70.01 64.30 4030.83 3882.23 2758.22 5807.41 5914711.22 466812.28 MWD +IFR- AK- CAZ -SC 8344.77 69.39 64.21 4063.64 3915.04 2796.73 5887.28 5914749.32 466892.35 MWD +IFR- AK- CAZ -SC 8438.79 68.99 64.17 4097.04 3948.44 2835.00 5966.40 5914787.17 466971.66 MWD +IFR- AK- CAZ -SC 8532.27 68.50 64.12 4130.93 3982.33 2872.99 6044.80 5914824.76 467050.24 MWD +IFR- AK- CAZ -SC 8625.51 70.26 65.59 4163.76 4015.16 2910.06 6123.79 5914861.42 467129.42 MWD +IFR- AK- CAZ -SC 8718.42 69.96 65.54 4195.37 4046.77 2946.20 6203.34 5914897.14 467209.14 MWD +IFR- AK- CAZ -SC 8813.69 69.87 63.95 4228.09 4079.49 2984.38 6284.26 5914934.89 467290.25 MWD +IFR- AK- CAZ -SC 8908.41 69.82 63.88 4260.73 4112.13 3023.47 6364.12 5914973.58 467370.30 MWD +IFR- AK- CAZ -SC 9001.84 69.62 63.97 4293.11 4144.51 3062.00 6442.84 5915011.69 467449.21 MWD +IFR- AK- CAZ -SC 9095.43 69.48 64.01 4325.81 4177.21 3100.45 6521.65 5915049.73 467528.21 MWD +IFR- AK- CAZ -SC 9190.38 69.86 63.05 4358.80 4210.20 3140.14 6601.35 5915089.00 467608.11 MWD +IFR- AK- CAZ -SC 9284.74 69.30 62.60 4391.72 4243.12 3180.52 6680.02 5915128.98 467686.97 MWD +IFR- AK- CAZ -SC 9379.19 69.95 63.51 4424.61 4276.01 3220.64 6758.94 5915168.69 467766.10 MWD +IFR- AK- CAZ -SC 9473.65 69.56 62.74 4457.29 4308.69 3260.70 6838.00 5915208.34 467845.35 MWD +IFR- AK- CAZ -SC 9567.91 70.27 64.27 4489.66 4341.06 3300.19 6917.22 5915247.41 467924.77 MWD +IFR- AK- CAZ -SC 9662.11 69.89 63.56 4521.76 4373.16 3339.13 6996.77 5915285.94 468004.51 MWD +IFR- AK- CAZ -SC 9756.76 69.63 63.54 4554.50 4405.90 3378.69 7076.28 5915325.08 468084.21 MWD +IFR- AK- CAZ -SC 9852.03 68.12 63.65 4588.84 4440.24 3418.21 7155.87 5915364.19 468164.00 MWD +IFR- AK- CAZ -SC 9942.56 67.84 63.12 4622.78 4474.18 3455.81 7230.90 5915401.39 468239.22 MWD +IFR- AK- CAZ -SC 10037.19 65.16 63.41 4660.51 4511.91 3494.85 7308.40 5915440.03 468316.91 MWD +IFR- AK- CAZ -SC 10131.43 62.66 63.13 4701.95 4553.35 3532.91 7383.99 5915477.70 468392.68 MWD +IFR- AK- CAZ -SC ! 10225.54 59.50 61.89 4747.46 4598.86 3570.91 7457.05 5915515.32 468465.94 MWD +IFR- AK- CAZ -SC 10319.06 55.36 62.63 4797.79 4649.19 3607.60 7526.79 5915551.64 468535.85 MWD +IFR- AK- CAZ -SC 10412.44 50.82 63.08 4853.86 4705.26 3641.66 7593.21 5915585.36 468602.44 MWD +IFR- AK- CAZ -SC 10506.95 47.25 62.89 4915.81 4767.21 3674.07 7656.78 5915617.44 468666.17 MWD +IFR- AK- CAZ -SC 10601.25 44.64 62.55 4981.38 4832.78 3705.13 7717.01 5915648.18 468726.55 MWD +IFR- AK- CAZ -SC 10695.73 41.83 63.33 5050.20 4901.60 3734.58 7774.63 5915677.33 468784.32 MWD +IFR- AK- CAZ -SC 10789.42 38.66 64.89 5121.71 4973.11 3761.02 7829.06 5915703.49 468838.88 MWD +IFR- AK- CAZ -SC 10798.89 38.70 64.91 5129.10 4980.50 3763.54 7834.42 5915705.98 468844.25 MWD +IFR- AK- CAZ -SC 10835.20 38.47 65.30 5157.48 5008.88 3773.07 7854.96 5915715.40 468864.84 MWD +IFR- AK- CAZ -SC 10931.30 40.51 65.10 5231.64 5083.04 3798.70 7910.43 5915740.75 468920.44 MWD +IFR- AK- CAZ -SC 11024.09 39.53 64.63 5302.70 5154.10 3824.05 7964.45 5915765.81 468974.58 MWD +IFR- AK- CAZ -SC 11121.24 36.11 66.60 5379.44 5230.84 3848.67 8018.68 5915790.15 469028.93 MWD +IFR- AK- CAZ -SC 11214.64 31.84 68.97 5456.88 5308.28 3868.45 8066.96 5915809.68 469077.31 MWD +IFR- AK- CAZ -SC 11308.72 27.72 70.53 5538.52 5389.92 3884.66 8110.77 5915825.66 469121.20 MWD +IFR- AK- CAZ -SC 1 11403.85 20.73 68.78 5625.22 5476.62 3898.14 8147.37 5915838.95 469157.86 MWD+IFR- AK- CAZ -SC 11499.23 18.59 69.39 5715.03 5566.43 3909.60 8177.34 5915850.26 469187.89 MWD +IFR- AK- CAZ -SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 10/1112007 Time: 13:1137 Page: 4 Field: Kuparuk River Unit Co- ordinate(NE) Reference: Well: 2N -310, True North Sate: Kuparuk 2N Pad Vertical (TVD) Reference: 2N -310: 148.6 Well: 2N -310 Section (VS) Reference: Well (O.00N,O.00E,64,47Ati) Welipath: 2N -310 Survey Calculation Method: Minimum Curvature Db: Oracle Survey NID Inel Azim TVD Sys TVD N/S E/W MapNz MspE Tool ft deg deg ft It .4 ft ft z ft 11594.32 20.11 65.12 5804.75 5656.15 3921.82 8206.36 5915862.33 469216.97 MWD +IFR- AK- CAZ -SC 11689.29 19.73 65.67 5894.04 5745.44 3935.29 8235.78 5915875.65 469246.45 MWD +IFR- AK- CAZ -SC 11744.19 19.28 65.81 5945.79 5797.19 3942.82 8252.49 5915883.09 469263.20 MWD +IFR- AK- CAZ -SC 11840.00 19.28 65.81 6036.23 5887.63 3955.79 8281.35 5915895.90 469292.12 - PROJECTED to TD TABLE 2: SIDEWALL CORE DEPTHS Depth Formation Result Condition Show Destination Description 1 11142.50 Cairn Success Good None Core Lab Sdst, of , fair porosity, no show. 2 11144.00 Cairn Success Sli soft Weak Core Lab Sdst, of -f , fair poros, 25 -30% fluor 3 11161.50 Cairn Success Good Mod Baseline Sdst, of -f , fair poros, 40 -50% fluor 4 11166.00 Cairn Success Good Mod Baseline Sdst, of , sli oil stain, 25% fluor 5 11167.50 Cairn Success Good Mod Core Lab Sdst, f , good por, sli oil stain 6 11172.00 Cairn Success Good Mod Baseline Sdst, of -f , weak oil stain, 50% fluor 7 11182.00 Cairn Success Good Weak Core Lab Sdst, f , weak show, 10% fluor 8 11193.00 Cairn Success Good Weak Core Lab Sdst, of , weak show, 10% fluor 9 11194.00 Cairn Success Good Weak Core Lab Sdst, f , weak show, 15 -20% fluor 10 11213.00 Cairn Success Good Mod Baseline Sdst, f , sli oil stain, 50% fluor 11 11219.00 Cairn Success Good Mod Baseline Sdst, f , sli oil stain /odor, 40% fluor 12 11226.00 Cairn Success Good Good Baseline Sdst, f , mod oil stain /odor, 50% fluor 13 11281.00 Bermuda Success Good Mod Baseline Sdst, f , sli oil stain /odor, 50% fluor 14 11307.00 Bermuda Failed - - - -- - - - -- - - - -- Core attempt failed. POOH to surface. 15 11324.50 Bermuda NA NA NA NA NA 16 11341.50 Bermuda NA NA NA NA NA 17 11361.00 Bermuda NA NA NA NA NA 18 11377.00 Bermuda NA NA NA NA NA 19 11406.50 Bermuda NA NA NA NA NA 20 11651.00 Esker NA NA NA NA NA 21 11665.00 Esker NA NA NA NA NA 22 11679.00 Esker NA NA NA NA NA 23 11688.00 Esker NA NA NA NA NA 24 11697.50 Esker NA NA NA NA NA 25 11704.00 Esker NA NA NA NA NA NA = Not attempted. Pulled tool out of hole after 14 core (S WC tool failed). Summary_2N_310.doc Page 2 of 2 10/10/2007 it i 2N -310 TABLE 1: FORMATION TOPS AND MARKERS MD TVD TVDSS TVD +/- to To /Marker prognosis prognosis Prognosis MD actual actual TVDSS Prognosis 12 -1/4" Surface Casing Borehole: Permafrost . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . W. Sak Sands ( Top) ..................................... ............................... .... . .. . . . . . . . . . ... . . . . . . . . . . ... . . ... . . . . . . . .... . . . . . . . . . . . ..... . . . . . . W. Sak Sands (Base) 9 5/8" Casing Shoe 3,520' 2,400' - 2,249' 3,520' 2,393' - 2,244' -7 C80 3,822' 2,505' - 2,355' 3,847' 2,504' - 2,355' -1' ....... ...... .._ ................................................. _......._........... _. .... _..__.._.............. _ ........ ..._....... C50 8,072' 3,980' - 3,830' 8,010' 3,949' - 3,800' -31' ... ................................................................._.._......... .........._...._..._..._....... C40 8,734' 4,210' - 4,060' 8,730' 4,199' - 4,050' -11' . ............................... .................................._............._..._.._.................. ......_..............._...._... C37 9,152' 4,355' - 4,205' 9,238' 4,375' - 4,226' 20' ........... . .................................. . . . . . _ . . . . . . . . . . . . . ... . . . . . . . . . . . . . . . . . . . . . . . . . .. . _ . . . . . . . . . . . . . . . . . . . . . . . . ... . .. . . . . . .. . . . . . . . . . T7 10,705' 5,065' - 4,915' 10,678' 5,037' - 4,888' -28' ............ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7 "...Casing._ Shoe ...................................................... ............................... 10,800' 5,137' - 4,987' 10,828' 5,152' - 5,003' 15' T4 10,968' 5,274' - 5,124' 11,079' 5,345' - 5,196' 71' ............ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cairn Top 10,997' 5,300' - 5,150' 11,098' 5,360' - 5,211' 60' Cairn Bottom 11,089' 5,380' - 5,230' 11,243' 5,479' - 5,330' 99' T3 (Top Reservoir) 11,179' 5,459' - 5,309' 11,270' 5,504' - 5,355' 45' T2 (Base Reservoir) 11,273' 5,544' - 5,394' 11,353' 5,577' - 5,428' 33' .................................................._........................._..._...._._..._..... ......_........................ . C35 11,471' 5,725' - 5,575' 11,484' 5,700' - 5,551' -25' .. ........... ......... . .............................. ................... . .................. _............................ ........ ............ ........... K -3 11,559' 5,750' - 5,601' Esker To 11,593' 5,834' - 5,684' 11,646' 5,852' - 5,703' 18' Esker (Base) 11,707' 5,910' - 5,761' TD 11,840' 6,058' - 5,908' 11,840' 6,036' - 5,887' 1 -22' Twenty five core points were chosen (Table 2) from the 2N -310 Cairn, Bermuda and Esker formations based on information pooled from MWD/LWD data, cuttings samples (shows) and formation fluid ratios (wetness, balance and character). Cores were acquired using a Schlumberger drill pipe conveyed rotary sidewall coring tool. Twelve cores were attempted from the Cairn and two from the Bermuda. The second attempt from the Bermuda (14 overall) was unsuccessful due to the coring tool motor failing/seizing. The tool was pulled and the remaining core points were cancelled. Thick solids were caked around the core motor/bit area after inspection of the tool at surface. The thirteen successful cores consisted of mainly very fine to fine grained sandstone, some with weak to moderate hydrocarbon fluorescence. AN �. � t�t)t,'� 12/27/07 b11l11111IateI -ep �:,3' "i: �` 4.1;� i'°,'.,:?ra:; i ;`_ ;Iu;S. a_ :ri'•,§�S"PIIi:a! ' 3 NO. 4537 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 2N -327 11837491 OH LDWG EDIT (SONIC SCANNER) ¢jfj 08/08/07 1 1 2N -310 11850433 OH LDWG EDIT (SONIC SCANNER) 09/16/07 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. WELL LOG TRANSMITTAL To: State of Alaska December 18, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7 th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 2N -310 AK -MW- 5033959 1 LDWG formatted CD Rom with verification listing. API #: 50 -103- 20549 -00 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 Alaa,99518 r Date. ' Signed: Mrl 19- Nov -07 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2N -310 Dear Dear Sir /Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie -on Survey: 30.00' MD Window/ Kickoff Survey 0.00' MD (if applicable) Projected Survey: 11,840.00' 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 1 Date �j �7 Signed Please call me at 273 -3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) v'7 -c�q� 11126/07 1 6 4 Schlumbopgop NOV M1,17 NO. 4513 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk • Well Job # Log Description Date BL Color CD 2N-310 11839685 PERF RECORn/SI3HP SURVEY 11117/07 2Z-01A 11837536 PRODUCTION PROFILE 11116/07 3R-14 11839686 LDL 19 11) , 11118107 2M-10 11839687 PRODUCTION PROFILE 11119107 3J -10 11837539 PRODUCTION P 11/19/07 2A-20 11839688 INJECTION PROFILE 11/20/07 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 10 day flowback for 2N -310 0 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, November 21, 2007 11:07 AM To: 'NSK Prod Engr Tech' Cc: 'Guy Schwartz' Subject: RE: 10 day flowback for 2N -310 Bob, Notification is not a problem. As I remember we have talked about the Esker operations previously. Main thing is to report any production volumes actually "sold ". Tom Maunder, PE AOGCC From: NSK Prod Engr Tech [ mailto :nll39 @conocophillips.com) Sent: Wednesday, November 21, 2007 10:38 AM To: Maunder, Thomas E (DOA) Subject: 10 day flowback for 2N -310 Tom, Just a heads up. Following frac job in Esker formation, the plan is to flowback 2N-310 (injector) for 10 days starting Monday Nov. 27th. Based on inquires during my last shift I understand there are no special permits required. Is it OK if I send you these email to confirm we are good to go before these types of events? Or are you overloaded with emails and phone calls already? Bob Buchholz Greater Kuparuk Area Production Engineering Technician Office (907) 659 -7535 NSK -69 Pager (907) 659 -7000 (924) 11/21/2007 11/02/07 SchlumbepUep NO. 4356 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 1D -103 11837528 INJECTION PROFILE I ) :Co_ _J (�Gj� 10127107 1 1L -28 11839680 PRODUCTION PROFILE 10128/07 2N-310 11839674 DDL 10/30107 1C-190 11837524 INJECTION PROFILE 10120107 2V -1 11837526 PRODUCTION PROFILE 10/24107 IH-04 11837527 INJECTION PROFILE 10125107 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. it 11/07/07 Schlumhepgep NO. 4482 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 3J -10 11850465 SBHP SURVEY J ts 10131107 1B -08A 11839682 INJECTION PROFILE L Z -1/ 0 % 10/31107 1D-01 11846458 LDL - n - 11/01107 2A -15 11846459 PRODUCTION PROFILE )41 11/02/07 1E-02 11850470 PRODUCTION PROFILE /S D 0,S 11104107 2N-310 11745242 SCIVIT 11/04/07 1E-119 10687772 OHLDWGEDIT 04108/04 1E -119 10687772 C M R (,Tr jo C 04108/04 1 E -119 10687772 MDT 04/08104 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. L RECEIVED OCT 2 4 2007 nocoPhfll'ps Alaska Oil & Gas Cons- Commission Anchorage TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke AT01486 TO: Christine Mahnken ConocoPhilii P s Alaska A Inc. OGC C in P.O. Box 100360 333 W. 7 Ave., Suite 100 Anchorage AK 99510 -0360 Anchorage, Alaska 99501 -3539 RE: 2N -310 DATE: 10/23/2007 Lemke del ft Tr Tarn 2N -310 Report, color mudlog prints, CDROM Epoch End of Well Report, 2N -310, L. Browne, Jr., 09109/2007; table of contents, equipment and crew, well details, geological data, pressure /formation, drilling data, daily reports, formation logs: Formation MD, TVD; LWD Combo MD and TVD; gas ratio MD and TVD; Drilling dynamics MD and TVD. CDrom contains: Final well report, morning reports, LAS data, pdf files, DML data) remarks files and sample photos. Please check off each item as received, promptly sign and return transmittal if not done at time of data delivery. To all data reci Tents: All data is confidential until State of Alaska desi Hated AOGCC release date CC: Derik Kleibacke , CPAI Geologist ECr Receipt: �-% Date: OCT 2 4 2007 Alaska Oil & Gas Cons. t o,ttrnissiol" AnchorW w P ® G15- Technical Data Management I Conocoftllips I Anchorage, Alaska I Ph: 907.265.6947 Sandra.D.LemkeC&Conocophillips com o?p -0q r.Sxcri MUM cunt kcIvviv uuu ttvv�i� ragC t vt t i • Maunder, Thomas E (DOA) From: Schwartz, Guy L [ Guy. L. Schwattz@conocophillips.com) Sent: Tuesday, October 23, 2007 9:26 AM To: Maunder, Thomas E (DOA) Cc: Walters, Martin N. Subject: Esker /Cairn zone ( e wv&2N- 327) Tom, I checked into the Tam Pool rules and these two zones (Esker and Cairn) are covered within that document. We will of course send out 40Ts after the flow test of these zones and let you know our long term plans. There is a chance they will stay open to production but if P & A is needed will submit a sundry. Guy Schwartz Drilling and Wells Engineer office: 907-265-6968 Cell: 240 -5696 ATO -1512 guy. l.schwartzaconocophillips.com i 10/24/2007 I 10/15/07 Schlumbepp '9 a NO. 4445 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 2N-343 (REDO) 11745232 MEM INJECTION PROFILE Cj a p l 08108107 1B-14 11837493 PRODUCTION PROFILE 08127107 IA-18 11839651 PRODUCTION PROFILE 08130107 IY-18 11837499 PRODUCTION PROFILE C 08/30107 IG-14 11839652 INJECTION PROFILE 08131/07 IA-01 NIA USIT - 06-9 08131107 1Y-04 11839653 INJECTION PROFILE () 09101107 1Y-32 11839655 PRODUCTION PROFILE j-61- e)0,'j 09102/07 2T-TAB-01 11839656 INJECTION PROFILE 1:70- - 0,-; - 09103/07 2K-25 11846439 INJECTION PROFILE U = f -C) 1 09106/07 1 2K-18 11846440 INJEC PROFILE 09107107 1 1 113-18 11846441 PRODUCTION PROFILE afl-n(ol 09108107 1 2T-20 11846442 PRODUCTION PROFILE j 09109107 1 2N-310 11850433 SONIC SCANNER Qb4 -0 ej c)_ 09/16107 • 2N-310 11850433 SONIC SCANNER-FMI 09116107 1J-176 11846443 USIT Q n6 -p 09117107 1 E-29 NIA UCI / t a - 1.37q 09/19107 3F-21 11837503 RSTI WFL I)mc- a w 09120107 213-10 11839661 INJECTION PROFILE 0T(l 09122107 1G-05 11837506 INJECTION PROFILE O 09/23107 21-1-13 11839662 INJECTION PROFII- -()q 09/23/07 1 -05 11837508 INJECTION PROFILE j,) 71,0- 1 -� - � - j - a) 09124107 31-1-08 11839663 PRODUCTION PROFILE iAx - 0116 09124107 IY-31 11839664 PRODUCTION PROFILE 1 09/25107 IG-06 11839665 INJECTION PROFILE 09/26107 2Z-01A 11837512 USIT 00 II 1 09127107 12V-08A 11837511 ISOLATION SCANNER U /6Z/-091 09128107 IG-11 11837513 PRODUCTION PROFILE 1&3 -1:31 09/29107 11Y-22 11837515 PRODUCTION PROFILE r) 09130/07 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. WE D SARAH PAL1N, GOVERNOR ALASKA LISA 011L AND � 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM USSIOAT ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 -0360 Re: Kuparuk River Field, Tarn Oil Pool, 2N -310 ConocoPhillips Alaska, Inc. Permit No: 207 -090 Surface Location: 24' FNL, 602' FEL, SEC. 3, T9N, R7E, UM Bottomhole Location: 1342' FNL, 2858' FEL, SEC. 36, T10N, R7E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). 4 an DATED this l0 day of July, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Post Office Box 100360 ps Anchorage, Alaska 99510 -0360 Randy Thomas Phone (907) 265 -6830 Email: Randy .L.Thomas@conocophillips.com June 14, 2007 CF1F— Alaska Oil and Gas Conservation Commission Kr- 333 West 7`" Avenue, Suite 100 jUN 2 7 200 1 Anchorage, Alaska 99501 Alaska Oil & Gasr�ns.orrsmission RE: Application for Permit to Drill 2N -310 anct�ntat a Dear Commissioners, ConocoPhillips Alaska, Inc hereby applies for a Permit to Drill for the onshore infection well 2N -310. The well will be drilled and completed using Nordic Rig #3. The planned spud date for 2N -310 is August 17'`, 2007. Please find attached for the review of the Commission forms 10 -401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information, please contact Jason Brink at 907 - 265 -6419. Sincerely, Randy Thomas Ku aruk Drilling Team Leader p g i RECEIVED • STATE OF ALASKA � .JUN 7 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska 01! & Gas cons. Commission 20 AAC 25.005 Anchora 1a. Type of Work: 1b. Current Well Class: Exploratory ❑ Development Oil ❑ 1c. Specify if well is proposed for: Drill Q Re -drill ❑ Stratigraphic Test ❑ Service Q Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone El Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: ✓ Blanket Single Well 11. Well Name and Number. ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180 2N - 310 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 11840' TVD: 6058' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 24' FNL, 602' FEL, Sec. 3, T9N, R7E, UM ADL 380053 Tarn Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1488' FNL, 3191' FEL, Sec. 36, T10N, R7E, UM ALK 4601 8117/2007 Total Depth: 9. Acres in Property: 14. Distance to . 3700 A0 && , 0;? 1342' FNL, 2858' FEL, Sec. 36, TI ON, R7E, UM 2560 Nearest Property: < 1 mile 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest ... Surface: x - 460991 ` y - 5911983 Zone 4 (Height above GL) 148.6 AMSL feet Well within Pool: none, kK4 21f� 16. Deviated wells: Kickoff depth: 400 ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 70° deg Downhole: 3112 psig Surface: 2511 psig ! `'Z�• 7 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H -40 Welded 80' 30' 30' 120' 120' 122 sx AS 1 12.25" 9 -5/8" F 40# L -80 BTC 3520' 30' 30' 3520' . 2400' ' 570 sx AS Lite, 170 sx DeepCRETE 8.75" 7" 26# L -80 BTCM 10800' 30' 30' 10800' , 5137' 1210 sx GasBLOK w /Class G 6.125" 4.5" 12.6# L -80 IBTM 1240' 10600' 4989' 11840' 6058' 1170 sx GasBLOK w /Class G 19 PRESENT WELL CONDITION SUMMARY (To be completed fo Redrill a n d R - Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑✓ BOP Sketch Drilling Program ✓ Time v. Depth Plot Lj Shallow Hazard Analysis ❑✓ Property Plat ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements ❑✓ 21. Verbal Approval: Commission Representative: Date: 22. 1 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 2L , 6 S Date E / 2. E / a 7 ' S haron All Dra Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: �?"^ �O 50- l�3 " �S T I e W Date: • 07 for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrat gas contained in shales: El K,X* Ca,�.nk� a��*t�.�lc �� Samples req'd: Yes El No 9 ud to req'd: Yes ❑ No [r Other: . «� H2S Yes d No Wirn q'd: Yes ❑ No t3 w I VED BY THE COMMISSION DATE: in I k I A I COMMISSIONER Form 10-401 Revised 12/2005 b it i Duplicate i J G• 2- -7-197 . Ation for Permit to Drill, Well 2N -310 Saved: 21- Jun -07 Permit It — Well 2N -310 lcl"'J Application for Permit to Drill Document 1A0xT z Table of Contents 1. Well Name ................................................................................................... ..............................2 Requirements of 20 AAC 25. 005 ()9 ......................................................................................... ............................... 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 Requirements of 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)(5) ................................................................................... ............................... 3 6. Casing and Cementing Program .............................................................. ..............................4 Requirements of 20 AAC 25.005(c)(6) .................................................................................... ............................... 4 7. Diverter System Information .................................................................... ..............................4 Requirements of 20 AAC 25.005(c)(7) .................................................................................... ............................... 4 8. Drilling Fluid Program .............................................................................. ..............................4 Requirements of 20 AAC 25.005(c) (8) .................................................................................... ............................... 4 9. Abnormally Pressured Formation Information ...................................... ..............................5 Requirements of 20 AAC 25.005 (c)(9) ................................................................................... ............................... 5 10. Seismic Analysis ......................................................................................... ..............................5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................. ............................... 5 11. Seabed Condition Analysis ........................................................................ ..............................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................. ............................... 5 12. Evidence of Bonding .................................................................................. ..............................5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................. ............................... 5 13. Proposed Drilling Program ....................................................................... ..............................5 Requirements of 20 AAC 25.005 (c) (13) ................................................................................. ............................... 5 2N -310 APD Page 1 of 7 Printed: 21- Jun -07 ORIGINAL A�tion for Permit to Drill, Well 2N -310 Saved: 21- Jun -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 Directional Plan ............................................................................................... ............................... 7 Attachment 2 Drilling Hazards Summary .............................................................................. ............................... 7 Attachment Well Schematic ................................................................................................. ............................... 7 Attachment Cement Summary .............................................................................................. ............................... 7 1. Well Name Requirements of 20 AAC 25.005 69 Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple cell 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 2N -310. 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 folloring items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (4)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth. referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic aind Atmospheric Adnninistration: (C) the proposed depth of the well at the top of each objective formation and at total depth: Location at Surface 24' FNL, 602' FEL, Sec: 3, T9N, R7E, UM NGS Coordinates RKB Elevation 148.6' AMSL Northings: 5,911,983 Eastings: 460,991 Pad Elevation 118.6' AMSL Location at Top of Productive Interval 1488' FNL, 3191' FEL, Sec. 36, T10N, R7E, UM Cairn — Exploratory Test Interval NGS Coordinates Measured Depth, RKB: 10,986' Northings: 5,915,761 Eastings: 468,975 Total Vertical Depth, RKB: 5,300' Total Vertical Depth, SS: 5,150' Location at Top of Productive Interval 1454' FNL, 3114' FEL, Sec. 36, T10N, R7E, UM (Bermuda) NGS Coordinates Measured Depth, RKB: 11,179' Northings: 5,915,795 Eastings: 469,052 Total Vertical Depth, RKB: 5,459' Total Vertical Depth, SS: 5,310' Location at Total Depth 1342' FNL, 2858' FEL, Sec. 36, T10N, R7E, UM ' NGS Coordinates Measured Depth, RKB: 11,840' ° Northings: 5,915,906 Eastings: 469,309 Total Vertical Depth, RKB: 6,058' Total Vertical Depth, SS: 5,910' and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10 -401) must (1) include a plat, drawn to a suitable scale. showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 2N -310 APD Page 2 of 7 Printed: 21- Jun -07 ORIGINAL Antion for Permit to Drill, Well 2N -310 Saved: 21- Jun -07 and (2) for all wells within 200 feet of the proposed ivellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c) (3) An application for a Permit to 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: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Nordic 3. 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 identified in the application: (4) information on drilling ha_ards, including (A) the maxinunn downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the Bermuda sands in the 2N -310 area vary from 9.9 to 11.0 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from existing wells on the field together with reservoir model forecasts. The expected reservoir pressures in the Cairn sand in the 2N -310 area are expected to be normally pressured at .45 psi/ft or 8.6 ppg EMW. There is no offset injection or withdrawal from the Cairn interval. W "" Equivalent Mud Weight @TD = 3,123/(5,459 *.052) = 11.0 ppg The maximum potential surface pressure (MPSP) while drilling 2N -310 is calculated using the predicted 3,123 psi reservoir pressure, a 0.11 psi/ft gas gradient, and an Bermuda top TVD of 5,459'. MPSP = (5,459 ft TVD) *(0.57 - 0.11 psi/ft) = 2511 psi f (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo pressured strata. lost circulation =ones, and zones that have a propensity for differential sticking; Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill mist be accompanied by each of the following items, except for an item already on file with the conunission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(t); 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. 2N -310 APD Page 3 of 7 ORIGINAL Printed: 21- Jun -07 Aion for Permit to Drill, Well 2N -310 Saved: 21- Jun -07 6. 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 folloiring items, except for an item already on file kith the connnission 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: Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MDITVD MD ?VD OD (in) (in) (Ib/ft ) Grade Conn. (ft) (ft) (ft) Cement Program Cemented to surface with 16 24 62.5 H -40 Welded 80' Surf 120'/ 120' 122 sx ASl 15.7# Cemented to Surface with 9 -5/8 12 -1/4 40.0 L -80 BTC 3,520' Surf 3,520'/ 2,400' 570 sx ASLite Lead, 170 sx Dee CRETE Tail Cement Top planned @ 9,800' MD / 7 8 -3/4" 26.0 L -80 BTCM 10,800' Surf 10,800'/ 5,137' 4,580' TVD. Cemented w/ 210 sx GasBLOK wif Class "G" Cement Top planned @ 10,600' MD / 4 -1/2 6 -1/8 12.6 L -80 IBTM 1,240' 10,600'/ 4,989' 11,840'/ 6,058' 4,988' TVD. Cemented w/ 170 sx GasBLOK w/ Class "G" 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill iiurst be accompanied by each of the folloir ing items, except for an item alreadv on file with the connnission 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 haired by the commission under 20 AAC 25.035(h)(2): Please reference diverter schematic on file for Nordic 3. 8. 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 following items, except for an item already on file with the connnission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033: Drilling will be done using mud systems having the following properties: Surface Interval Production Interval Mud Type Spud Mud LSND Density (ppg) 8.5 -10.2 9.5 -11.0 i Funnel Viscosity(sec) 150 -250* 45 -55 Yield Point (cP) 30 -50 22 -28 Plastic Viscosity (lb /100 sji 20 -60 14 -25 10 sec. Gel (lb /100 sj) 10 -35 5 -9 API Filtrate (cc) NC -6 4 -6 pH 8.5 -9.5 9 -9.5 Solids ( %) +10 < 5% *Spud mud should be adjusted to a FV between 150 -250 sec /qt to drill gravel beds Diagram of Nordic 3 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 2N -310 APD Page 4 of 7 Printed: 21- Jun -07 � �. GI NAL 0 Vion for Permit to Drill, Well 2N -310 T Saved: 21- Jun -07 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c) (9) An application for a Permit to Drill must be accompanied by each of the following items, exceptfor an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25.03309: N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c) (10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a): N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) 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: .(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(b): N/A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bondingihave been met. Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be 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 program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Nordic 3 on 2N -310 Conductor. 2. NU and function test diverter system and prepare spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. 4. Spud and directionally drill 12 -1/4" hole to 9 -5/8" surface casing point (3,520' MD/ 2,400' TVD) according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. ' 5. Run and cement 9 -5/8" 40.0# L -80 BTCM casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Perform top job if required to bring cement to surface. 6. Nipple down diverter, remove warning signage, and install wellhead and test to 5000 psi.. Nipple up BOPE and test to a minimum of 3500 psi. Record results. 7. Shut in BOP'S and pressure test casing to 3000 psi per AOGCC regulations. Record results. 8. Drill out cement and 20' minimum to 50' maximum of new hole. Perform LOT.. 9. Directionally drill 8 -3/4" hole to 10,800 MD / 5,137' TVD. Run MWD /LWD logging tools in drill string as required for directional monitoring and formation data gathering. 10. Run 7" 26# L -80 BTCM casing to 10,800' MD / 5,137' TVD. Pump cement and displace with mud, land casing hanger and bump plug. 2N -310 APD Page 5 of 7 Printed: 21- Jun -07 ORIGINAL 0 Ap�tion for Permit to Drill, Well 2N -310 Saved: 21- Jun -07 11. PU 4 -3/4" drilling assembly and 6 -1/8" bit and clean out to shoe. Shut in BOP and test casing to 3,000 psi. Record results. Drill 20' minimum to 50' maximum of new hole. Perform LOT. 12. Drill Production hole to TD @ 11,840' MD / 6,058' TVD. 13. POOH and run open hole logs. ✓ 14. Lay down logs and run 4 -1/2" liner completion and cement same. 15. Run 4 -1/2" tubing with GLMs and SCSSSV with control line attached (for future lubrication of +/-100' patch across Cairn interval) to OD of tbg. Land 4 -1/2" completion tubing string in the seal bore in the 4 -1/2" liner top and pressure test to 2500 psi. Record results. 16. Pull landing joint. Install BPV. Nipple down BOP stack and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree to 5000 psi. Pull test plug. Secure well. 17. Pressure up to shear out valve in lowest GLM and freeze protect inner annulus with diesel to below the permafrost. Set BPV. Release rig. 18. Clean location and RDMO. 19. MIRU coiled tubing. Displace mud from well with brine. 20. RU E -Line, run CBL and perforate well. 21. Flow test Cairn interval. 22. RU Dowell, frac well if necessary. 23. Isolate Cairn with through tubing patch if necessary. 24. Secure well and handover to production. 2N -310 APD Page 6 of 7 GINAL Printed: 21- Jun -07 s A�tion for Permit to Drill, Well 2N -310 r Saved: 21- Jun -07 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AA 25.005 (c) (14) An application for a Permit to Drill mustc be accompanied by each of the following items, exceptfor 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 nerd and cuttings and a statement of whether the operator intends to request authori_ation under 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. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary 2N -310 APD Page 7 of 7 ORIG Printed: 21- Jun -07 f onocoftillips Alaska, In# CPAI Plan Report Company: ConocoPhillips Alaska Inc. Date: 6/7/2007 Time: 10:33:42 Page: 1 Field: Kuparuk River Unit Co- ordinate(NE) Reference: Well: Plan: 2N -310, True North Site: Kuparuk 2N Pad Vertical (TVD) Reference: 2N- 310wp06148.6 Well: Plan: 2N -310 Section (VS) Reference: Well (O.00N,O.00E,64.45Azi) Wellpath: Plan: 2N -310 Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 2N- 310wp06 Date Composed: 6/7/2007 Zebra Inboard Version: 9 Principal: Yes Tied -to: From Well Ref. Point Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Gen Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: Kuparuk 2N Pad Site Position: Northing: 5911970.20 ft Latitude: 70 10 13.596 N From: Map Easting: 460932.24 ft Longitude: 150 18 51.920 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.30 deg Well: Plan: 2N -310 Slot Name: Well Position: +N / - S 13.35 it Northing: 5911983.24 ft Latitude: 70 10 13.727 N +E / -W 59.01 It Easting : 460991.31 ft' Longitude: 150 18 50.211 W Position Uncertainty: 0.00 ft Wellpath: Plan: 2N -310 Drilled From: Well Ref. Point Zebra Inboard Tie -on Depth: 30.00 ft Current Datum: 2N- 310wp06 Height 148.60 ft Above System Datum: Mean Sea Level Magnetic Data: 8/1712006 Declination: 23.39 deg Field Strength: 57566 nT Mag Dip Angle: 80.65 deg Vertical Section: Depth From (TVD) +N / -S +E / -W Direction ft ft ft deg 30.00 0.00 0.00 64.45 Survey Program for Definitive Wellpath Date: 10/24/2006 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft Plan Section Information MD Incl Azim TVD +N / -S +E / -W DLS Build Turn TFO Target ft deg deg It ft ft deg /100ft deg /100ft deg /100ft deg 30.00 0.00 0.00 30.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 5.00 160.00 499.75 -8.20 2.98 2.50 2.50 0.00 160.00 2509.23 69.69 63.61 2048.80 378.02 1006.11 3.50 3.22 -4.80 -98.19 9900.21 69.69 63.61 4614.44 3458.76 7215.22 0.00 0.00 0.00 0.00 11178.05 25.00 66.34 5458.60 3853.70 8041.70 3.50 -3.50 0.21 178.36 2N- 310wp02 T -3 11840.08 25.00 66.34 6058.60 3965.98 8297.96 0.00 0.00 0.00 0.00 I G I N A L � s 3 ° o z w ° + F, V � M O O � N W �� C�0O0Q.0 CD O 3 U °� °_ Cl a {� a ai Fri C�i C�i o •m z Q d o c mia: vU o � o O J N M qqq v' CD Y�YIe V 100 o - o M .. z [n! /8000z1 ( +)yuoN/(- )yanoS X000 ° — o d � zM w�oNN y vi ai bq ,o , - - a U Fb N oz ��¢o- 4 � a 2.y ��Qo Cl ° r pr CL N �Q o Fy °oG o � o ti o � on 0 OS V] C M 7 CD W a >> Q O O , 7 y V7 W p N N N v V] T a�i a�i r� N O p W ° O V P. C?. °09 M O O o0 ma Cl Cl + 3 0+ w °o M Q v Q b z c O O� > [n!n;000z] yaaaQ WOMOn aniy Z a nDinihiAl O ponocoPhilli p s Alaska, Inc*. n CPAI Plan Report Company: ConocoPhillips Alaska Inc. Date: 6/7/2007 Time: 10:33:42 Page: 2 Field: Kuparuk River Unit Co- ordinate(NE) Reference: Well: Plan: 2N -310, True North Site: Kuparuk 2N Pad Vertical (TVD) Reference: 2N-31 OwpO6 148.6 Well: Plan: 2N -310 Section (VS) Reference: Well (O.00N,O.00E,64.45Azi) Wellpath: Plan: 2N -310 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Tncl Azim TVD Sys TVD N/S E/W MapN MapE DLS TFO Comment ft deg deg ft ft ft ft It ft deg /100ft deg 30.00 0.00 0.00 30.00 - 118.60 0.00 0.00 5911983.24 460991.31 0.00 0.00 100.00 0.00 0.00 100.00 -48.60 0.00 0.00 5911983.24 460991.31 0.00 0.00 200.00 0.00 0.00 200.00 51.40 0.00 0.00 5911983.24 460991.31 0.00 0.00 300.00 0.00 0.00 300.00 151.40 0.00 0.00 5911983.24 460991.31 0.00 0.00 400.00 / 2.50 160.00 399.97 251.37 -2.05 0.75 5911981.19 460992.05 2.50 0.00 500.00 5.00 160.00 499.75 351.15 -8.20 2.98 5911975.03 460994.25 2.50 0.00 600.00 5.68 122.35 599.34 450.74 -14.94 8.65 5911968.26 460999.89 3.50 261.81 700.00 7.99 99.84 698.64 550.04 -18.78 19.69 5911964.37 461010.90 3.50 299.30 800.00 10.95 88.35 797.28 648.68 -19.69 36.04 5911963.37 461027.24 3.50 321.66 900.00 14.16 81.84 894.87 746.27 -17.68 57.65 5911965.26 461048.87 3.50 333.00 1000.00 17.48 77.73 991.08 842.48 -12.75 84.45 5911970.05 461075.68 3.50 339.35 1100.00 20.86 74.91 1085.52 936.92 -4.93 116.32 5911977.72 461107.59 3.50 343.31 1200.00 24.27 72.85 1177.86 1029.26 5.77 153.15 5911988.22 461144.48 3.50 345.98 1300.00 27.70 71.27 1267.74 1119.14 19.30 194.81 5912001.53 461186.20 3.50 347.88 1400.00 31.14 70.01 1354.83 1206.23 35.60 241.13 5912017.60 461232.60 3.50 349.30 I 1500.00 34.60 68.99 1438.81 1290.21 54.63 291.95 5912036.36 461283.51 3.50 350.40 1600.00 38.06 68.12 1519.36 1370.76 76.30 347.08 5912057.75 461338.74 3.50 351.26 1700.00 41.53 67.39 1596.18 1447.58 100.54 406.30 5912081.68 461398.08 3.50 351.96 1800.00 45.00 66.74 1668.99 1520.39 127.26 469.40 5912108.07 461461.32 3.50 352.52 1900.00 48.48 66.17 1737.52 1588.92 156.35 536.15 5912136.81 461528.20 3.50 352.99 2000.00 51.95 65.66 1801.50 1652.90 187.71 606.29 5912167.81 461598.50 3.50 353.38 2100.00 55.43 65.19 1860.70 1712.10 221.23 679.56 5912200.94 461671.94 3.50 353.71 2200.00 58.91 64.77 1914.90 1766.30 256.77 755.69 5912236.08 461748.24 3.50 353.99 2300.00 62.40 64.37 1963.90 1815.30 294.20 834.40 5912273.11 461827.14 3.50 354.22 2400.00 65.88 64.00 2007.51 1858.91 333.39 915.39 5912311.87 461908.32 3.50 354.41 2500.00 69.37 63.64 2045.57 1896.97 374.18 998.36 5912352.23 461991.49 3.50 354.58 2509.23 69.69 63.61 2048.80 1900.20 378.02 1006.11 5912356.03 461999.26 3.50 354.71 2600.00 69.69 63.61 2080.31 1931.71 415.86 1082.36 5912393.47 462075.70 0.00 0.00 2700.00 69.69 63.61 2115.02 1966.42 457.54 1166.37 5912434.72 462159.91 0.00 0.00 2800.00 69.69 63.61 2149.74 2001.14 499.22 1250.38 5912475.96 462244.13 0.00 0.00 2900.00 69.69 63.61 2184.45 2035.85 540.90 1334.39 5912517.21 462328.34 0.00 0.00 3000.00 69.69 63.61 2219.16 2070.56 582.59 1418.40 5912558.45 462412.55 0.00 0.00 3100.00 69.69 63.61 2253.87 2105.27 624.27 1502.41 5912599.70 462496.77 0.00 0.00 3200.00 69.69 63.61 2288.59 2139.99 665.95 1586.42 5912640.94 462580.98 0.00 0.00 3300.00 69.69 63.61 2323.30 217470 707.63 1670.43 5912682.19 462665.20 0.00 0.00 3400.00 69.69 63.61 2358.01 2209.41 749.32 1754.44 5912723.43 462749.41 0.00 0.00 3500.00 69.69 63.61 2392.73 2244.13 791.00 1838.45 5912764.67 462833.63 0.00 0.00 3520.95 69.69 63.61 2400.00 2251.40 799.73 1856.05 5912773.32 462851.27 0.00 0.00 9 5/8" x 12 1/4" 3600.00 69.69 63.61 2427.44 2278.84 832.68 1922.46 5912805.92 462917.84 0.00 0.00 3700.00 69.69 63.61 2462.15 2313.55 874.36 2006.47 5912847.16 463002.06 0.00 0.00 3800.00 69.69 63.61 2496.87 2348.27 916.05 2090.48 5912888.41 463086.27 0.00 0.00 3900.00 69.69 63.61 2531.58 2382.98 957.73 2174.48 5912929.65 463170.49 0.00 0.00 4000.00 69.69 63.61 2566.29 2417.69 999.41 2258.49 5912970.90 463254.70 0.00 0.00 4100.00 69.69 63.61 2601.01 2452.41 1041.09 2342.50 5913012.14 463338.92 0.00 0.00 4200.00 69.69 63.61 2635.72 2487.12 1082.78 2426.51 5913053.39 463423.13 0.00 0.00 4300.00 69.69 63.61 2670.43 2521.83 1124.46 2510.52 5913094.63 463507.35 0.00 0.00 4400.00 69.69 63.61 2705.15 2556.55 1166.14 2594.53 5913135.88 463591.56 0.00 0.00 4500.00 69.69 63.61 2739.86 2591.26 1207.82 2678.54 5913177.12 463675.78 0.00 0.00 4600.00 69.69 63.61 2774.57 2625.97 1249.51 2762.55 5913218.37 463759.99 0.00 0.00 4700.00 69.69 63.61 2809.29 2660.69 1291.19 2846.56 5913259.61 463844.21 0.00 0.00 4800.00 69.69 63.61 2844.00 2695.40 1332.87 2930.57 5913300.86 463928.42 0.00 0.00 4900.00 69.69 63.61 2878.71 2730.11 1374.55 3014.58 5913342.10 464012.64 0.00 0.00 5000.00 69.69 63.61 2913.43 2764.83 1416.24 3098.59 5913383.35 464096.85 0.00 0.00 f onocoPhillips Alaska, Inco. CPAI Plan Report Company: ConocoPhillips Alaska Inc. Date: 6/7/2007 Time: 10:33:42 Page: 3 Field: Kuparuk River Unit Co- ordinate(NE) Reference: Well Plan: 2N -310, True North Site: Kuparuk 2N Pad Vertical (TVD) Reference: 2N- 310wp06148.6 Well: Plan: 2N -310 Section (VS) Reference: Well (O.00N,O.00E,64.45Azi) Wellpath: Plan: 2N -310 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DLS TFO Comment ft deg deg ft ft ft ft ft ft deg /100ft deg 5100.00 69.69 63.61 2948.14 2799.54 1457.92 3182.60 5913424.59 464181.07 0.00 0.00 5200.00 69.69 63.61 2982.85 2834.25 1499.60 3266.61 5913465.84 464265.28 0.00 0.00 5300.00 69.69 63.61 3017.57 2868.97 1541.28 3350.62 5913507.08 464349.50 0.00 0.00 5400.00 69.69 63.61 3052.28 2903.68 1582.96 3434.62 5913548.33 464433.71 0.00 0.00 5500.00 69.69 63.61 3086.99 2938.39 1624.65 3518.63 5913589.57 464517.93 0.00 0.00 5600.00 69.69 63.61 3121.70 2973.10 1666.33 3602.64 5913630.82 464602.14 0.00 0.00 5700.00 69.69 63.61 3156.42 3007.82 1708.01 3686.65 5913672.06 464686.35 0.00 0.00 5800.00 69.69 63.61 3191.13 3042.53 1749.69 3770.66 5913713.30 464770.57 0.00 0.00 5900.00 69.69 63.61 3225.84 3077.24 1791.38 3854.67 5913754.55 464854.78 0.00 0.00 6000.00 69.69 63.61 3260.56 3111.96 18.33.06 3938.68 5913795.79 464939.00 0.00 0.00 6100.00 69.69 63.61 3295.27 3146.67 1874.74 4022.69 5913837.04 465023.21 0.00 0.00 6200.00 69.69 63.61 3329.98 3181.38 1916.42 4106.70 5913878.28 465107.43 0.00 0.00 6300.00 69.69 63.61 3364.70 3216.10 1958.11 4190.71 5913919.53 465191.64 0.00 0.00 6400.00 69.69 63.61 3399.41 3250.81 1999.79 4274.72 5913960.77 465275.86 0.00 0.00 6500.00 69.69 63.61 3434.12 3285.52 2041.47 4358.73 5914002.02 465360.07 0.00 0.00 6600.00 69.69 63.61 3468.84 3320.24 2083.15 4442.74 5914043.26 465444.29 0.00 0.00 6700.00 69.69 63.61 3503.55 3354.95 2124.84 4526.75 5914084.51 465528.50 0.00 0.00 6800.00 69.69 63.61 3538.26 3389.66 2166.52 4610.76 5914125.75 465612.72 0.00 0.00 6900.00 69.69 63.61 3572.98 3424.38 2208.20 4694.76 5914167.00 465696.93 0.00 0.00 7000.00 69.69 63.61 3607.69 3459.09 2249.88 4778.77 5914208.24 465781.15 0.00 0.00 7100.00 69.69 63.61 3642.40 3493.80 2291.57 4862.78 5914249.49 465865.36 0.00 0.00 7200.00 69.69 63.61 3677.12 3528.52 2333.25 4946.79 5914290.73 465949.58 0.00 0.00 7300.00 69.69 63.61 3711.83 3563.23 2374.93 5030.80 5914331.98 466033.79 0.00 0.00 7400.00 69.69 63.61 3746.54 3597.94 2416.61 5114.81 5914373.22 466118.01 0.00 0.00 7500.00 69.69 63.61 3781.26 3632.66 2458.30 5198.82 5914414.47 466202.22 0.00 0.00 7600.00 69.69 63.61 3815.97 3667.37 2499.98 5282.83 5914455.71 466286.44 0.00 0.00 7700.00 69.69 63.61 3850.68 3702.08 2541.66 5366.84 5914496.96 466370.65 0.00 0.00 7800.00 69.69 63.61 3885.39 3736.79 2583.34 5450.85 5914538.20 466454.87 0.00 0.00 7900.00 69.69 63.61 3920.11 3771.51 2625.03 5534.86 5914579.45 466539.08 0.00 0.00 8000.00 69.69 63.61 3954.82 3806.22 2666.71 5618.87 5914620.69 466623.30 0.00 0.00 8100.00 69.69 63.61 3989.53 3840.93 2708.39 5702.88 5914661.93 466707.51 0.00 0.00 8200.00 69.69 63.61 4024.25 3875.65 2750.07 5786.89 5914703.18 466791.72 0.00 0.00 8300.00 69.69 63.61 4058.96 3910.36 2791.76 5870.90 5914744.42 466875.94 0.00 0.00 8400.00 69.69 63.61 4093.67 3945.07 2833.44 5954.90 5914785.67 466960.15 0.00 0.00 8500.00 69.69 63.61 4128.39 3979.79 2875.12 6038.91 5914826.91 467044.37 0.00 0.00 8600.00 69.69 63.61 4163.10 4014.50 2916.80 6122.92 5914868.16 467128.58 0.00 0.00 8700.00 69.69 63.61 4197.81 4049.21 2958.48 6206.93 5914909.40 467212.80 0.00 0.00 8800.00 69.69 63.61 4232.53 4083.93 3000.17 6290.94 5914950.65 467297.01 0.00 0.00 8900.00 69.69 63.61 4267.24 4118.64 3041.85 6374.95 5914991.89 467381.23 0.00 0.00 9000.00 69.69 63.61 4301.95 4153.35 3083.53 6458.96 5915033.14 467465.44 0.00 0.00 9100.00 69.69 63.61 4336.67 4188.07 3125.21 6542.97 5915074.38 467549.66 0.00 0.00 9200.00 69.69 63.61 4371.38 4222.78 3166.90 6626.98 5915115.63 467633.87 0.00 0.00 9300.00 69.69 63.61 4406.09 4257.49 3208.58 6710.99 5915156.87 467718.09 0.00 0.00 9400.00 69.69 63.61 4440.81 4292.21 3250.26 6795.00 5915198.12 467802.30 0.00 0.00 9500.00 69.69 63.61 4475.52 4326.92 3291.94 6879.01 5915239.36 467886.52 0.00 0.00 9600.00 69.69 63.61 4510.23 4361.63 3333.63 6963.02 5915280.61 467970.73 0.00 0.00 9700.00 69.69 63.61 4544.95 4396.35 3375.31 7047.03 5915321.85 468054.95 0.00 0.00 9800.00 69.69 63.61 4579.66 4431.06 3416.99 7131.04 5915363.10 468139.16 0.00 0.00 9900.00 69.69 63.61 4614.37 4465.77 3458.67 7215.05 5915404.34 468223.38 0.00 0.00 10000.00 66.20 63.72 4651.91 4503.31 3499.78 7298.10 5915445.02 468306.63 3.49 178.36 10100.00 62.70 63.84 4695.04 4546.44 3539.64 7379.02 5915484.46 468387.75 3.50 178.32 10200.00 59.20 63.96 4743.59 4594.99 3578.10 7457.51 5915522.50 468466.43 3.50 178.27 ORIGINAL r t o onocoPhillips Alaska, In. CPAI Plan Report Company: ConocoPhillips Alaska Inc. Date: 6/7/2007 Time: 10:33:42 Page: 4 Field: Kuparuk River Unit Co- ordinate(NE) Reference: Well: Plan: 2N -310, True North Site: Kuparuk 2N Pad Vertical (TVD) Reference: 2N- 310wp06 148.6 Well: Plan: 2N -310 Section (VS) Reference: Well (O.00N,O.00E,64.45Azi) Wellpath: Plan: 2N -310 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DLS TFO Comment ft deg deg ft ft It ft ft It deg /100ft deg 10300.00 55.70 64.09 4797.39 4648.79 3615.02 7533.27 5915559.03 468542.37 3.50 178.21 10400.00 52.20 64.23 4856.22 4707.62 3650.25 7606.03 5915593.88 468615.31 3.50 178.14 10500.00 48.71 64.39 4919.88 4771.28 3683.67 7675.51 5915626.94 468684.95 3.50 178.06 10600.00 45.21 64.57 4988.13 4839.53 3715.16 7741.45 5915658.08 468751.05 3.50 177.95 10700.00 41.71 64.77 5060.70 4912.10 3744.59 7803.61 5915687.19 468813.35 3.50 177.83 10800.00 38.21 64.99 5137.34 4988.74 3771.85 7861.75 5915714.15 468871.63 3.50 177.69 10900.00 34.72 65.26 5217.74 5069.14 3796.85 7915.66 5915738.87 468925.66 3.50 177.52 11000.00 31.22 65.58 5301.63 5153.03 3819.49 7965.14 5915761.25 468975.25 3.50 177.30 11065.84 28.92 65.83 5358.60 5210.00 3833.06 7995.20 5915774.67 469005.38 3.50 177.03 7 "x 8 3/4" 11100.00 27.73 65.97 5388.67 5240.07 3839.68 8010.00 5915781.21 469020.21 3.50 176.82 11178.05 25.00 66.34 5458.60 5310.00 3853.70 8041.70 5915795.06 469051.97 3.50 176.70 2N- 310wp02 T -3 11200.00 25.00 66.34 5478.49 5329.89 3857.42 8050.19 5915798.74 469060.48 0.00 180.00 11300.00 25.00 66.34 5569.12 5420.52 3874.38 8088.90 5915815.50 469099.28 0.00 180.00 11400.00 25.00 66.34 5659.75 5511.15 3891.34 8127.61 5915832.26 469138.07 0.00 180.00 11500.00 25.00 66.34 5750.38 5601.78 3908.30 8166.32 5915849.02 469176.86 0.00 180.00 11600.00 25.00 66.34 5841.01 5692.41 3925.26 8205.03 5915865.78 469215.65 0.00 180.00 11700.00 25.00 66.34 5931.65 5783.05 3942.22 8243.74 5915882.53 469254.45 0.00 180.00 11800.00 25.00 66.34 6022.28 5873.68 3959.18 8282.45 5915899.29 469293.24 0.00 180.00 11840.08 25.00 66.34 6058.60 5910.00 3965.98 8297.96 5915906.01 469308.79 0.00 180.00 4 1/2" x 6 1/8" Targets Map Map < - - -- Latitude - - - -> < --- Longitude - - -> Name Description TVD +N / -S +E / -W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 2N- 310wp02 T -3 5458.60 3853.70 8041.70 5915795.06 469051.97 70 10 51.587 N 150 14 57.122 W -Plan hit target Annotation MD TVD Casing Points MD TVD Diameter Hole Size Name ft ft in in 3520.95 2400.00 9.625 12.250 9 5/8" x 12 1/4" 11065.84 5358.60 7.000 8.750 7 "x 8 3/4" 11840.08 6058.60 4.500 6.125 4 1/2" x 6 1/8" Formations MD TVD Formations Lithology Dip Angle Dip Direction PI INAL Alaska, In OonocoPhilfips a , Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 6/7/2007 Time: 10:30:11 Page: 1 Field: Kuparuk River Unit Reference Site: Kuparuk 2N Pad Co- ordinate(NE) Reference: Well: Plan: 2N -310, True North Reference Well: Plan: 2N -310 Vertical (TVD) Reference: 2N- 310wp06 148.6 Reference Wellpath: Plan: 2N -310 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100 /1000 of reference Reference: Plan: 2N- 310wp06 & NOT PLANNED PR RAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 30.00 to 11840.08 ft Scan Method: Trav Cylinder North Maximum Radius: 1381.01 ft Error Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name It ft in in 3520.95 2400.00 9.625 12.250 9 5/8" x 12 1/4" 11065.84 5358.60 7.000 8.750 7 "x 8 3/4" 11840.08 6058.60 4.500 6.125 4 1/2" x 6 1/8" Plan: 2N- 310wp06 Date Composed: 6/7/2007 Zebra Inboard Version: 9 Principal: Yes Tied -to: From Well Ref. Point Summary <---------------- - - - - -- Offset Wellpath ----------------- - - - - -> Reference Offset Ctr -Ctr No -Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft It ft Kuparuk 2N Pad 2N -302 2N -302 V11 345.14 350.00 115.50 6.31 109.20 Pass: Major Risk Kuparuk 2N Pad 2N -303 2N -303 V4 342.67 350.00 105.06 5.50 99.57 Pass: Major Risk Kuparuk 2N Pad 2N -304 2N -304 PB1 V12 1375.85 1350.00 57.16 21.19 35.97 Pass: Major Risk Kuparuk 2N Pad 2N -304 2N -304 V32 1375.85 1350.00 57.16 21.19 35.97 Pass: Major Risk Kuparuk 2N Pad 2N -305 2N -305 V6 293.86 300.00 75.82 5.14 70.69 Pass: Major Risk Kuparuk 2N Pad 2N -306 2N -306 V1 298.99 300.00 61.30 5.40 55.90 Pass: Major Risk Kuparuk 2N Pad 2N -307 2N -307 V7 797.94 800.00 33.94 11.21 22.74 Pass: Major Risk Kuparuk 2N Pad 2N -308 2N -308 V2 291.80 300.00 30.75 5.20 25.55 Pass: Major Risk Kuparuk 2N Pad 2N -309 2N -309 V2 444.06 450.00 13.96 6.57 7.40 Pass: Major Risk Kuparuk 2N Pad 2N -311 2N -311 V1 373.43 375.00 14.84 6.45 8.40 Pass: Major Risk Kuparuk 2N Pad 2N -311 2N -311A V6 374.03 375.00 14.85 6.45 8.39 Pass: Major Risk Kuparuk 2N Pad 2N -313 2N -313 V2 299.79 300.00 46.19 5.18 41.01 Pass: Major Risk Kuparuk 2N Pad 2N -314 2N -314 V3 172.38 175.00 60.78 3.02 57.77 Pass: Major Risk Kuparuk 2N Pad 2N -315 2N -315 V2 299.79 300.00 76.35 5.37 70.98 Pass: Major Risk Kuparuk 2N Pad 2N -316 2N -316 V9 345.04 350.00 90.54 5.75 84.79 Pass: Major Risk Kuparuk 2N Pad 2N -317 2N -317 V2 448.94 450.00 106.41 6.80 99.61 Pass: Major Risk Kuparuk 2N Pad 2N -318 2N -318 V4 270.50 275.00 120.29 4.60 115.69 Pass: Major Risk Kuparuk 2N Pad 2N -319 2N -319 V2 399.08 400.00 136.63 6.37 130.26 Pass: Major Risk Kuparuk 2N Pad 2N -320 2N -320 V2 415.67 425.00 148.30 6.33 141.97 Pass: Major Risk Kuparuk 2N Pad 2N -321 2N -321 V2 299.77 300.00 167.13 5.34 161.80 Pass: Major Risk Kuparuk 2N Pad 2N -321 2N -321A V4 299.77 300.00 167.13 5.34 161.80 Pass: Major Risk Kuparuk 2N Pad 2N -323 2N -323 V2 274.57 275.00 196.74 4.92 191.83 Pass: Major Risk Kuparuk 2N Pad 2N -325 2N -325 V2 299.78 300.00 227.39 5.07 222.32 Pass: Major Risk Kuparuk 2N Pad 2N -326 2N -326 V3 243.56 250.00 241.33 4.16 237.17 Pass: Major Risk Kuparuk 2N Pad 2N -326 Plan 2N -326A V1 Plan: 239.29 250.00 241.25 4.05 237.21 Pass: Major Risk Kuparuk 2N Pad Plan: 2N -301 Plan: 2N -301 (Zebra Al 324.46 325.00 134.95 6.83 128.12 Pass: Major Risk Kuparuk 2N Pad Plan: 2N -322 Plan: 2N -322 VO Plan: 633.15 650.00 175.40 10.46 164.94 Pass: Major Risk Kuparuk 2N Pad Plan: 2N -322 Prelim: 2N -322ST VO PI 633.15 650.00 175.40 10.46 164.94 Pass: Major Risk I G"' N A L 0000000000000000000000 0000non0000000000000OOOOo kf) N V 1 1- O O H O m1kc, O O 0 0 N 'Zr "O 00 0 W) HNvi too MM l-00 O - — — — NN O M kn o �00C O -O 0000 O z 0 �q v ssx�m�o - - -- F 0 a a a as i z > C oo v i C C rve� Y v W W R L XA 888e E o �os i i F y z g o O N M R z o A a 00000 a o000000000000000000o N 3 0000knokn 0000000c00000000 o rn O Dr4Ot--- -- N Oe4O1AOSA0�OOOO - --- tQ� O ..� F•' N � l� � ..r �-. � N M M R 7 V'• [— 00 � .-•i ,-•i � •••i .w kV f'1 _ N 00 Z L VI � 00 R U I V I I I I I I I I I b 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O p O y M O t -00000 90'00 F V NsA ICON V)l�OMOtn ® "0000 d 9 ` 0 W V O 00 Z v M \ E s bfi N f U u` R Vi \ l G L O s M e z N v d � u M � U z M N N c l ei •' Aa ' 0 8 M �, iN 3ry r , (Z kf) LL S i M M O =en e -wa M OM �y Nip N o ° o . "s ¢ o HUH .. W o !a! ;I N � �ZZ Mt'rl tm M eS „` 3 gflo i ` : ! s ss sss •3 ""�b0 E>"A a:gSAa. §` m aba2a�gaet33F N i M OM iT a s. ;F$i's - " q3 --Iffiffl NN GCS N c� � €,' saszs?a!t�dG:23!!!'! M 'N z z i M M -M M • 1 • 1 ' G .............. - - -- - - -- .......... ..... ...... - -. - -- i i C> 1 I M ! N ...... . ...... . ....,.... .... ,......_ ... _ - ...... -._ - a' r 0 M i : N O ! M O N M N ! III 1 ;o z i .__ M N j } i I I I j I . ! 4 I ' ! j > O O O O O C [Ui /13000I] � +)uljoN/� _ URIGINAL 2N -310 Drilling Hazards Summary Surface Hole Risks Event Risk Level Mitigation Strategy / Contingenc Broach of conductor Low Monitor cellar & pad continuously during interval Gas Hydrates Moderate Minimum mud weight of 10.0 ppg. If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, addition of Lecithin Running sands & gravel Moderate Maintain planned mud parameters, Increase mud weight/viscosity, Use weighted sweeps, monitor fill on connections Hole swabbing/Tight hole on Moderate Circulate hole clean prior to trip, proper hole filling trips (use of trip sheets), pumping out of hole as needed Production Hole Risks Event Risk Level Mitigation Strategy / Contingenc Insufficient or undetermined Low Importance of LOT communicated to all parties, all LOT parties familiar with LOT procedure. Test will be carried out until leak off is observed or to an FIT of 16 ppg MW equivalent Swabbing Campaignian sands Moderate Minimum mud weight of 9.6 ppg, mandatory flow (50 ft TVD below C -80) check above sands on all trips High reservoir pressure Moderate T' top set above the Bermuda High ECD / Tight hole on trips/ Moderate Condition mud & clean hole prior to trips., Monitor Swabbing ECDs with PWD tool while drilling across reservoir interval. Hole cleaning best practices. Backream out on trips as a last resort, proper hole filling (use of trip sheets) Lost circulation Moderate Keep hole clean — use PWD to monitor hole cleaning. If losses occur — reduce pump rates and mud rheolo y, use LCM ORIGINAL ' TARN 2N -310 wp(06) 1✓ ConocoPhillips Proposed Completion Schematic 4 -1/2" Completion String 4 -1/2" FMC Gen 5 Tubing Hanger, 4 -1/2" L -80 IBTMod pin down 4 -1/2" 12.6# L -80 IBTMod Spaceout Pups as Required w/ spec. clear. cplgs 4 -' /z° 12.6# IBTM L -80 w/ special clearance couplings, 4.920" OD cplg 4 -1/2" Cameo TRM- 4PE -CF SCSSV (6.0" OD) wl 3.812" DB Profile 4 -1/2" x 6'L-80 X -over ( NEW VAM x IBTM) handling pups installed above and 16" 62.6# below Conductor Set at +/- 2000' TVD +/- 80' MD/TVD TAM 9 -518" Port Collar Use of port collar at the discretion of the drilling team. Grade BTC Threads 4 -' /2" 12.6# IBTM L -80 w/ special clearance couplings, 4.920" OD cplg 1000' MD/TVD) 4 -1/2" x 1" Camco'KBG -2' Mandrels w/ DV's (Max. OD 5.985 ", ID 3.833 "), IBTMod pin x pin, 4 -1/2" x 6'L-80 IBTMod box x box handling pup w/ spec. clear. Cplgs installed above, 4 -1/2" x 6' L -80 IBTMod box x pin handling pup w/ spec. clear. Cplgs installed below. Spaced out w/ 4 -1/2" 12.6# L -80 IBTMod tubing w/ spec. clear. Cplgs as follows: GLM # TVD -RKB MD -RKB GLM Numbers and Spacing To Be Determined Surface csg. 9 -5/8" 40# L -80 BTC +/- 3520' MD/ 2400' TVD 4 -1/2" x 1" Camco'KBG -2' mandrel w/ DCK -2 shear valve (Max. OD 5.985 ", ID 3.833 "), IBTMod pin x pin, Pinned for 2000 psi shear (casing to tubing differential), 4 -1/2" x 6' L -80 IBTMod box x box handling pup w/ spec. clear. cplgs installed above, 4 -1/2" x 6'L-80 IBTMod box x pin handling pup w/ spec. clear. Cplgs installed below 1 jt 4-%" 12.6# IBTM L -80 w/ special clearance couplings, 4.920" OD cplg 4 -1/2" Baker'CMD' sliding sleeve w/ 3.813" X- profile, IBTMod box x pin. 4 -1/2" X 6'L-80 IBTMod handling pup w/ spec. clear. Cplgs installed above 4 -1/2" x 6' L -80 IBTMod handling pup w/ spec. clear. Cplgs installed below 1 jt 4 -' /2" 12.6# IBTM L -80 w/ special clearance couplings, 4.920" OD cplg X-OVER PUP, 6'. 4-%" 12.6# L -80 IBTM boxxTCll pin Intermediate csg Bullet seal assembly for 5" ID PBR tie back extension, 15', 4 -%" TCII box 7" 26.0# L -80 BTCM +/- 10,800' MD / 5137' TVD (200' above Top Cairn) 4 '/2" x 7" HRD ZXP w/ 15' PBR extension, 4 -'/2" Hydri1521 box down 4 -'/2" x 7" Flex Lock Hanger, 4 -' /2" Hydril 521 pin x pin (re -cut pin to IBT) Future Perforations: Set at +/- 200' MD above 7" casing shoe Cairn top @ 10997 MD/ 5300 TVD Cairn bottom @ 11089 MD/ 5380 TVD PUP jt 10', 4 '' /_" 12.6# IBTM L -80 w/ special clearance couplings, 4.920" OD cplg (10' pup so that Baker can space liner cement wiper dart below nipple profile) Bermuda top @ 11178 MD/ 5460 TVD 4 -1/2" Camco 3.75"'1313' nipple profile 4 -' /i' 12.6# IBTM L -80 w/ special clearance couplings, 4.920" OD cplg BOT Landing Collar type I w/ ceramic insert 4 -' /2' IBT box x pin 4 -' /=" 12.6# IBTM L -80 w/ special clearance couplings, 4.920" OD cplg 4 -1/2" 12.6# L -80 4 -' /z" IBT Float Collar IBTModMOD 4.92" Spec. 4 -' /z" 12.6# IBTM L -80 w/ special clearance couplings, 4.920" OD cplg Clearance 4 - %" IBT Float Shoe +/- 11,840' MD / 6058' TVD ' 5/6/2007 *I N A L CemCADE Preliminary Job Design Schlumherger 9 5/8" Surface Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Nordic 3 Volume Calculations and Cement Systems Location: Tarn Volumes are based on 300% excess in the permafrost and 50% excess below the Client: ConocoPhillips Alaska, Inc. Revision Date: 6/19/2007 permafrost. The top of the tail slurry is designed to be at 2,720' MD. Prepared by: Maureen Torrie Location: Anchorage, AK Lead Slurry Minimum pump time: 250 min. (pump time plus 120 min.) Phone: (907) 265 -6336 ARCTICSET Lite @ 10.7 ppg - 4.45 ft3 /sk Mobile: (907) 952 -0445 email: mtorrie @slb.com 1.4895 ft /ft x (80') x 1.00 (no excess) = 119.2 ft 0.3132 ft /ft x (1560'- 80') x 4.00 (300% excess) = 1854.1 ft < ToC at Surface 0.3132 ft /ft x (2720'- 1560' x 1.50 (50% excess) = 545 ft 119.2 ft + 1854.1 ft 545 ft = 2518.3 ft 2518.3 ft / 4.45 ft /sk = 565.9 sks Round up to 570 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Previous Csg. < 20", sous casing Tail Slurry Minimum pump time: 190 min. (pump time plus 120 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3 /sk at 80' MD 0.3132 ft /ft x (3520'- 2720') x 1.50 (50% excess) = 375.8 ft 0.4257 ft /ft x 0' (Shoe Joint) = 34.1 ft 375.8 ft +34 . 1 ft = 409.9 ft 409.9 ft 2.47 ft /sk = 166 sks Round up to 170 sks BHST = 50F, Estimated BHCT = 65F. < Base of Permafrost at (BHST calculated using a gradient of 2.2F/100 ft. below the permafrost) 1,560' MD (1,500' TVD) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) ( bbl) (min) (min < Top of Tail at CW 100 5 50 10.0 10.0 2,720' MD Drop Bottom Plug 15.0 25.0 MudPUSH II 6 50 8.3 33.3 Lead Slurry 7 452 64.6 97.9 Tail Slurry 7 75 10.7 108.6 Drop Top Plug 5.0 113.6 Water 5 20 4.0 117.6 Switch to Rig 5.0 122.6 Pumps < 9 5/8 ", 40.0# casing Displacement 6 221 36.8 1 159.4 in 12 1/4" off Slow Rate 3 20 6.7 166.1 TD at 3,520' MD MUD REMOVAL (2,400' TVD) Recommended Mud Properties: 9.5 ppg, P < 15, T < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, P = 17 -21, T = 20 -25 Centralizers: Recommend 1 per joint across zones of interest, and 2 per joint for bottom 8 joints for proper cement placement. Mark of Schlumberger ORIGINAL ' SchluinhopUep 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. Volume Calculations and Cement Systems Revision Date: 6/20/2007 Volumes are based on 50% excess. Tail slurry is designed for 1000' MD above the Prepared by: Maureen Torrie intermediate casing shoe (cement type as per client's request). Maximum dynamic Location: Anchorage, AK pressure experienced during cement job is expected to be 14.7 ppg. Phone: (907) 265 -6336 Mobile: (907) 952 -0445 email: mtorrie @slb.com Tail Slurry Minimum thickening time: 230 min. (Pump time plus 120 min.) GasBLOK w/ Class G + 2 gps D60OG + 0.1% B155 + 0.2 gps D047 + 0.35% D065 @ 15.8 ppg - 1.17 ft3 /sk 0.1503 ft /ft x 1000'x 1.50 (50% excess) = 225.5 ft 0.2148 ft /ft x 80' (Shoe Joint) = 17.2 ft 225.5 ft + 17.2 ft = 242.7 ft 242.7 ft 3 / 1.17 ft /sk = 207.4 sks Previous Csg. Round up to 210 sks < 9 5/8 ", 40.0# casing BHST = 110, Estimated BHCT = 75F. at 3,520' MD (BHST calculated using a gradient of 2.2F/1 00 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) min Drop Bottom Plug 10.0 10.0 MudPUSH II 5 25 5.0 15.0 Tail Slurry 6 44 7.3 22.3 Drop Top Plug 5.0 27.3 < Top of Tail at Pump Water 4 20 5.0 32.3 9,800 MD Switch to Rig 5.0 37.3 P u m p Displacement 5 350 70.0 107.3 Slow Rate 3 40 1 13.3 120.6 < 7 ", 26.0# casing in 8 3/4" off MUD REMOVAL Recommended Mud Properties: 10 ppg, P < 15, T < 22. As thin and light as possible to aid in mud removal during cementing. TD at 10,800' MD Spacer Properties: 13.0 ppg MudPUSH" ll, P = 19 -22, T = 22 -29 (5,137 TVD) Centralizers: Recommend 2 per joint across zones of interest for proper cement placement. Cerra ADE Preliminary Job Design NE& Schlumber er 4 1/2" Liner Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Nordic 3 Location: Tarn Client: ConocoPhillips Alaska Volume Calculations and Cement Systems Revision Date: 6/19/2007 Volumes are based on 50% excess. Displacement is calculated with a 4.5 "- 16.6# drill Prepared by: Maureen Torrie string. Cement job is designed to seal off liner top by bringing cement 200' above liner Location: Anchorage, AK top, with 15.8 ppg G cement (cement type as per client's request). Maximum dynamic Phone: (907) 265 -6336 pressure experienced during cement job is expected to be 15.0 ppg. Mobile: (907) 952 -0445 email: mtorrie @slb.com Tail Slurry Minimum thickening time: 190 min. (pump time plus 120 min.) GasBLOK w/ Class G + 2 gps D60OG + 0.1 % B155 + 0.2 gps D047 + 0.35% D065 @ 15.8 ppg - 1.17 ft3 /sk Liner Cap: 0.1044 ft /ft x 200'x 1.00 (no excess) = 20.9 ft Liner Lap: Top of Tail at 0.1044 ft /ft x (10800'- 10600') x 1.00 (no excess) = 20.9 ft < 10,400' MD Annular Volume: 0.0942 ft /ft x (11840'- 10800') x 1.50 (50% excess) = 147 ft Shoe Volume: < Liner Top at 0.0854 ft /ft x 80'x 1.00 (no excess) = 7.7 ft 10,600' MD Totals: 20.9 ft3 +20.9 ft3 +147 ft3 +7.7 ft' = 196.5 ft 196.5 ft 1.17 ft /sk = 167.9 sks Previous Csg. Round up to 170 sks 7", 26.0# casing BHST = 130F, Estimated BHCT = 104F. at 10,800' MD (BHST calculated using a gradient of 2.2F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) bbl (min) min < 41/2", 12.6# casing Pressure Test 10.0 - in 61/8" off Mud PUSH II 5 15 3.0 3.0 Tail Slurry 5 35 7.0 10.0 Drop Top Plug 3.0 13.0 Displacementl 3 1 168 1 56.0 1 69.0 MUD REMOVAL Recommended Mud Properties: 11.4 ppg, P < 15, T < 22. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.0 ppg MudPUSH" II, P = 19 -22, T = 22 -29 TD at 11,840' MD Centralizers: Recommend 1 per joint from 5950' MD to TD, and 2 per joint from 5870' (6,058' TVD) MD to 5940' MD for proper cement placement. Mark of Schlumberger ORIGINAL EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 6000000 - • AEO 1 s 5950000 2N -310 (surface) yr, i 5900000 - -- __ 40 CFR 14 7.71:0T =b3 • • 5850000 - ---- 400000 500000 600000 700000 800000 SHARON K. ALLSUP -DRAKE 1187 CONOCOPHILUPS A OO G 630 DATE 561551/441 ANCHORAGE AK 99501 PA TO THE $ (!)O, O tt � ORDER OF p�CARS LJ 3 J PMorganChase Valid Up TO 5000 Dollars JPMorgan Chase Bank, N.A. Columbus, OH MEMO i:044 L 15 5 10: S 28 ?47 190 79 2 ?►l' L 18 ? 0 TRANSMITTAL LETTER CHECKLIST WELL NAydE /<'.,t?a Z/ ' - 3/6 PTD# Zd 7 '`r Development / Service Exploratory Stratigraphic Test Non - Conventional Well Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK i ADD -ONS ' TEXT FOR APPROVAL LETTER WHAT j (OPTIONS) APPLIES i MTILTI LATERAL The permit is for a new wellbore segment of existing i well (If last two digits in Permit No. ,API No. 50- - API number are between 60 -69) Production should continue to be reported as a function of the i original API number stated above. PLOT 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 4 acquired for well 1 SPACING The permit is approved subject to full compliance with 20 AAC ` EXCEPTION 25.055. Approval to perforate and produce / inject is contingent I upon issuance of a conservation order approving a spacing j i exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH j All dry ditch sample sets submitted to the - Commission must be in i SA!VtPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target Zones. i Please note the following . special condition of this permit: j Non - Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and ! i implemented a water well testing program to provide baseline data j on water quality and quantity. (Company Name) must contact the i Commission to obtain advance approval of such water well testing program. i Rev: 1125i06 C:' jody \transmittal_checklist Field & Pool KUP RIVER, TARN O IL - 49 0165 Well Name: KUPARUK RIV U TARN 2 N_310 Program SER Well bore seg ❑ PTD #:2070900 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type SER / PEND GeoArea 890 Unit 1116 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes -- ----------------------------------- 2 Lease number appropriate- - - - - - - - - - - - - - - - - - - -------------- - _ _ Yes _ - _ _ - _ - Surface in ALD0375074; well-passes through unleased acreage of Section 2, T9N, R7E,_UM; top-prod _int &_TD in - 3 Unique welln_amea--- -- - - -- --- ----------------------- -- - -- - -- Yes ------- ADL0380053.___________ _______________________________ ------------------ 4 Well located i_n_a_ defined pool --------------------------------------- Yes _ _ _ _ _ _ _ KUPARUK RIVER, TARN 490165, governed by C0- - - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 Well located proper distance from drilling unit.boundary ---- - - - _ - _ _ . _ Yes _ - _ _ - _ - Well lies about 3938'_from_ boundary-with unleased acreage._ CO 430A requires 300'_set back from property lines, - 6 Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Conforms to Conservation Order_No. 430A_ Rule 3, which specifies 10 -acre spacing. ---- - - - - -- 7 Sufficient acreage available in_drilling unit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - _ _ - - - - _ - - - - - - ------------------- --- ------------ ------------------ 8 If deviated, is_we_llbore plat-included - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - ----------------------------------------------- 9 Operator only affected art p y - -- Yes---- - ------------------------------------------------------------------- 10 Operator has_appropriate_bond in force - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ Yes _ - - - - - _ - - 11 Permit-can be issued without conservation order- - - - - - - - - - - - - - - - - - - - - - - - - - - Yes --------------------------------------------- ------------------ Appr Date 12 Permit can be issued without administrative-approval - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ - - - - _ _ - - - - - - - - - - - - - - - - -- - - - - - SFD 719/2007 13 Canpermitbeapprovedbefore15- daywait- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes- - - - - - 14 Well located within area and - strata authorized by_Injection Order# (put 10# in-comments)_(For_ Yes - - - - - - - AIO.16_ - - - - - - - 15 All wells-within 1 /4_mil_e area_of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - _ _ _ _ None_ -- ----- - - - - - -- - - - - -- ------------------------ 16 Pre - produced injector: duration of pre - production Less than 3 months_(For_service well only) _ _ No_ _ _ _ _ _ _ _ Will_bepreproduced from the_Cairn interval for up-to 6 months to test its production capability. then_ - - - - - - _ _ - 17 Nonconven. gas conforms to AS31,05 ._030(j.1_.A),(j.2.A -D) - - - - - - - - - - - - - - - - - - - - - NA_ _ _ _ - - _ - converted to injection in the Bermuda interval. -(Jason Brink,_CPAI,_7 /6/20.07). - - - - - ---------------- 18 Conductor string - provided - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ _ _ - _ - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - Engineering 119 Surface casing_ protects all-known_ USDWs - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ - _ _ _ _ _ AII_ aquifers exempted, 40 CFR- 147.102 (b)I3). _ _ - - - - - - - -- - - - - - - - - - - - - - - - - - - - -- -- 20 GMT_vol_ adequate_ to circulate-on conductor & surf _csg___________________ Yes- -_ - ________________ -_ - - - --- __- ___ - -_ -_ _ _ 21 C_MT_vol_ adequate_ totie- inlong string to surf csg --- ---- --- ----------- - - - - -- N_o_ - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - 22 _ C_ MT_ will cover all known -productive horizon _ s_____ __ __ ___ __________________ Yes_________ -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - -- - - - - - !23 Casing designs adequate for C,_T, B &_permafrost_ _ _ _ _ _ - - - - - Yes - --------- ----------------- - --- -- - - - - - -- ---- - - - - -- - - - - -- 24 Adequate-tankage or reserve pit - . - - . - _ - - - - - _ Yes - _ _ _ _ _ _ Rig is_equipped with steel -pits. -No reserve_ pit planned. All waste to approved annulus or disposal well($). 125 If_a_re- drill, has_a_ 1.0 7403 for abandonment been approved _ . - - - - _ _ - - _ -- - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - 26 Adequate wellbore separation - proposed _ _ - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ - _ - _ - Proximity_ analysis performed, Traveling cylinder path calculated. Gyros possible in surface_hole. - _ _ . _ - - _ _ 27 If_ diverterrequired, does it meet regulations ---------------- --- --- --- - - - - -- Yes_______________ - ----- - - - - - - - - - - - - - ----------------------- ------------------ Appr Date 28 _Drilling fluid program schematic &equip list adequate- - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Maxim um expected formation pressure up 11.0 _EMW._ PI_anned MW up to_11.0_ppg or as needed._ - - - - - _ _ _ TEM 7/3/2007 29 BOPEs,_dothey meet regulation - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- Yes - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 011 30 BOPE_press rating appropriate; test to -(put psig in comments) - - - - - - - - - - - - - - - - - - - Yes _ _ . _ _ _ . MASP calculated at 2511 psi_ 3500- psi -BOP test-proposed -- - _ - _ _ - - _ _ • ` 131 C-hoke_manifold complies w /API_ RP -53 (May 84)_ Yes _ _ _ _ - - - ----------------- ------------- ------------ - - - - -- -------------------- 32 Work will occur without operation shutdown- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - ---------------------------------------------------------------- 33 Is presence of H2S gas probable - - _ . - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - _ - - - - - ----------------------------------------------------- 34 Mechanical- condition of wells within AOR verified (_For service well only) _ _ _ _ _ _ _ . _ _ _ Yes _ _ _ _ _ _ - No AOR issues_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ F 35 Permitcan be issued w/o hydrogensulfide measures No Nearest offsetwell,KRU 2N -304, measured 56 ppm H2S on 10/13/2006.Geology Data_ presented on potential overpressure zones - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ - - _ _ 8.6 ppg-gradient expected_thru Cairn at 10986' MD / 5300'_TVD; Bermuda at 1- - - - D /_5- - - ND expected -- Appr Date 37 Seismic analysis_ of shallow gas_zones_ _ _ _ _ _ - _ _ - - _ - _ - - - - - - - - NA_ _ - - - - to have 11.0_ppg gradient. Mud program_indicates weights to_11.0_ppg will be used. - - - _ - - - - - - - _ - SFD 6/27/2007 i 38 Seabed condition survey (if off-shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ _ - _ _ --------- - - - - -- 39 Contact name /phone for weekly-progress reports [exploratory only] NA ---- - - - - -- ------ ------------------------------- --------------- Geologic Engineering ub i Well passes through unleased acreage: Section 2, T9N, R7E, UM. Productive interval lies more than 3900' from nearest property Date: Date Date Commissioner: Commissioner: Co miss r line. Will be preproduced from the Cairn interval for up to 6 months to test its production capability, then converted to injection in 7J' 7 / /O/ 7 �f> /O a e Bermuda interval. Both intervals are part of the Kuparuk River Tarn Oil Pool as defined in CO 430A. }� 7 Q p7 ,. /'�'" Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. I 2n- 310.tapx Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Dec 17 10:57:23 2007 Reel Header Service name .............LISTPE Date . ...................07 /12/17 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number ...... 01 Previous Reel Name....... UNKNOWN Comments .................STS LIS Writing Library. scientific Technical Services Tape Header Service name .............LISTPE Date . ...................07 /12/17 origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number ...... 01 Previous Tape Name....... UNKNOWN Comments .................STS LIS writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Tarn MWD /MAD LOGS WELL NAME: 2N -310 API NUMBER: 501032054900 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 17- DEC -07 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: w- 0005033959 w- 0005033959 w- 0005033959 LOGGING ENGINEER: B. STEPHENS B. STEPHENS B. STEPHENS OPERATOR WITNESS: D. MORRIS D. MORRIS D. MORRIS MWD RUN 4 MWD RUN 5 JOB NUMBER: w- 0005033959 W- 0005033959 LOGGING ENGINEER: B. STEPHENS 0. OBI OPERATOR WITNESS: D. MORRIS D. MORRIS SURFACE LOCATION SECTION: 3 TOWNSHIP: 9N RANGE: 7E FNL: 24 FSL: FEL: 602 Page 1 2n- 310.tapx FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 148.60 GROUND LEVEL: 118.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 16.000 80.0 2ND STRING 8.750 9.625 3520.0 3RD STRING 6.125 7.000 10828.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 -5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER - MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR4). MWD RUNS 4,5 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). ADDITIONALLY, MWD RUN 5 INCLUDED AZIMUTHAL LITHO - DENSITY (ALD) AND COMPENSATED THERMAL NEUTRON (CTN). THERE ARE DATA GAPS IN THE DGR (497' - 607'MD) AND THE EWR4 (489.5'- 599.5') DUE TO A BHA RECONFIGURATION. 4. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER PHONE CONVERSATION ON 12/17/07 BETWEEN D. KLEIBACKER (CPAI) AND B. BRYANT (SDS). MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1 -5 REPRESENT WELL 2N -310 WITH API #: 50- 103 - 20549 -00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11840'MD /6036'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT- DERIVED RESISTIVITY EXTRA- SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT- DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT - DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT- DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX,FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED (LOW -COUNT BIN). Page 2 2n- 310.tapx SCO2 = SMOOTHED STANDOFF CORRECTION (LOW -COUNT BIN). SNP2 = SMOOTHED NEAR - DETECTOR -ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW -COUNT BIN). SLIDE = NON - ROTATED INTERVALS REFLECTING BIT DEPTHS. DENSLIDE = NON - ROTATED INTERVALS ADJUSTED FOR BIT -TO- SENSOR DISTANCE. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: FIXED (6.125" BIT) MUD WEIGHT: 9.6 PPG MUD SALINITY: 700 -1200 PPM CHLORIDES FORMATION WATER SALINITY: 19149 PPM CHLORIDES FLUID DENSITY: 1.0 G /CM3 MATRIX DENSITY: 2.65 G /CM3 LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07 /12/17 Maximum Physical Record..65535 File Type. ............LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPD 171.0 11789.0 RPX 171.0 11789.0 RPS 171.0 11789.0 FET 171.0 11789.0 RPM 171.0 11789.0 GR 179.0 11781.5 ROP 223.5 11840.0 NPHI 10800.0 11753.5 NCNT 10800.0 11753.5 RHOB 10800.0 11769.0 DRHO 10800.0 11769.0 PEF 10800.0 11769.0 FCNT 10800.0 11753.5 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 MWD 1 171.0 541.0 MWD 2 541.5 2506.0 MWD 3 2506.0 3530.0 Page 3 2n- 310.tapx MWD 4 3530.0 10840.0 MWD 5 10840.0 11840.0 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 .1IN Max frames per record .............Undefined Absent value ...................... -999 Depth Units. .. .. ..... Datum Specification Block sub-type ... 0 Name Service Order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G /CC 4 1 68 12 4 DRHO MWD G /CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 NPHI MWD PU -S 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 171 11840 6005.5 23339 171 11840 FCNT MWD CP30 190.06 1072.51 456.265 1908 10800 11753.5 NCNT MWD CP30 17302.6 37846.9 26106.7 1908 10800 11753.5 RHOB MWD G /CC 0.39 2.989 2.41254 1939 10800 11769 DRHO MWD G /CC -2.795 0.449 0.0410005 1939 10800 11769 RPD MWD OHMM 0.69 2000 20.5776 23016 171 11789 RPM MWD OHMM 0.63 2000 17.8997 23016 171 11789 RPS MWD OHMM 0.11 1446.45 8.67413 23016 171 11789 RPX MWD OHMM 0.82 767.67 6.95946 23016 171 11789 FET MWD HR 0.21 130.59 2.12362 23016 171 11789 GR MWD API 9.45 232.37 112.675 22985 179 11781.5 PEF MWD B/E 2.22 12.25 3.53422 1939 10800 11769 ROP MWD FPH 0.06 2463.08 153.881 23234 223.5 11840 NPHI MWD PU -S 15.9 42.9 29.2442 1908 10800 11753.5 First Reading For Entire File.......... 171 Last Reading For Entire File ........... 11840 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number ........... 1.0.0 Page 4 Date of Generation ....... 07 /12/17 2n- 310.tapx Maximum Physical Record..65535 File Type ................LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07 /12/17 Maximum Physical Record..65535 File Type. ............LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 171.0 489.0 RPX 171.0 489.0 RPS 171.0 489.0 FET 171.0 489.0 RPD 171.0 489.0 GR 179.0 496.5 ROP 223.5 541.0 LOG HEADER DATA DATE LOGGED: 21- AUG -07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 541.0 TOP LOG INTERVAL (FT): 223.0 BOTTOM LOG INTERVAL (FT): 541.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 1.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 222163 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 80.0 BOREHOLE CONDITIONS MUD TYPE: Native /Spud Mud Page 5 MUD DENSITY (LB /G): 2n- 310.tapx 9.60 MUD VISCOSITY (S): 230.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 1000 FLUID LOSS (0): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 5.000 52.8 MUD AT MAX CIRCULATING TERMPERATURE: 3.150 87.8 MUD FILTRATE AT MT: 5.300 52.0 MUD CAKE AT MT: 5.100 52.0 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 AIN Max frames per record .............Undefined Absent value ...................... -999 Depth Units. .. .. ..... Datum Specification Block sub-type ... 0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD010 OHMM 4 1 68 4 2 RPM MWD010 OHMM 4 1 68 8 3 RPS MWD010 OHMM 4 1 68 12 4 RPX MWD010 OHMM 4 1 68 16 5 FET MWD010 HR 4 1 68 20 6 GR MWD010 API 4 1 68 24 7 ROP MWD010 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 171 541 356 741 171 541 RPD MWD010 OHMM 3.06 26.9 9.76462 637 171 489 RPM MWD010 OHMM 2.93 31.5 9.77077 637 171 489 RPS MWD010 OHMM 2.8 29.71 9.11631 637 171 489 RPX MWD010 OHMM 2.71 23.11 8.16287 637 171 489 FET MWD010 HR 0.21 4.96 1.91942 637 171 489 GR MWD010 API 18.73 109.17 53.8553 636 179 496.5 ROP MWD010 FPH 25.94 1208.85 275.831 636 223.5 541 First Reading For Entire File.......... 171 Last Reading For Entire File ........... 541 File Trailer Page 6 2n- 310.tapx Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07 /12/17 Maximum Physical Record..65535 File Type ................LO Next File Name ........... STSLIB.003 Physical EOF File Header service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07 /12/17 Maximum Physical Record..65535 File Type. ............LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 541.5 2506.0 RPS 600.0 2454.5 RPX 600.0 2454.5 RPD 600.0 2454.5 FET 600.0 2454.5 RPM 600.0 2454.5 GR 607.5 2462.0 LOG HEADER DATA DATE LOGGED: 23- AUG -07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 2506.0 TOP LOG INTERVAL (FT): 541.0 BOTTOM LOG INTERVAL (FT): 2506.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .7 MAXIMUM ANGLE: 69.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 222163 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER's CASING DEPTH (FT): 80.0 Page 7 2n- 310.tapx BOREHOLE CONDITIONS MUD TYPE: Native /Spud Mud MUD DENSITY (LB /G): 10.00 MUD VISCOSITY (S): 200.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 1000 FLUID LOSS (0): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 5.000 52.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.610 105.8 MUD FILTRATE AT MT: 5.300 52.0 MUD CAKE AT MT: 5.100 52.0 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 .1IN Max frames per record .............Undefined Absent value ...................... -999 Depth Units. .. .. ..... Datum Specification Block sub-type ... 0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 541.5 2506 1523.75 3930 541.5 2506 RPD MWD020 OHMM 0.69 1153.64 36.3396 3710 600 2454.5 RPM MWD020 OHMM 0.63 957.71 33.786 3710 600 2454.5 RPS MWD020 OHMM 0.79 403.23 24.8413 3710 600 2454.5 RPX MWD020 OHMM 0.91 181.33 17.3748 3710 600 2454.5 FET MWD020 HR 0.25 8.7 0.863186 3710 600 2454.5 GR MWD020 API 9.45 122.31 75.1479 3710 607.5 2462 ROP MWD020 FPH 0.27 2463.08 194.298 3930 541.5 2506 First Reading For Entire File.......... 541.5 Last Reading For Entire File ........... 2506 Page 8 2n- 310.tapx File Trailer service name... .......STSL2B.003 service sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07 /12/17 Maximum Physical Record..65535 File Type ................LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07 /12/17 Maximum Physical Record..65535 File Type..............LO Previous File Name ....... STSLIB.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 2455.0 3477.5 RPX 2455.0 3477.5 FET 2455.0 3477.5 RPM 2455.0 3477.5 RPD 2455.0 3477.5 GR 2462.5 3485.5 ROP 2506.5 3530.0 LOG HEADER DATA DATE LOGGED: 24- AUG -07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 3530.0 TOP LOG INTERVAL (FT): 2506.0 BOTTOM LOG INTERVAL (FT): 3530.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 67.1 MAXIMUM ANGLE: 71.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 222163 Page 9 BOREHOLE AND CASING DATA 2n- 310.tapx OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 80.0 BOREHOLE CONDITIONS MUD TYPE: Native /Spud Mud MUD DENSITY (LB /G): 10.00 MUD VISCOSITY (S): 200.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 1000 FLUID LOSS (0): 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 5.000 52.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.610 105.8 MUD FILTRATE AT MT: 5.300 52.0 MUD CAKE AT MT: 5.100 52.0 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 .1IN Max frames per record .............Undefined Absent value ...................... -999 Depth units. .. .. ..... Datum Specification Block sub-type ... 0 Name service order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 2455 3530 2992.5 2151 2455 3530 RPD MWD030 OHMM 4.71 16.4 8.19042 2046 2455 3477.5 RPM MWD030 OHMM 4.58 17.42 7.97399 2046 2455 3477.5 RPS MWD030 OHMM 4.4 16 7.63898 2046 2455 3477.5 RPX MWD030 OHMM 3.9 14.85 7.17668 2046 2455 3477.5 FET MWD030 HR 0.27 11.06 1.15427 2046 2455 3477.5 GR MWD030 API 56.92 144.98 95.7701 2047 2462.5 3485.5 ROP MWD030 FPH 19.27 310.54 173.158 2048 2506.5 3530 Page 10 i 2n- 310.tapx First Reading For Entire File.......... 2455 Last Reading For Entire File ........... 3530 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07 /12/17 Maximum Physical Record..65535 File Type ................LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07 /12/17 Maximum Physical Record..65535 File Type. ............LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 3475.5 10785.0 RPS 3478.0 10785.0 RPD 3478.0 10785.0 RPX 3478.0 10785.0 FET 3478.0 10785.0 GR 3486.0 10793.0 ROP 3530.5 10840.0 LOG HEADER DATA DATE LOGGED: 01- SEP -07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 10840.0 TOP LOG INTERVAL (FT): 3530.0 BOTTOM LOG INTERVAL (FT): 10840.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 38.7 MAXIMUM ANGLE: 70.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 120557 Page 11 i 2n- 310.tapx EWR4 ELECTROMAG. RESIS. 4 145654 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 3520.0 BOREHOLE CONDITIONS MUD TYPE: Native /Spud Mud MUD DENSITY (LB /G): 9.70 MUD VISCOSITY (S): 43.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 350 FLUID LOSS (0): 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.960 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.040 134.0 MUD FILTRATE AT MT: 3.100 68.0 MUD CAKE AT MT: 2.100 68.0 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 AIN Max frames per record .............Undefined Absent value ...................... -999 Depth Units. .. .. ..... Datum specification Block sub-type ... 0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3475.5 10840 7157.75 14730 3475.5 10840 RPD MWD040 OHMM 1.51 2000 13.3583 14615 3478 10785 RPM MWD040 OHMM 1.65 2000 9.02614 14617 3475.5 10785 RPS MWD040 OHMM 0.11 31.1 4.47485 14615 3478 10785 RPX MWD040 OHMM 1.62 19.65 4.3373 14615 3478 10785 FET MWD040 HR 0.27 98.61 1.50073 14615 3478 10785 Page 12 • 2n- 310.tapx GR MWD040 API 47.91 220.86 124.798 14615 3486 10793 ROP MWD040 FPH 0.44 917.95 151.227 14620 3530.5 10840 First Reading For Entire File.......... 3475.5 Last Reading For Entire File ........... 10840 File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07 /12/17 Maximum Physical Record..65535 File Type. .LO Next File Name ........... STSLIB.006 Physical EOF File Header service name... .......STSLIB.006 Service sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07 /12/17 Maximum Physical Record..65535 File Type. ............LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPx 10785.5 11789.0 RPM 10785.5 11789.0 FET 10785.5 11789.0 RPS 10785.5 11789.0 RPD 10785.5 11789.0 GR 10793.5 11781.5 FCNT 10800.0 11753.5 NCNT 10800.0 11753.5 RHOB 10800.0 11769.0 DRHO 10800.0 11769.0 NPHI 10800.0 11753.5 PEF 10800.0 11769.0 ROP 10840.5 11840.0 LOG HEADER DATA DATE LOGGED: 09- SEP -07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 11840.0 TOP LOG INTERVAL (FT): 10840.0 Page 13 BOTTOM LOG INTERVAL (FT): 2n- 310.tapx 11840.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 18.6 MAXIMUM ANGLE: 40.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 CTN COMP THERMAL NEUTRON 1844674407370955 EWR4 Electromag Resis. 4 159439 ALD Azimuthal Litho -Dens 10508942 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10828.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB /G): 9.60 MUD VISCOSITY (S): 62.0 MUD PH: 9,9 MUD CHLORIDES (PPM): 500 FLUID LOSS (0): 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.800 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.520 135.0 MUD FILTRATE AT MT: 3.300 70.0 MUD CAKE AT MT: 3.000 70.0 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 AIN Max frames per record .............Undefined Absent value ...................... -999 Depth Units. .. .. ..... Datum specification Block sub-type ... 0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MWD050 CP30 4 1 68 4 2 NCNT MWD050 CP30 4 1 68 8 3 RHOB MWD050 G /CC 4 1 68 12 4 DRHO MWD050 G /CC 4 1 68 16 5 RPD MWD050 OHMM 4 1 68 20 6 RPM MWD050 OHMM 4 1 68 24 7 RPS MWD050 OHMM 4 1 68 28 8 Page 14 2n- 310.tapx RPX MWD050 OHMM 4 1 68 32 9 FET MWD050 HR 4 1 68 36 10 GR MWD050 API 4 1 68 40 11 PEF MWD050 B/E 4 1 68 44 12 ROP MWD050 FPH 4 1 68 48 13 NPHI MWD050 PU-S 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 10785.5 11840 11312.8 2110 10785.5 11840 FCNT MWD050 CP30 190.06 1072.51 456.265 1908 10800 11753.5 NCNT MWD050 CP30 17302.6 37846.9 26106.7 1908 10800 11753.5 RHOB MWD050 G /CC 0.39 2.989 2.41254 1939 10800 11769 DRHO MWD050 G /CC -2.795 0.449 0.0410005 1939 10800 11769 RPD MWD050 OHMM 0.95 2000 60.0528 2008 10785.5 11789 RPM MWD050 OHMM 0.9 2000 67.8089 2008 10785.5 11789 RPS MWD050 OHMM 0.87 1446.45 10.282 2008 10785.5 11789 RPX MWD050 OHMM 0.82 767.67 6.19793 2008 10785.5 11789 FET MWD050 HR 0.9 130.59 10.0384 2008 10785.5 11789 GR MWD050 API 62.29 232.37 129.906 1977 10793.5 11781.5 PEF MWD050 B/E 2.22 12.25 3.53422 1939 10800 11769 ROP MWD050 FPH 0.06 212.17 35.3455 2000 10840.5 11840 NPHI MWD050 PU -S 15.9 42.9 29.2442 1908 10800 11753.5 First Reading For Entire File.......... 10785.5 Last Reading For Entire File ........... 11840 File Trailer Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation ....... 07 /12/17 Maximum Physical Record..65535 File Type ................LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer service name .............LISTPE Date . ...................07 /12/17 origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments .................STS LIS writing Library. scientific Technical services Reel Trailer Service name .............LISTPE Date . ...................07 /12/17 Ori?in ...................STS Reel Name. .... ........UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Page 15 2n- 310.tapx Physical EOF Physical EOF End Of LIS File Page 16 i ConocoPhillips Alaska, Inc. FINAL WELL REPORT ConocoPhillips Alaska, Inc. TARN 2N -310 24' FNL, 602' FEL Sec 3 — T9N - R7E, UM North Slope, Alaska IL 1N' z r' ?ze try r Compiled by: Lees F. Browne, Jr. September 9, 2007 14 EPOCH COnOCOPhillips Tam 2N 310 TABLE OF CONTENTS • 1 MUDLOGGING EQUIPMENT & CREW ................................. ..............................1 1.1 Equipment Summary .......................................................... ..............................1 1.2 Crew ................................................................................... ..............................2 2. GENERAL WELL DETAILS ...................................................... ..............................1 2.1 Objectives ............................................................................ ..............................1 2.2 Well Summary ...................................................................... ..............................1 3. GEOLOGICAL DATA ................................................................ ..............................2 3.1 Lithostratigraphy ................................................................. ..............................2 3.2 Mudlog Summary ................................................................ ..............................3 3.3 Sampling Program / Sample Dispatch .............................. .............................26 3.4 Cali Bond Gas Bag Sample and IsoTube Inventory ........ .............................27 4. PRESSURE / FORMATION STRENGTH DATA ...................... .............................28 • 4.1 Formation Integrity /Leak Off Tests ................................... .............................28 4.2 Pore Pressure Evaluation Introduction ............................ .............................28 4.3 Pore Pressure Summary .................................................... .............................29 5. DRILLING DATA ...................................................................... .............................30 5.1 Daily Activity Summary ..................................................... .............................30 5.2 Bit Record ........................................................................... .............................34 5.3 Survey Record .................................................................... .............................35 5.4 Mud Record ...................................................................... .............................39 14 EPOCH 3 • • 0 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Comments Total Downtime QGM electric gas trap Flame Ditch gas ionization total & chromatograph 1 hour Replace agitator in top hole section.; detector Sent to Totco via WITS Rate of penetration (ROP) BEI Encoder- Primary draw works - No problems block position indicator RIGWATCH Turck Magnetic Minor adjustments Pump stroke counter (SPM) proAmity sensor - while drillin Hook Load (HLKD) /Weight RIGWATCH Ametek Hydraulic on bit OB pressure cell - No problems Torque RTOQ Top Drive Feed - Not receiving Torque signal from Totco Top drive rota RPM Top Drive Feed - Totco Wits feed Standpipe & casing pressure SPP /CSIP Totco Hydraulic pressure cell - Mud flow out (FLOW) Totco Flow Paddle - Totco Wits Feed Ball Float sensors in all pits & trip Pit levels x 6 tank - Totco Wits Feed Mud logging unit computer system Com ac Pentium III - No problems Geologist's workstation Com ac Pentium III Totco Workstation Corn any Man's workstation rcompac om ac Pentium III - Totco Workstation Tool usher's workstation Pentium III - Totco Workstation H EPOCH i • ConocoPhilli • 40 In Tam 2N 310 1.2 Crew Unit Type Arctic Unit Number : ML012 Mudloggers Years Days Geotechnicians Years Days Technician Trainees " 1 On On Pad Pad I John Lundy 16 7 Ryan Massey 1 20 Brian O'Fallon 23 7 Mainuddin 1 20 Chowdhu Lees F. 26 13 Browne Jr. Steven Pike 4 12 '1 Years experience as Mudlogger Additional Comments Two spare poly -flow gas lines were run through a heated umbilical to insure non freezing for the gas lines and rig air lines to the unit. The QGM gas trap was routinely cleaned of drilling mud and the gas lines blown back with rig air during connections and bit trips. Pump Pressure was calibrated relative to Totco. Block height was recalibrated to ensure accuracy after every cut and slip, and after casing runs. Calibration of Gas Detection and Chromatograph was checked and recalibrations performed if necessary to confirm accuracy. Calibrations on all equipment held extremely well throughout the well. H EPOCH 2 2. GENERAL WELL DETAILS 2.1 Objectives 2N -310 is a combination Exploration and Development well whose primary purpose is to establish reservoir quality and injection support on the eastern margin of the Bermuda reservoir. A secondary objective of the 2N -310 is to perform an extended flow test to investigate reservoir properties in the slightly shallower Cairn prospect. 2N -310 is designed to obtain open -hole log data across both formations, perform an extended test in the Cairn reservoir and ultimately be completed as an injector in the Bermuda reservoir. 2N -310 well design consists of a 9 5/8" surface casing, 7" intermediate casing top set above the Bermuda pay interval and a 4'/" cemented production liner. H EPOCH i • • • 2.2 Well Summary Well 2N -310 API 103- 20549 -00 Classification Exploration Block N/A Nordic KB Elevation 148.6' AMSL KB Elevation Rig Name / Drilling/ Surface Co- 30' S 3 EC 3, Type Land Ordinates F , T9N, FE R7E , S , Nordic # 3 uM Primary Bermuda T- Primary Target 11179' MD/ 5459' Secondary CAIRN/ Secondary 10997' Target 3 Depth TVD Target ESKER Target Depth 11593' Spud Date 8/21/2007 TD Depth 11840' MD/ 6058' TD Formation ESKER TD Date 9/9/07 SS TVD Completion N/A Suspension N/A Days Drilling 19 Days Testing NIA Status -5887 Date TD Mud FIT Hole Maximum Depth Formation Weight Deviation Coring Casing Shoe Depth (ppg) Section TVDSS (ppg) (o inc) / Liner MDRT (ft) (ft) 12.25" 3530 -2248 WEST SAK 90 1 0-70 NONE 9 5/8" 3520 2244 12.8 8.5" 10840' -5012 T -7 9 ' 6 70 0 -38 0 NONE 7" 10828' - 14.8 9.7 5002 7" 11840' ESKER 9.6 -10.0 38 19 NONE 4.5" H EPOCH Conoco Phillips Tam 2N 310 Additional Comments: Epoch commenced logging the 2N -310 on 8/21/07 at 80' drilling out of 16" conductor pipe, tagging ice at 120'. Samples were caught at 50' intervals to 6030' (100'above the Bermuda formation). Gas bags were collected at 500' intervals and at gas kicks to a depth of 5900'. Sample catchers were used throughout the well. Isotubes were collected in 30' intervals starting from 100' above the Bermuda Formation (6050') and a 10' sampling program was started with ditch cuttings. Drilling commenced at 0.73° drilling with a mud motor. The inclination was brought to 70.4 AT 3530' (surface casing). The inclination was held to 9756', in which angle was dropped to 38.7 at 10840'. The inclination was decreased to 19.28 at 11840'. No hole roblems were encountered drilling the surface hole. Permafrost ravel N , � caused minor problems with the gas trap, with gravel being caught in the agitator spindles and breaking off one of the three spindle prongs. The spindle was replaced and drilling commenced under the Permafrost and again gas trap problems occurred with massive thick clays plugging off the gas trap and overloading the possum belly. Rig crew hands were consistently washing down the shale shakers to enhance sample recovery and keep from losing drilling mud fluids off the shale shakers. Running sands and gravel were limited in scope with maintained mud parameters. Sample Catchers checked and cleared the gas trap of clay accumulation at each sample interval, and whenever a change in gas or lithology was noted. Gas hydrates flows showed a maximum recording of 3942 units with mud weights running 9.6 to 10.1 The mud system was swapped from Spud mud to LSND at 3530'. No hole problems were encountered while drilling from 3530' to the top of the Bermuda (Intermediate Hole Section). Good hole cleaning techniques were used drilling the deviated hole (70 with high viscosity sweeps and good flow rates. Each connection allowed circulating time to clean the hole of cuttings above the BHA. All hole trips showed no drag or sticking. Slower trip and connection speeds prevented swab /surge damage to the hole. Good maximum ROP effective rates were obtained to clean the angled hole with assistance of using torque and drag trends, ECD and shale shakers productivity to establish a clean hole baseline. The production hole section drilled with no hole or drilling problems. No lost circulating or hole sticking was encountered. The drill string was kept moving whenever possible to avoid sticking. The ROP was controlled to 50 ft/hr to record good ditch cuttings throughout the production zone. Additionally, care and attention was taken to avoid over washing. The hole was breathing (taking fluid and giving it back) through the Berumda to Esker with only very minor losses. Upon reaching total depth (11840) the well was flowing slightly and the mud weight raised from 9.6 to 10.0 and the well monitored. H EPOCH 1 COnocOPh1111ps Tam 2N 310 3. GEOLOGICAL DATA 3.1 Lithostratigraphy Drilling picks & actual wireline tops refer to provisional picks provided by the wellsite Geologist. DRILLING ACTUAL WIRELINE HIGH/LOW FORMATION PROGNOSED PICK PICK (ft) MDRT TVD/TVDSS MDRT (ft) (ft) (ft) MD TVD/TVDSS 9 5/8° Casing 3520' 24007-2249' 3520' 23937 -7' Shoe -2244' C80 (K10) 3822' 25057-2355' 3847' 26047 -11 -2355' Camp Sand NA NA N/A N/A NA C50 8072' 39807-3830' 8010' 39497 -31' -3800' C40 8734' 42107 -4060' 8730' 41997 -11' -4050' C37 9152' 43557-4205' 9238' 4375/ -20' -4226' T7 10705' 50657-4915' 10678' 50377 -28' -4888' 7" Casing , - 10828' 5151'/ +14' Shoe 10800 5137/4987 , -5002 T4 10968' 52747-5124' 11079' 53457 +71' -5196 Caim Top 10997' 53007-5150' 11098' 53607 +60' -5211' Caim Bottom 11089' 53807-5230' 11243' 54797 +99' -5330' T3 Top 11179' 54597-5309' 11270' 55047 +45' Reservoir -5355' T2 Base 11273' 55447-5394' 11353' 55777 +33' Reservoir -5428' C35 (K -3) 11471' 57257-5575' 11484' 57007 -25' -5551' Esker (Top) 11593' 58347-5684' 11646' 58527 +18' 5703' Esker(Base) N/A N/A 11707' 59107 N/A -5761' TD 11840' 6058' _ 11840' 60367 -22' 5908' -5887 H EPOCH 2 GonocoPhiiiiPS Tam 2N 310 3.2 Mudlog Summary The following text provides a brief summary of the defining lithological and drilling characteristics for that part of the well, over which drill cuttings were collected. Surface to Surface Casing Point 80' to 3530' MDRT ( +68' to -2248' TVDSS) The 2N-310 was commenced on 8/21/07 from surface. Formation was encountered at 80' as drilling progressed under surface conductor pipe. Mud weight was 9.6 ppg at surface with an increase to 10.1 by 1900'. Surface casing was run to 3520'. FIT was run with an EMW of 12.8 ppg. Trip gas of 0 units was recorded after the Leak Off Test. Samples collected from surface to the top of the permafrost were predominantly coarse grain sands (conglomerate) with heavy thick clays. The clays composed of clay and claystone being light gray to medium gray and very soft. The overall consistency and tenacity of the clay was malleable to sectile when cohesive, lumpy to clotted to gelatinous to slimy overall. Clays exhibited moderate to good cohesion with very good adhesion. There were no visible structures with a rare silty texture. Solubility was fair to moderate with moderate expansion and easily hydrated. Abundant pebble conglomerate was collected from roughly 100' to 950'. The lithologic color was very light gray to light medium gray and scattered light green to dark brown and various hues of all. Clast size ranged from pebble (possible cobble) to very coarse with scattered medium to lower coarse grain as matrix sands. Cuttings displayed an abundant angularity with bit impacted fragments scattered with sub round to sub angular matrix sands throughout the conglomerate section. Most sands displayed low to moderate developed sphericity with very poor sorting and a general polished texture with pitting to impacted textures in matrix sands. No visible cement was noted and samples appeared to be of sub mature nature. Matrix material was very slight to non existent. Cuttings contained greater than 50% lithics with fair to good estimated porosity and permeability and no show of oil. Conglomerate sands graded finer downward to a coarse grained sand towards the base of the conglomerate zone (900'). Samples below the permafrost were predominantly clay and claystone and sand. Cuttings became very thick and clumpy plugging the possum belly and gas trap with thick, extremely cohesive and adhesive clay -rich sediment. Clays were very homogeneous showing a light gray to very light gray and being very soft to soft. Cuttings displayed various consistency and tenacity throughout the lower zone being: malleable to sectile, mushy to pasty, tacky to slimy with slight to moderate cohesiveness and moderate adhesiveness. The clay fracture was amorphous with a massive habit and a moderate earthy luster. Texture was dominantly clayey with massive homogeneous clay composed of greater than 90% i clay with minor silt, very fine grain sand, pyroclastic relic shards and various detrital materials. Overall; clean clay. The unconsolidated sands were light gray to very light gray, soft, moderate to well sorted with clast size ranging from fine lower to fine upper H EPOCH 3 Conocof'hillips Tam 2N 310 grains. Grains displayed sub angular to sub rounded shape with translucent quartz 0 predominantly with common milky and smoky quartz. Scattered in minor amount were common medium gray lithic grains with trace various coloured lithics. The sands graded to and became interbedded with associated siltstones. ands were primarily g S p y grain supported with occasional thin beds of poorly indurated fragments displaying abundant clay matrix support. Trace amounts of very fine calcite. Sand becomes 50% to 60% of the samples after 3100' with primarily grain supported with possible hydrophilic matrix being lost in circulation of the drilling mud. Siltstones, as with the sands and clays were gradational and interbedded throughout the zone. Silts displayed a uniform light gray to very light gray colour with a slight yellowish secondary hue. Hardness was soft to slightly firm with occasionally stiff irregular fragments with a dull earthy luster. Textures were slight to very gritty possibly due to sand mechanically worked in during circulation. The silt occurs as interbeds in gradational contact within massive claystone beds. Drill Rate ( ft/hr) Total Gas ( °�) Maximum Minimum Average Maximum Minimum Average 334 4 204 3942 0 135 Surface Casing to C-80 3530' to 3847' MDRT ( -2244' to -2355' TVDSS) • From under surface casing to the top of the C-80, samples consisted of predominantly siltstones being medium gray to light gray with a very slight brownish secondary hue. Samples were firm to moderately soft with dull earthy to gritty luster with a slight sandy /gritty texture. Samples noted a trace of poorly developed fissility with cuttings generally sub blocky to irregular in habit. Throughout the samples are traces of fine carbonaceous inclusions and trace very thin carbonaceous micro lamina. Overall the silts were interbedded and grading to very fine grain silty sand. Minor clay beds or inter beds are throughout the zone. Drill Rate (ft/hr) Total Gas ( %) Maximum Minimum Average Maximum Minimum Average 245 65 178 92 4 38 C -80 to C -50 3847' to 8010' MDRT ( -2355' to -3800' TVDSS) The C -80 formation was drilled at 68 to 70 thus having a long outreach of the formation from 3847' to 8010. The drill rate was 160 to 200 ft/hr. Samples consisted . of siltstone, sandstone and clay. From 3847' to 5615' samples consisted of predominantly siltstone with secondary sands and clays. The siltstone was light brownish gray and displaying poor to some moderate induration; being generally [4 EPOCH 4 Con000Phillips Tam 2N 310 brittle and crumbly to crunchy. Cuttings showed a slight cohesiveness with non to slight adhesiveness and showed an earthy fracture with a sub nodular habit and dull earthy luster. Textures were silty to gritty to an occasional sub sucrosic texture when grading to a very fine grained sandstone. Overall a massive gradational section of silt and thin clean sands being very fine grained. Sandstones and sand were light gray to light brownish gray and generally unconsolidated with scattered poorly consolidated fragments. Clast size ranges from very fine upper to fine lower with sub angular to sub spheroidal to occasionally sub rounded clear to translucent white quartz. Sandstones show grain support and matrix support with poor porosity and permeability and grade to associated siltstones. At 3930' to 3935' a trace very dull brownish fluorescence with no visible oil stain or odor with trace cuts. From 4000' to 4050' a common bright yellow gold to yellow orange sample fluorescence was noted with a moderate streaming yellow white cut fluorescence with a fair yellow gold residual cut. 40 unit gas increases were noted on both show zones. Clays were going into solution and grading to siltstones with a medium gray with secondary brownish hues and being very soft to slightly firm when grading to silt. Clays displayed a dull earthy to gritty luster and a slight sandy to gritty texture with traces of poorly developed fissility. Cuttings are generally sub blocky to irregular in habit and slightly to non adhesive and moderate cohesive. Overall clean clays are very hydrophilic and tend to form clayey masses at the shaker. Traces of fine to very fine carbonaceous inclusions and rare micro fine carbon laminae are noted. From 5600' to 6350' sandstone is the dominant lithology. The sandstones are light brownish gray and commonly mottled light gray with ashy sand inter beds. Clast size ranges from fine lower to very fine lower and grading to silt in a clayey to very silty ashy matrix. Sand grains are sub angular to sub round with moderate developed sphericity with poor sorting. Grains display impacted textures and an immature to mature nature. Overall non to slight calcareousness with moderate silt structured matrix. Grains are both grain and silt matrix supported and composed of predominantly quartz. Some micro carbon inclusions and display low porosity and permeability. At 6405' the shaker screens were changed out to add a larger mesh screens and thus stopping the mud run off at the end of the shakers. In doing so the sample percentage of sandstone dropped from 60% to only 25 -30 %. Gradational silt was the dominant lithology to 7550'. The siltstones were gradational from silt and grading to very fine grained sandstones in thin to micro beds. Silts were pale yellowish brown to light brownish gray and poor to some moderate induration. Silts were overall brittle to slightly stiff being crumbly and crunchy with cuttings displaying a slight cohesiveness and a non adhesive structure. Fractured cuttings were earthy with a silty to gritty texture and a dull earthy luster. Samples are very gradational with very fine grained sands and slight to moderate amount of interbedded detrital material. From 7550' to the top of the C -50 samples were predominantly sandstone very light gray with clast size ranging from fine lower to very fine lower. Grains sub angular to sub round with moderate developed sphericity and poor sorting. Textures are pitted to impact with a sub mature to mature nature and a non calcareous reaction. Samples are arenaceous with a very slight matrix material and predominantly grain supported with abundant grain overgrowths giving a poor porosity and permeability and grading to a sandy siltstone. H EPOCH 5 ConoCOl�hilliPS Tam 2N 310 • Drill Rate (ft/hr) Total Gas ( °k) Maximum Minimum Average Maximum Minimum Average 319 2 162 109 2 30 C -50 to C-40 8010' to 8730' MDRT ( -3800' to -4050' TVDSS) The C -50 is composed of gradational siltstone and very fine grained sandstones with minor clays. The siltstones are light brownish gray to pale yellowish brown to yellowish gray and various hues of all colours. Induration is poor to moderate with some well developed locally with an overall brittleness to very slightly stiff in parts through gradational sequences with some grading to hydrophilic silty clay. Overall consistency is mushy to pasty and being non to moderate cohesive and moderate adhesive. The fracture of cuttings is amorphous to blocky and shapes are massive to sub nodular with a dull earthy luster. Textures are clayey to silty with massive gradational silt, clay and silty sandstones present. Sandstones and very minor sand is clear to light gray to off white with clast sizes ranging from fine lower to very fine grained and grading to silt. Sphericity is moderate and grains are poorly sorted. Sands display slight calcareous cement and trace carbonaceous specs interbedded with a overall poor porosity and permeability. Claystones are minor in percentage and appear dark gray to medium dark gray with some grayish brown. Hardness is brittle to slightly firm with a irregular to amorphous fracture and amorphous cutting habit. All display very earthy to dull lusters with a clayey texture with thin inter beds of siltstone, sandstone and sand. Drill Rate (ft/hr) Total Gas ( °�) Maximum Minimum Average Maximum Minimum Average 226 33 145 60 13 39 C-40 to C -37 8730' to 9238' MDRT (4050' to -4226' TVDSS) The C-40 interval is represented by predominantly siltstone with thin bedded sands. A lower sequence of carbonaceous silty shale comprises the bottom of the formation. The siltstone is brownish gray to light brownish gray and grading to dark brown to medium grayish brown with depth. Minor hues of very dusky red and dark reddish brown are noted at 8800' to 8900'. Samples are firm to stiff with an amorphous fracture and amorphous cuttings habit. Silts display a very dull earthy texture with some slightly gritty textures within very thin lenses of sand and minor gritty claystones. Minor claystones are noted from 8900' to 9000'. Clays are dark gray to brownish gray with some slight light olive gray. Samples are firm to brittle with a N EPOCH 6 COnOCOPh111IpS Tam 2N 310 • irregular to amorphous fracture and amorphous cuttings habit. Overall, a very earthy to dull luster with a clayey texture with some slight gritty lenses of siltstone and very fine grained sandstone. From 9000' to the base of the C-40 silt and carbonaceous silty shale is noted. The carbonaceous silts are brownish gray distinctly mottled brownish black and various hues of both colours. Samples are brittle to flexible displaying a planar fracture and a flaky to scaly habit with a greasy to earthy luster. Textures are matte to mottled silty with thin to laminae beds of very carbonaceous silt and shale all with planar orientation. Drill Rate (ft/hr) Total Gas ( °�) Maximum Minimum Average Maximum Minimum Average 235 47 136 73 14 45 C -37 toT -7 9238' to 10678' MDRT ( -4226' to -4888' TVDSS) The C -37 sequence displayed gradational siltstones and predominant unconsolidated sand. The siltstones are dark brown to medium grayish brown with hues of pale reddish brown, dusky red and dark yellowish orange, moderately stiff to firm, with . irregular to slightly splintery fractures. Cuttings habit are amorphous with a dull earthy luster. Textures are very silty with very thin interbedded with very thin lenses of sand throughout. The predominant lithology of sand is white to frosted white with light gray to clear and translucent colours. Comprised of predominantly quartz grains in very fine grain size to lower medium grain sizes samples are poorly sorted with sub round to sub angular with very well rounded to very angular grains. Sands were frosted to pitted to some polished surface textures. Fair to moderate porosity and permeability with scattered aggregate pyrite crystals with no show of oil cuts was noted. Drill Rate (ft/hr) Total Gas ( %) Maximum Minimum Average Maximum Minimum Average 319 17 129 676 15 60 T -7 to T-4 (Iceberg) 10678' to 11079' MDRT ( -4888' to -5196' TVDSS) The T -7 interval displayed siltstone which becomes gradational and becoming interbedded with unconsolidated sand. The siltstones are medium dark gray to medium gray becoming brownish gray with some hues of reddish brown, dusky red • and dark yellowish orange. Samples are stiff to firm with irregular to slightly splintery fracture with an amorphous cuttings habit and a prominent dull earthy luster with a very silty texture and thinly interbedded with very thin lenses of sand. H EPOCH 7 ConocoPhi lips Tam 2N 310 The sand and minor sandstones are thinly bedded and become interbedded with . siltstone. Colours are light gray to white with some translucent to clear quartz grains throughout. Clast size ranges from fine upper to medium lower with sub angular to sub rounded shape with moderate sphericity with fair porosity and permeability. Some very poor trace cuts are noted. Possibly these are from mud additives (pipe dope, etc.) Minor amounts of C -5 are noted at less than 15 ppm. Intermediate casing was run to 10828' and ten foot samples caught from 10900' until 11840'. Drill Rate (ft/hr) Total Gas ( %} Maximum Minimum Average Maximum Minimum Average 198 4 66 34 2 15 T-4 to Cairn Top 11 079' to 11 098' MDRT ( -5196' to -5211' TVDSS) From the bottom of the T-4 to the top of the Cairn, the total footage is only 19'. Samples were a mix of siltstone (50 %) and sand and sandstone (50 %). The siltstone is medium gray to light gray with some dark brownish gray in parts. Cuttings were very soft to slimy with irregular to amorphous fracture and habit. • Lusters were very dull to somewhat earthy with a silty to slightly gritty texture. Sand and sandstones were thinly bedded to some interbedded throughout the short section. Drill Rate (ft/hr) Total Gas ( °�) Maximum Minimum Average Maximum Minimum Average 77 9 31 13 6 11 Cairn Top to Cairn Bottom 11098' to 11243' MDRT ( -5211' to -5330' TVDSS) The Cairn formation is a distinct change of formation from siltstone with thin sand beds to 100% sandstone and unconsolidated sand. The sand is very light gray to light gray with clast size ranging from fine upper to very fine upper with sands becoming coarse at 11150' (medium upper to fine lower). Sands are sub round with moderate sorting with no abundant faction. Textures are impacted to pitted with a overall mature nature. No visible matrix material is noted with dominant grain support and a slight amount of calcareousness. Samples are dominantly unconsolidated with fair to good estimated porosity and permeability. Samples show an increase in sandstone towards the base with a smaller clast size of very fine to fine. Sorting is poorer than the sand with less porosity and poor H EPOCH 8 ConocoPhillips Tarn 2N 310 permeability with grain overgrowths. A 25 to 50% even to patchy light yellow green • sample fluorescence is noted with an instant dull translucent light blue green sample cut. Samples are slow to develop and are very poor oil cuts. A possible oil "flush" of the unconsolidated sands is possible resulting in poor oil cuts as the oil matrix is flushed into the mud system and leaving flushed sands. Background gas was 10 to 20 units. Two gas kicks were noted with 9.6 mud weight. The first kick reached a maximum of 229 units from 11185' to 11200' and the second kick from 11215' to 11230' with a maximum gas reading of 255 units. C -1 through C -5 was noted throughout the start of the Cairn formation and through its base. U:j EPOCH CPAI 2N -310 North Slope, AK aM+ r' i 05 �� • U EPOCH 9 ConocoPhiliiPs M2N-310 lope, AK H EPOCH 10 r { w ,. r — - ConOCOPhillipS Tam 2N 310 CPAI [I EPOCH 2N-3 • 2N -310 North Slope, AK ir CPAI -r f i • tmm 0.5 • H EPOCH 2N _ 2N -310 « North Slope, AK P d� r 7 mm • U.5 H EPOCH 11 ConocoPhillipS Tarn 2N 310 II EPOCH CPAI • 2N -310 North Slope, AK . Y _ y R , e t .F � I I F i i • H EPOCH 12 ConocoPhillips Tarn 2N 310 E4 EPOCH CPAI • 2N -310 North Slope, AK Mad, 10 4 -0% 4 y �> y • C4 EPOCH 13 1w I COnOCOPhillips Tam 2N 310 H EPOCH CPAI • 2N -310 North Slope, AK K a � 0 ., as W N I� • r � i � 1 mm — H EPOCH 14 ConocoPhillips Tarn 2N 310 E� EPO CH CPAI 2N -310 North Slope, AK ti 4 4 V M • 1mm U.5 1 Drill Rate (ft/hr) Total Gas ( %) Maximum Minimum Average Maximum Minimum Average 532 4 42 255 8 76 Cairn Bottom to T3 (Top Reservoir) 11232' to 11270' MDRT ( -5321 to -5355' TVDSS) From the bottom of the Cairn (11232') to the top of the T -3 (11270') is only 38'. Samples were 80% sandstone very light gray with some white. Clast size ranges from very fine lower to very fine upper with some medium lower. Clasts were sub round to round with moderate developed sphericity with poor to moderate sorting. Textures were pitted and overall sandstones being sub mature in nature. Moderate grain overgrowths were noted giving poor porosity and permeability. Continued 25% even to patchy light yellow green sample fluorescence with poor slow developed oil cuts. Very poor oil shows with continued C -5 readings through the formation. H EPOCH 15 ConocoPhillips Tam 2N 310 [I EPOCH CPAI 2N -310 North Slope, AK 100 4 • EPOCH CPAI 2N -310 North Slope, AK WW ,4 t 4 4 0.5 • H EPOCH 16 ConoCOPhillips Tam 2N 310 • Drill Rate (ft/hr) Total Gas ( %) Maximum Minimum Average Maximum Minimum Average 532 7 51 35 10 25 T3 (Top Reservoir) to T2 (Base Reservoir) 11270' to 11353' MDRT ( -5355' to -5428' TVDSS) From the top of the T -3 to the top of the T -2 samples were predominantly sand and sandstone. Continued C -5 through the formation marked by two gas kicks. Average background readings were 15 to 20 units. The first kick (11300' to 11310') was 169 units. The second kick (11325' to 11335') was 135 units. Samples were 60% unconsolidated sand and 40% sandstone. The sandstones were the equivalent of the Cairn. The sands were light gray to medium gray with white to clear and translucent colours. Sands were mostly quartz grains with clast size ranging from very fine upper to fine upper. Sands were moderately sorted and sub angular to sub round with moderate sphericity. No visible matrix material was noted with moderate porosity and permeability. Sample fluorescence was 50 to 70% dull pale • yellow with an instant dull hazy to milky oil cut and a very poor to poor cuts overall. H EPOCH CPAI 2N -310 North Slope, AK _ g r. r� A i 7 mm • 03 � H EPOCH 17 Cor)OCI PhilliPs Tam 2N 310 E4 EPOCH CPAI 2N -310 North Slope, AK Ir t s T • [I EPOCH 18 ConocoPhillipS Tam 2N 310 . , CPAI • *, 2N -310 North Slope, AK Aid � s r i H EPOCH CPAI 2N -310 North Slope, AK Ir Iw }: Y • � 1mm H EPOCH 19 ConocoPhillips Tam 2N 310 H EPOCH *� CPAI 2N -310 North Slope, AK d� t Drill Rate (ft/hr) Total Gas Maximum Minimum Average Maximum Minimum Average 158 4 29 169 4 42 T2 (Base Reservoir) to C35 11353' to 11484' MDRT ( -5428' to -5551' TVDSS) The T -2 to the C -35 consists of sandstone grading to siltstone and a general decrease of C -5 through the transition of the formation. The sandstones are medium gray to light gray with some clear to some white. Clast size ranges from very fine upper to fine lower and consisting of predominantly quartz. Samples are moderately sorted with sub angular grains and moderate sphericity. Textures display slightly frosted and etched markings. Porosity is moderate to poor with slight calcareous • cement. Moderate grain overgrowths are noted with poor permeability. No shows of oil fluorescence or oil cuts. The sandstones grade into a light gray (11470') and medium gray siltstone (11484'). Silts are poor to moderately indurated and brittle to 14 EPOCH 20 ConocoPhillips Tam 2N 310 stiff in parts and display moderate cohesiveness and non adhesiveness with a sub • planar fracture and a sub platy habit. Lusters are dull to earthy with a silty texture with gradational sands decreasing with depth. E� EPOCH ' - CPAI 2N -310 North Slope, AK J 4 d i I .Y I } 1mm H EPOCH 21 Conoco Phillips Tarn 2N 310 H EPOCH CPAI • 2N -310 North Slope, AK 1 t aw 4y as • Drill Rate (ft/hr) Total Gas ( %) Maximum Minimum Average Maximum Minimum Average 150 6 25 20 5 9 (C -35) to Esker (Top) 11484' to 11646' MDRT ( -5601' to -5703' TVDSS) The C -35 to the to p p of the Esker formation is comprised of siltstone and very carbonaceous silts and clay. The carbonaceous silts are very thi bedded to bei micro laminated throughout the siltstones. Very minor sandstones are interbedded, especially towards the bottom. At 11600' a minor bed of sandstone interbedded with tuff is noted, which appears reworked and redeposited. The carbonaceous silt is brownish gray mottled pale yellowish brown to dark gray and • various hues of all. Samples are brittle to flexible with planar fracture with a micro flaky habit. Lusters are dull and greasy with a matte to silty texture. Occurs as thin to micro laminated beds of very carbonaceous silt and appears very heterogeneous. U EPOCH 22 COnocoPhillips Tam 2N 310 • The siltstones are light gray mottled with micro laminae of brownish gray to brownish black. Induration is poor to moderate with a sub planar fracture and a sub platy habit. Lusters are dull and earthy with a silty texture. Bedding occurs as a massive gradational bed of silt and very carbonaceous silt with minor sandstones with interbedded tuff. Drill Rate (ft/hr) Total Gas ( %} Maximum Minimum Average Maximum Minimum Average 67 12 37 34 7 15 Esker (Top) to Esker Base 11646' to 11707' MDRT ( -5703' to -5761' TVDSS The Esker formation is noted with a slight gas increase from 12 units to a maximum of 35 units. Samples displayed only 30% sand and sandstone, light gray to white with clast size ranging from fine upper to medium lower. A well sorted sub round to sub angular sand with moderate sphericity and grains displaying frosting and slight pitting. Porosity and permeability were poor with a 20% dull yellow patchy sample fluorescence with a trace oil cut rating very poor. The dark brownish area in some photos is a dried mud additive which was very hard to clean from the wet samples before drying them. Samples graded to a predominant siltstone once exiting the bottom of the Esker to a total depth of 11840'. H EPOCH 23 COnOCOPhillips Tam 2N 310 EA EPOCH CPAI 2N -310 North Slope, AK g ot 7mm ' Y :4 > a5 t t .f 1:1 EPOCH C PAI 2 N-31 0 t North Slope, AK y a �r T El EPOCH 24 COnoCOPhillips Tam 2N 310 • El EPOCH CPAI 2N -310 North Slope, AK f The dark brown area in the photos is a dried mud additive. Sample quality was only fair. Drill Rate (ft/hr) Total Gas ( %) Maximum Minimum Average Maximum Minimum Average 51 24 42 35 13 25 • H EPOCH 25 ConocoPhillips Tam 2N 310 • 3.3 Sampling Program / Sample Dispatch Set Type / Purpose Interval Frequency Dispatched to Wet: No wet samples collected Bayview Lab ConocoPhillips Alaska, Inc. 619 Ship Creek Ave., Ste. 100 Anchorage, AK 99501 Attn: D. Przywojski (907)- 263 -4859 1 80'— 3050' 50' 3050'— 6750' 50' Bayview Lab ConocoPhillips Alaska, Inc. Washed, screened & 6750'— 10500' 50' 619 Ship Creek Ave., Ste. 100 dried Dry Samples 10500 11610 50'+10' Anchorage, AK 99501 5 Boxes Set A 11610'— 11840' 10'+ 30' Attn: D. Przywojski (907)- 263 -4859 1 Washed, screened & 80'— 3050' 50' dried Dry Samples 3050'— 6750' 50' 5 Boxes Set B 6750'— 10500' 50' Bayview Lab ConocoPhillips Alaska, Inc. 10500'— 11610' 50'+ 10' 619 Ship Creek Ave., Ste. 100 11610'— 11840' 10'+ 30' Anchorage, AK 99501 Attn: D. Przywojski (907 )-263 -4859 • 1 Gas Bags Box "A" 80' 500' or as — 6500' 80 -6500' kicks g ISOTECH LABORATORIES 1 1308 Parkland Court Gas Bags Box "B" 6500' 6500'— 10500' 500' or gas Champaign, IL. 61821 1 - 10500 kicks 10930' — 11750' 217- 398 - 3490 /FAX 217- 398 -3493 IsoTubes One box of 30' or gas mail isotechlabs.com 25 kicks Sample frequency was locally altered according to drill rate constraints. • H EPOCH 26 ConoCoPhilliPS Tam 2N 310 • 3.4 Cali Bond Gas Bag Sample and IsoTube Inventory Gas Bag # Depth Gas Units IsoTube # Depth Gas Units 1 500 11 1 10931 77 2 1000 5 2 10940 11 3 1500 32 3 10970 10 4 2036 99 4 11000 16 5 2500 505 5 11030 11 6 3000 59 6 11060 7 7 3500 260 7 11090 11 8 3938 70 8 11120 14 9 4000 28 9 11150 79 10 4013 60 10 11180 50 11 4500 30 11 11210 66 12 5000 37 12 11240 30 13 5555 30 13 11270 17 14 6000 30 14 11300 68 15 6500 13 15 11330 120 16 7000 34 16 11360 14 17 7500 26 17 11390 11 18 8000 33 18 11420 7 19 8500 25 19 11450 6 20 9000 56 20 11480 13 • 21 9512 32 21 11510 20 22 9674 130 22 11950 8 23 10000 62 23 11590 69 24 10500 45 24 11650 17 25 11750 11 • H EPOCH 27 i ConocoPhillips Tam 2N 310 • 4. PRESSURE / FORMATION STRENGTH DATA 4.1 Formation Integrity /Leak Off Tests Equivalent mud weight (EMW) is calculated from rotary table (RT). LOT/ FIT (pp9 FORMATION MDRT (ft) TVDSS (ft) EMW) 3550' -2554' 12.8 CSG SHOE + 40'(T-7) 10860' - 5028.19 14.8 CSG SHOE + 20' LOT (Leak Off Test) in bold italics. 4.2 Pore Pressure Evaluation Introduction Trend Indicators The following pore pressure parameters are considered to provide reliable indicators • for pore pressure trends during the drilling of this well; Background Gas (BG) Connection Gas (CG) Trip Gas (TG) Hole Corrected D exponent (DXC) 1 Mud Weight (MW) Conditions (HC) Sonic (SON) Wireline Density (WDEN) Resistivity (RES) Pressure Tests (RFT) • H EPOCH 28 i COnocOPhillips Tam 2N 310 4.3 Pore Pressure Summary Equivalent mud weight (EMW) is calculated from rotary table (RT). Pore Pressure Trend Source of Formation Primary Interval Tops (EMW) Indic ators Quantitative Interval Lithology MDRT TOSS Estimate (ft) (ft) SL C80 SLTST /SS 3847' -2355' 9.7 9.8 INCR CG CG /MW C50 SLTSTISS 8010' -3800' 9.7 9.8 EVEN BG /CG BG /CG C40 SLTST 8730 -4050' 9.7 9.8 EVEN BG /CG/MW BG /CG SL C37 SLTST /SAND 9238' -4226' 9.7 9.8+ INCR CG /BG BG SL T7 SLTST 10678' -4888' 9.6 9.7 DECR BG /CG BG /CG T4 SLTST /SAND 11079' -5196' 9.6 9.7 EVEN BG /CG BG /CG (ICEBERG) SL Cairn Top SAND /SS 11098' -5211' 9.7 9.8 INCR BG BG /CG SL Cairn Bottom SS 11243' -5330' 9.6 9.7 DECR BG BG T3 Top SAND/ SS 11270' -5355' 9.7 9.8 SL BG /CG BG /CG Reservoir INCR T2 Base SL Reservoir SS /SLTST 11353' -5428 9.6 9.7 DECR BG/CG BG C -35 (K -3) SLTST 11484' -5551 9.6 9.7 EVEN BG /CG BG SL Esker (Top) SLTST /SS 11646' -5703' 9.6+ 9.7 INCR BG BG Esker SLTST 11707' -5761' 9.6+ 9.7 EVEN BG BG Bottom TD SLTST 11840' -5887' 9.6+ 9.7 EVEN BG BG /CG Refer to Section 4.3 for explanation of abbreviations used. H EPOCH 29 ConocoPh""PS Tam 2N 310 • 5. DRILLING DATA 5.1 Daily Activity Summary 8/21/07 Epoch rigged up and ready to Log at 1900 Hrs, 8/20/07 8/22/07 Pick up & make up BHA. Drill from 80' to 223'. Rack back HWDP, pick up & make up MWD tools. Upload MWD tools, pick up BHA & shallow pulse test. Drill from 223' to 341', auger packed off. POOH to 84'& clear auger. RIH to bottom, no fill. Drill from 341' to 541'. Not building correctly, POOH to re -orient tools. Wait on orders. Download MWD and L/D. M/U VBHO & orient. RIH to 500'. Wash to 541'& circulate /condition mud while waiting on orders. Drill from 541' to 563'& circulate /condition mud. 8/23/07 Drill to 653', and POOH to pick up MWD tools. Trip in and drill, rotating and sliding and building angle, from 653' to 1658' 8/24/07 Drill from 1658' to 2506', rotating and sliding, and dropping angle. Monitor well, and POOH for BHA. RIH, work through tight spot at 1468' (610 units of trip gas). Continue in hole and drill ahead, rotating and sliding to maintain angle, from 2506' to 2785'. Circulate out with pump no. 2 while work on pump no. 1. 8/25/07 Finish repair pump #1 and drill from 2785' to 3530', rotating and sliding to maintain angle. Circulate and condition hole and wiper trip to BHA. Run in hole to the bottom and circulate condition, 1752 unit trip gas. Pull 5 stands, pump dry job, POOH and lay down BHA. Begin rig up to run casing. 8/26/07 Rig up and RIH with 9 5/8" casing, circulating at 1007', 1588, 1975', 1975', and 3520', maximum gas 158 units at 3520'. Commenced cementing procedures and with completed procedures with cement to surface, and bumped the plug then rigging down cement equipment. 8/27/07 Wait on cement while picking up and racking back drill pipe in the derrick. Picked up the new BHA and surface tested the MWD. Ran into the hole with singles until above the shoe track, and cut and slipped new drill line at the shoe. H EPOCH 30 COnOC13�P1illips Tam 2N 310 8/28/07 . Circulated the mud at the casing and washed to 3378' and pressure tested the casing. Drilled out and make a swap out of the spud mud to LSND. Run a F.13 to 12.8 EMW and drilled ahead. 8/29/07 Drilled to 4888' and serviced the top drive. Drilled to 5458' and circulated the mud while replacing the valve seals in pumps #1 and #2. Drill to 6351' and circulate and condition the mud and change out the shaker screens to coarser screens to combat mud losses over the shakers. 8/30/07 Drilled to 7158' and circulated the mud while working on problems with pump #1. Monitor the well and pull out of the hole to the shoe (3520'). Monitor the well and service the top drive and repair pump #1 and test the pump circulating thirty minutes at 120 SPM. Ran into the hole to 7063' and washed to bottom and drilled ahead. Wiper Gas was 53 units. 9/01/07 Drilled and slide formation.. • 9/02/07 Drill to 10840' and pumped a high viscosity sweep. Circulated bottoms up three times and began to pull out of the hole for a wiper trip to the shoe. 9/03/07 Pull out of the hole to the shoe. Clean the rig floor and cut and slip new drill line. Service the top drive and run in the hole to 10769' and circulate the hole. Wiper gas was 1400 units. Continue to circulate the drilling mud and condition the hole for 7" casing. Begin to pull out of the hole with 5" drill pipe and lay down 5" drill pipe. 9/04/07 Continue to lay down 5" drill pipe and follow with the BHA. Download the MWD and wash out the BOPE. Change out the pipe rams to 7" and test the rams. Run 7" casing to 3484' and circulate ri late the drilling mud. Maximum gas was 27 units. Load mo re casing into the g to nun in the hole. 9/05/07 Circulate and condition the mud with 7" casing @ 3484'. Run in the hole to 4467' and circulate out 40 units. Run in the hole to 6000' and circulate out 40 units. Run in the hole to • 8035' and circulate out 30 units. Run in the hole to 9852' and circulate out 1160 units. Run in the hole to 10828' and circulate out 2613 units of trip gas. Make up cement head and pump cement to casing. Maximum gas while pumping cement was 1604 units and rigged [4 EPOCH 31 Conoco Phi ips Tam 2N 310 down cement equipment. 9/06/07 Change out upper rams to 4" and unload casing equipment from the rig. Test 4" rams and load 4" drill pipe into the rig. Pick up and make up 4" drill pipe and run in the hole to 3515' and pull out of the hole and rack back. Change out liners in mud pumps from 5.5" to 5 ". Service the top drive and start to make up the BHA. 9/07/07 Make up BHA and upload MWD and shallow test the MWD tool. Load nuke sources and run into the hole to 10556'. Wash to 10650' and circulate the drilling mud. Test casing to 3000 psi for 30 minutes. Wash to 10740' and tag plug. Drill through plug and float at 10743'. Displace the hole with new 9.6 ppg mud. Drill to 10860' ( +20' of new hole) and circulate the hole clean. Run a Leak Off Test at 14.8 ppg MWE, 9.6 ppg mud and then drill formation. 9/08/09 Drilled and slide formation for the full twenty four hours. 9/09/07 Drilled and slide formation the last twenty four hours. 9/10/07 • Drill formation to 11840' (TD) and pump a high viscosity sweep. Rotate and reciprocate the drill pipe. Circulate and condition the drilling mud and monitor the well. Well is showing a slight flow. Circulated bottoms up and circulated and condition the drilling mud and increase the mud weight to 10.0 ppg. Monitor the well and pull out of the hole to 10744' and monitor the well again. Service the rigs top drive, swivel and crown. 9/11/07 Test BOPE and run into the hole from the shoe to 11840'. Pump a high viscosity sweep at 4 bpm and circulate and condition the hol.:. Wiper gas was 259 units. Monitored the well and circulate again and lost 50 bbis of mud. Swab gas was 255 units and then a downtime gas of 115 units. Hole received back 15 bbis in 15 minutes and slowed to 1 bbl/hr. Total fluid back while monitoring was 24 bbls. Pulled out of the hole to 10366' and pumped a dry job and began to pull out of the hole with bit #3. 9/12/07 Pull out of the hole to 397' (Top of BHA) and lay down the BHA. Lay down the HWDP and remove and lay down the nuke sources. Download the MWD data and rig up and test the logging tools. Run in the hole with drill pipe and drill pipe conveyed tools and side wall cores. Run in the hole to 6125' and circulate at 4 bpm with a maximum gas of 22 units. Run in the hole to 9165' and circulate at 4 bpm with a maximum gas of 34 • units. Run in the hole to 10630' and circulate at 4 bpm with a maximum gas of 13 units. Rig up loggers and nun in the hole with the wireline and begin to run side wall H EPOCH 32 ConOCOPhillips Tam 2N 310 cores. • 9/13/07 Take sidewall cores to 11307'. Pull out of the hole to 11602' on drill pipe and pull out of the hole with wireline. Monitor the well and run in the hole with drill pipe from 10602' to 11200' and circulate bottoms up at 51 spm and monitor the well with a maximum gas was 12 units. Pumped a dry job and cut and slip new drill line and then pull out of the hole to the core assembly. Rig down and lay down the core assembly and rig up and make up core assembly #2. Rig up logging tools and test. Run in the hole with the tools and fill the drill pipe every 3000'. 9/14/07 Run in the hole to 10402' and pick up the wireline tools and run in the hole with the wireline. Pump at 20 spm and run in the hole with the wireline on drill pipe and tag at 11322'. Unable to go down as required. Pull to the surface and run in the hole from ' was 26 units t 3 b 10482 to 11113 and circulate bottoms up. Wiper gas it m. Monitor a bp m. well and pull out of the hole to 11016' and monitor the well (static). Pull out of the hole to 102' and rig down and lay down the logging tools. Clean the rig floor and pick up and make up BHA and dumb iron for a clean out run. Begin to run in the hole with 4" drill pipe and old bit #3. Mud weight brought down from 10.0 ppg to 9.5 ppg. 9/15/07 Run in the hole to 10786' and swap out casing mud volume for 9.8 ppg and circulate • at 3 bpm. Maximum gas while circulating was 34 units. Run in the hole without pumps to 11520' and wash and rotate to 11840'. Circulate and condition the mud at 40 bph. Wiper gas was 122 units. Monitor the well and pull out of the hole to 10805' and monitor the well again. Run in the hole to 11655' and circulate and run to bottom and circulate. Wiper gas was 150 units. Circulate the drilling mud and move the drill pipe. 9/16/07 Pull out of the hole from 11840' to surface (345) and cut and slip new drill line. Pick up and make up logging tools and test. Run in the hole from 102' to 10745' and fill the drill pipe. Maximum gas filling the drill pipe was 6 units. Rig up and make up SWS Entry Sub and run in the hole from 10705' to 10713' and test the tool. Run in the hole from 10713' to 11 502' with wireline. 9/17/07 Run in the hole with logging tools to 11810' and log to 10836. Run in the hole with logging tolls to 10979'. Service the rig and experience power problems with the rig top drive (replacing the traction motor on the top drive). Circulate bottoms up with a maximum gas of 109 units. 14 EPOCH 33 COnocoPhillips Tarn 2N 310 5.2 Bit Record Bit / Total Bit Av. WOB PP Run Make Type Jets Depth Footage Hrs ROP (klbs) RPM (Psi) Wear BHA In (ft) (ft/hr) 12.25" HOLE 1 1X13, 1 1 41 w/ 0-0-NO- HTC MXL -S1 3X15 80 1024 6.26 204 20 slide 1456 A- E -1 -NO TD 8.5" HOLE 2 1 -1 -CT- HTC HCM605Z 5X15 3530 7310 54.94 151 24 83 w/ 2424 G -X 2- TD slide NO -TD 6.125" HOLE 1 -1 -ER- 3 HTC HCM505Z 5X10 10840' 1000' 38.13 1 1 38 28 56 w/ 2949 N- X -1 -PN- TD slide TD • I H EPOCH 34 COnOCOPhillips Tam 2N 310 5.3 Survey Record Measured Inclination Azimuth TVD Coordinates Dog Leg Depth Feet Degrees Degrees Depth N / S E / W Degrees/ 100 ft 30.00 0.00 0.00 30.00 O.00N 0.00E 0.00 79.00 0.73 24.69 79.00 0.28N 0.13E 1.49 170.00 0.80 22.73 169.99 1.40N 0.62E 0.08 266.00 0.67 335.36 265.98 2.52N 0.64E 0.63 351.00 1.30 285.39 350.97 3.23N 0.49W 1.19 444.00 0.65 222.17 443.96 3.12N 1.87W 1.25 477.00 0.70 203.14 476.96 2.80N 2.07W 0.69 505.00 0.81 231.93 504.96 2.52N 2.29W 1.39 536.00 1.61 192.61 535.95 1.96N 2.56W 3.58 565.00 3.18 182.90 564.92 0.76N 2.69W 5.57 597.00 4.84 176.47 596.84 1.48S 2.65W 5.37 625.00 4.75 166.06 624.75 3.785 2.30W 3.12 696.00 5.32 118.83 695.50 8.22S 1.29E 5.72 740.37 6.81 105.96 739.62 9.94S 5.62E 4.53 810.00 10.23 101.37 808.48 12.29S 15.66E 5.00 878.03 12.60 93.91 875.16 13.99S 28.99E 4.10 927.72 14.81 89.86 923.43 14.35S 40.75E 4.85 973.32 16.67 85.70 967.32 13.84S 53.10E 4.77 1019.13 18.43 84.15 1011.00 12.61S 66.85E 3.97 1113.33 21.69 77.69 1099.48 7.38S 98.69E 4.18 1212.43 24.51 75.50 1190.63 1.67N 136.49E 2.97 1305.86 25.28 74.61 1275.38 11.82N 174.49E 0.92 1397.74 28.21 72.51 1357.42 23.56N 214.12E 3.35 1494.00 31.55 70.12 1440.88 38.96N 259.52E 3.68 1586.45 39.26 68.79 1516.17 57.80N 309.61 E 8.38 1678.47 42.73 67.88 1585.62 80.1ON 365.70E 3.83 1772.25 4156 67.80 1654.04 104.29N 425.09E 0.89 H EPOCH 35 ConocoPhillips Tam 2N 310 Measured Inclination Azimuth I ND Coordinates Dog Leg Feet Degrees Degrees Depth N / S E / W 1866.75 45.17 67.01 1721.60 129.68N 486.09E Degrees/ 100 ft 1961.94 50.67 66.69 1785.37 157.45N 551.02E 1.80 2059.50 54.88 65.94 1844.37 188.66N 622.14E 5.78 2154.16 59.25 65.63 1895.83 221.25N 694.58E 4.36 2247.77 64.05 64.82 1940.26 255.77N 769.35E 4.62 2341.70 68.05 63.63 1978.39 293.10N 846.63E 5.18 2435.85 69.11 63.27 2012.77 332.28N 925.03E 4.41 2526.25 68.10 63.31 2045.75 370.11 N 1000.22E 1.18 2620.39 67.18 63.07 2081.56 409.38N 1077.92E 1.12 2714.65 68.19 63.18 2117.35 448.80N 1155.70E 1.01 2808.16 68.52 63.49 2151.84 487.80N 1233.38E 1.08 2901.40 69.96 63.65 2184.89 526.61 N 1311.45E 0.47 2996.56 71.19 63.41 2216.54 566.61 N 1391.78E 1.55 3090.86 70.40 63.25 2247.56 606.58N 1471.36E 1.31 3184.84 70.09 63.27 2279.32 646.38N 1551.35E 0.85 3278.91 69.42 62.46 2311.87 686.63N 1628.89E 0.33 3372.96 70.56 63.07 2344.06 727.07N 1707.47E 1.08 3458.84 70.30 62.41 2372.82 764.13N 1799.40E 1.36 3553.53 70.43 62.80 2404.64 805.17N 1858.58E 0.78 3616.17 70.09 62.71 2425.80 832.16N 1911.00E 0.41 3710.72 70.15 62.42 2457.95 87112N 1989.91 E 0.56 3806.50 70.18 61.81 2490.45 915.26N 2069.55E 0.30 3900.07 68.54 63.87 2523.43 955.24N 2147.45E 0.60 • 3994.50 68.06 63.26 2558.35 994.29N 2226.01 E 2.70 4089.80 67.86 65.00 2594.11 1032.64N 2305.49E 0.79 4184.81 67.88 64.68 2629.90 1070.25N 2385.15E 1.71 4279.00 69.59 65.50 2664.06 1107.22N 2464.76E 0.31 4373.26 69.41 65.27 2697.08 1144.00N 2545.03E 1.99 4469.55 70.41 64.24 2730.15 1182.56N 2626.82E 0.30 4563.64 70.51 64.03 2761.69 1221.33N 2706.77E 1.44 4659.85 70.74 63.84 2793.54 1261.13N 2788.14E 0.24 4755.33 70.18 63.46 2825.47 1301.06N 2868.77E 0.30 • C4 EPOCH 36 ConocoPhillips Tam 2N 310 Measured Inclination Azimuth ND Coordinates Coordinates • Depth Feet Degrees Degrees Depth N / S E / W Degrees/ 100 ft 4847.69 69.94 63.72 2856.97 1339.68N 2946.53E 0.37 4942.31 69.84 63.25 2889.50 1379.35N 3026.03E 0.48 5038.07 69.98 62.80 2922.40 1420.14N 3106.18E 0.46 5133.88 70.08 62.54 2955.12 1461.48N 3186.18E 0.28 5228.60 70.09 61.85 2987.38 1503.03N 3264.95E 0.68 5323.32 69.21 63.94 3020.33 1543.49N 3344.00E 2.27 5417.72 69.02 63.36 3053.98 1582.64N 3423.03E 0.61 5512.74 68.84 64.90 3088.14 1621.32N 3502.81 E 1.52 5605.98 68.53 64.40 3122.03 1658.51 N 3581.31 E 0.60 5699.38 70.44 65.84 3154.77 1695.31 N 3660.66E 2.50 5794.53 70.22 65.15 3186.79 1732.47N 3742.19E 0.72 5888.72 69.83 64.43 3218.89 1770.18N 3822.31 E 0.78 5982.85 69.91 64.10 3251.21 1808.57N 3901.95E 0.33 6077.10 69.61 63.49 3262.01 1849.55N 3985.17E 0.55 6171.82 69.61 63.09 3273.10 1891 A2N 4068.40E 0.72 6267.62 69.28 62.56 3306.74 1932.38N 4148.20E 0.62 6362.50 69.79 63.42 3339.91 1972.75N 4227.40E 1.01 6457.04 68.99 63.19 3373.19 2012.50N 4306.45E 0.88 6551.07 70.45 64.53 3449.19 2047.52N 4377.93E 2.05 6645.27 70.09 64.36 3480.99 2085.77N 4457.92E 0.42 6739.06 70.27 64.13 3512.79 2124.11 N 4537.39E 0.30 6834.25 70.20 63.66 3544.98 2163.52N 4617.64E 0.47 6930.32 69.32 63.28 3577.74 2203.86N 4698.64E 0.47 • 7024.18 69.69 62.65 3610.15 2243.90N 4777.10E 0.68 7118.15 70.11 64.13 3642.44 2283.43N 4856.00E 1.55 7211.78 69.91 63.28 3674.45 2322.40N 4934.88E 0.88 7306.33 69.74 62.62 3707.06 2362.76N 5013.92E 0.68 7402.49 69.62 62.30 3740.45 2404.46N 5093.88E 0.34 7497.16 69.98 64.07 3773.14 2444.53N 5173.17E 1.80 7590.85 70.21 63.82 3805.04 2483.23N 5252.31 E 0.35 7686.09 70.05 63.51 3837.41 2522.96N 5332.58E 0.35 7779.23 69.85 63.42 3869.34 2562.05N 5410.86E 0.23 Feet Degrees Degrees Depth N / S E / W Degrees/ • H EPOCH 37 Conoco IPS Tam 2N 310 Measured Inclination Azimuth ND Coordinates Coordinates • Depth Feet Degrees Degrees Feet N/S E/W Degrees/100 ft 7872.36 69.60 63.17 3901.62 2601.31 N 5488.90E 0.37 7966.78 69.57 62.74 3934.55 2641.54N 5567.72E 0.43 8062.03 70.37 64.37 3967.18 2681.39N 5647.64E 1.81 8156.93 70.27 64.25 3999.14 2720.13N 5728.36E 0.16 8250.22 70.01 64.30 4030.83 2758.21 N 5807.41 E 0.28 8344.77 69.39 64.21 4063.63 2796.73N 588728E 0.66 8438.79 68.99 64.17 4097.03 2835.00N 5966.40E 0.43 8532.27 68.50 64.12 4130.92 2872.99N 6044.80E 0.53 8625.51 70.26 65.59 4163.76 2910.06N 6123.80E 2.40 8718.42 69.96 65.54 4195.37 2946.20N 6203.34E 0.33 8813.69 69.87 63.95 4228.09 2984.37N 6284.26E 1.57 8908.41 69.82 63.88 4260.72 3023.47N 6364.12E 0.09 9001.84 69.62 63.97 4293.11 3061.99N 6442.84E 0.23 9095.43 69.48 64.01 4325.81 3100.45N 6521.65E 0.15 9190.38 69.86 63.05 4358.80 3140.13N 6601.35E 1.03 9284.74 69.30 62.60 4391.72 3180.52N 6680.02E 0.74 9379.19 69.95 63.51 4424.60 3220.64N 6758.95E 1.14 9473.65 69.56 62.74 4457.29 3260.70N 6838.00E 0.87 9567.91 70.27 64.27 4489.66 3300.19N 6917.23E 1.70 9662.11 69.89 63.56 4521.76 3339.13N 6996.77E 0.82 9756.76 69.63 63.54 4554.50 3378.69N 7076.28E 0.28 9852.03 68.12 63.65 4588.83 3418.21 N 7155.87E 1.59 9942.56 67.84 63.12 4622.78 3455.80N 7230.91 E 0.62 10037.19 65.16 63.41 4660.51 3494.84N 7308.40E 2.85 • 10131.43 62.66 63.13 4701.95 3532.91 N 7383.99E 2.67 10225.54 59.50 61.89 4747.46 3570.91 N 7457.06E 3.55 10319.06 55.36 62.63 4797.79 3607.60N 7526.79E 4.48 10412.44 50.82 63.08 4853.85 3641.66N 7593.21 E 4.88 10506.95 47.25 62.89 4915.81 3674.07N 7656.78E 3.78 10601.25 44.64 62.55 4981.37 3705.12N 7717.01E 2.78 10695.73 41.83 63.33 5050.20 3734.57N 7774.63E 3.03 10789.42 38.66 64.89 5121.70 3761.02N 7829.06E 3.55 10798.89 38.70 64.91 5129.10 3763.53N 7834.42E 0.44 10835.20 38.47 65.30 5157.48 3773.07N 7854.96E 0.92 10931.30 40.51 65.10 5231.64 3798.70N 7910.44E 2.13 11024.09 39.53 64.63 5302.70 3824.04N 7964.46E 1.11 11121.24 36.11 66.60 5379.43 3848.67N 8018.68E 3.73 11214.64 31.84 68.97 5656.87 3868.45N 8066.96E 4.79 11308.72 27.72 70.53 5538.51 3884.65N 8110.77E 4.46 11372.69 23.26 69.85 5596.24 3893.97N 8136.67E 6.99 11403.85 20.73 68.78 5625.13 3898.08N 8147.59E 8.22 11499.23 18.59 69.39 5714.95 3909.55N 8177.56E 2.25 11594.32 20.11 65.12 5804.75 3921.82N 8206.36E 2.18 11689.29 19.73 65.67 5894.04 3935.29N 8235.78E 0.45 11744.19 19.28 65.81 5945.79 3942.82N 8252.49E 0.82 11840.00 19.28 65.81 6036.22 3955.78N 8281.35E 0.00 Feet Degrees Degrees Depth N / S E / W Degrees/ 100 ft H EPOCH 38 COnOcOPhillips Tam 2N 310 • 5.4 Mud Record M4 Drilling Spud Mud to 3520' LSND TO Contractor: Fluids Mud Type: Mud Type: 11840' Date Depth MW Vis PV YP Gels API Oil/Water Sand PH Cl Ca FL Solids 8/21/07 563 9.6 250 31 58 45/51/58 9.3 8/22107 1658 10.0 200 14 62 40/55/72 6 9 1/90 0.75 9.3 1000 120 8/23107 2785 10.1 165 29 61 28/52/63 5 10 1/89 1.5 9.8 800 80 8/24/07 3530 10.0 158 33 59 25/47/55 5 12 1/87 0.75 9.7 800 60 8/25/07 3530 10.1 158 28 64 25/47/55 5 14 TR/86 1 9.5 800 80 8/26/07 3530 9.6 54 19 20 5/8/9 6 8 TR /92 TR 9.0 540 80 8/27/07 3530 9.6 54 19 20 5/8/9 6 8 TR/92 TR 9.0 540 80 8/28/07 4730 9.7 44 12 24 8/11/16 6.8 7 /93 TR 9.0 320 20 8/29/07 6350 9.6 42 10 22 6/9/13 5.8 7 TR /93 TR 9.8 300 40 8/30/07 7612 9.7 43 16 22 10/18/24 4.6 8 TR/92 0.25 9.0 350 60 8/31/07 9550 9.6 44 17 20 8/18/19 5.8 10 /90 TR 8.8 300 40 9/1/07 10840 9.6 42 13 15 7/10/14 4.8 11 1/88 TR 9.2 325 40 9/2/07 10840 9.6 54 15 22 8/19/22 3.6 9 1/90 TR 9.2 300 40 9/3/07 10840 9.6 58 16 21 9/13/15 3.6 9 TR/91 TR 8.8 275 60 9/4/07 10840 9.6 42 8 14 4/5/6 4.8 9 TR/91 TR 8.7 250 60 • 9/5/07 10840 9.6 41 8 13 415!7 5 9 TR /91 TR 8.6 250 60 9/6/07 10840 9.6 170 34 20 4/6/6 4.8 7 /93 0 9.5 350 80 9/7/07 11170 9.6 62 23 21 5/5!7 5 9 1/90 TR 9.9 500 40 9/8/07 11525 9.6 66 23 18 5/5/6 4.8 10 3/87 TR 9.5 400 60 9/9/07 11840 10.0 66 27 20 5/6/6 4.2 8.5 3/89 TR 9.6 400 40 9/10/07 11840 10.0 70 28 20 5/7/8 4.2 8.5 3/89 TR 9.8 500 60 9/11/07 11840 10.0 69 25 21 5/6/7 4 8.5 3/89 TR 9.9 400 80 9/12107 11840 10.0 70 24 22 5./6/7 2 8.5 3/89 TR 9.9 500 80 9/13/07 11840 9.5 50 15 12 314/5 4 7.5 3/90 TR 10.3 400 80 9/14/07 11840 9.9 60 17 26 7/8/9 4.2 8 3/89 TR 9.9 400 80 9/15/07 11840 9.9 62 16 24 7/8/10 4 7 3/90 TR 9.7 400 80 9/16/07 11840 9.9 58 17 23 7/8/9 4 7 3/90 TR 9.7 400 80 • H EPOCH 39 Daily Report Page 1 of 1 CONOCOPHILLIPS DAILY WELLSITE REPORT _,_�k_;H 2N310 REPORT FOR BREEDENNAAGEN DATE Aug 20, 2007 DEPTH 80 PRESENT OPERATION PREPARING TO SPUD TIME 24:00 YESTERDAY 80 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @80' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 0 @ 0.0 FT /HR SURFACE TORQUE 0 @ 0 @ 0.0 AMPS WEIGHT ON BIT 0 @ 0 @ 0.0 KLBS ROTARY RPM 0 @ 0 @ 0.0 RPM PUMP PRESSURE 0 @ 0 @ 0.0 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 @ 0.0 TRIP GAS CUTTING GAS 0 @ 0 @ 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C -1) 0 @ 0 @ 0.0 CONNECTION GAS HIGH ETHANE (C -2) 0 @ 0 @ 0.0 AVG PROPANE (C -3) 0 @ 0 @ 0.0 CURRENT BUTANE (C -4) 0 @ 0 @ 0.0 CURRENT BACKGROUND /AVG PENTANE (C -5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Epoch rigged up and ready to oog at 1900 Hrs, 8/20/07 EPOCH PERSONNEL ON BOARD 3 DAILY COST 5585 REPORT BY John Lundy • file : / /C:\ Documents% 20and% 20Settings\ RigUser \My %20Documents \My %20Wells \CON... 8/21/2007 I Daily Report Pagel of 2 CONOCOPHILLIPS DAILY WELLSITE REPORT EI'QH 2N310 REPORT FOR BREEDEN, VAAUGEN, MORRISS DATE Aug 21, 2007 DEPTH 563 PRESENT OPERATION WAITING ON ORDERS TIME 23:46:26 YESTERDAY 80 24 HOUR FOOTAGE 483 CASING INFORMATION 16" @ 80' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA Inconclusive BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 12.25 HTC- MXL -S1 5091504 1= 13.3 =15 80 481 2.85 STILL IN DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 2229.1 @ 81 38.1 @ 181 321.6 459.59402 FT /HR SURFACE TORQUE 2 @ 199 0 @ 258 1.0 0.28063 AMPS WEIGHT ON BIT 21 @ 88 -11 @ 236 3.8 2.24300 KLBS ROTARY RPM 51 @ 443 1 @ 376 29.0 0.00000 RPM PUMP PRESSURE 2562 @ 368 49 @ 221 1285.1 2377.27271 PSI DRILLING MUD REPORT DEPTH 563' MD /TVD =? • MW 9.6 VIS 286 PV 31 YP 58 FL Gels 45/51158 CL- FC SOL SD OIL MBL 25 pH 9.3 Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 16 @ 484.00000 0 @ 117.00000 3.1 TRIP GAS CUTTING GAS 0 @ 561.00000 0 @ 561.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C -1) 1823 @ 484.00000 59 @ 406.00000 316.4 CONNECTION GAS HIGH ETHANE (C -2) 19 @ 396.00000 0 @ 266.00000 3.9 AVG PROPANE (C -3) 0 @ 561.00000 0 @ 561.00000 0.0 CURRENT BUTANE (C -4) 0 @ 561.00000 0 @ 561.00000 0.0 CURRENT BACKGROUND /AVG 2 PENTANE (C -5) 0 @ 561.00000 0 @ 561.00000 0.0 HYDROCARBON SHOWS NONE INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY Interbedded sand /sandstone, conclomeratic sand, pebble conglomerate and claystone with thin lignitic intervals. PRESENT LITHOLOGY 70% conglomeratic sand, 10% snad, 20% claystone. Pick up & make up BHA. Drill from 80' to 223'. Rack back HWDP, pick up & make up MWD tools. Upload MWD tools, DAILY pick up BHA & shallow pulse test. Drill from 223' to 341', auger packed off. POOH to 84'& clear auger. RIH to bottom, ACTIVITY no fill. Drill from 341' to 541'. Not building correctly, POOH to re- orient tools. Wait on orders. Download MWD and L /D. SUMMARY M/U VBHO & orient. RIH to 500'. Wash to 541'& circulate /condition mud while waiting on orders. Drill from 541' to 563' & circulate /condition mud. file: / /C:\ Documents %20and %20 S ettings \RigUser \My %20Documents \My %20 Wells \CON... 8/22/2007 Daily Report Page 2 of 2 EPOCH PERSONNEL ON BOARD 3 DAILY COST 3335.00 • REPORT BY John Lundy file://C:\ Documents %20and %20 Settings \RigUser \My %20Documents \My %20 W ells \CON... 8/22/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS Tarn Field DAILY WELLSITE REPORT L4 E �0�;�1 2N310 REPORT FOR Breeden, Vaagen, Morris DATE Aug 22, 2007 DEPTH 1658.00000 PRESENT OPERATION Drilling TIME 23:59 YESTERDAY 563.00000 24 HOUR FOOTAGE 1095 CASING INFORMATION 16" @ 80' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 565.00 3.18 182.90 564.92 SURVEY DATA 740.37 6.81 105.96 739.62 927.72 14.81 89.86 923,43 1212.43 24.51 75.50 1190.63 1586.45 39.26 68.79 1516.17 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 12.25 HTC- MXL -S1 5091504 1X13,3X15 80 1578 10.42 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 3324.1 @ 1047.00000 3.5 @ 1504.00000 214.7 189.59343 FT /HR SURFACE TORQUE 5 @ 1632.00000 0 @ 1484.00000 1.3 3.51931 AMPS WEIGHT ON BIT 51 @ 1310.00000 -16 @ 585.00000 21.9 12.85925 KLBS ROTARY RPM 69 @ 1449.00000 1 @ 1306.00000 21.1 62.00000 RPM PUMP PRESSURE 3422 @ 1250.00000 971 @ 672.00000 2282.6 1097.72473 PSI DRILLING MUD REPORT DEPTH 1565 MW 10.0 VIS 200 PV 14 YP 62 FL 6.0 Gels 40/55/72 CL- 1000 FC 2/ SOL 9.0 SD 0.75 OIL 1/90 MBL 25 pH 9.3 Ca+ 120 CCI MWD SUMMARY INTERVAL 653 TO Present TOOLS Bit #1 and Mud Motor; MWD (Surveys) GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 3942 @ 1257.00000 0 @ 907.00000 210.8 TRIP GAS CUTTING GAS 0 @ 1655.00000 0 @ 1655.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C -1) 367131 @ 1255.00000 35 @ 793.00000 12261.1 CONNECTION GAS HIGH ETHANE (C -2) 0 @ 1655.00000 0 @ 1655.00000 0.0 AVG 0 PROPANE (C -3) 0 @ 1655.00000 0 @ 1655.00000 0.0 CURRENT BUTANE (C -4) 0 @ 1655.00000 0 @ 1655.00000 0.0 CURRENT BACKGROUND /AVG 35u/33u PENTANE (C -5) 0 @ 1655.00000 0 @ 1655.00000 0.0 HYDROCARBON SHOWS Some methane hydrates INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 20% Conglomeratic Sand, 40% Sand, 30% Claystone, 10% Siltstone PRESENT LITHOLOGY 40% Sand, 40% Claystone, 20% Siltstone DAILY ACTIVITY Drill to 653', and POOH to pick up MWD tools. Trip in and drill, rotating and sliding and building angle, SUMMARY from 653' to 1658' EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 • REPORT BY Brian O'Fallon file: / /C: \Documents %20and %20 Settings \RigUser \My %20Documents\My %20 W ells \CON... 8/23/2007 Daily Report Page 1 of 2 CONOCOPHILLIPS Tarn Field DAILY WELLSITE REPORT U4 �,lQ�H 2N310 REPORT FOR Breeden, Vaagen, Morris DATE Aug 23, 2007 DEPTH 2785.00000 PRESENT OPERATION Work on Pump No. 1 TIME 23:59 YESTERDAY 1658.00000 24 HOUR FOOTAGE 1127 CASING INFORMATION 16" @ 80' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1678.47 42.73 67.86 1585.62 SURVEY DATA 1866.75 45.17 67.01 1721.60 2059.50 54.88 65.94 1844.37 2341.70 68.05 63.63 1978.39 2620.39 67.18 63.09 2081.56 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 12.25 HTC - MXL -S1 5091504 1X13,3X15 80 2506 2426 16.06 0- 0- NO- A- E -1 -NO BHA 1RR1 12.25 HTC - MXL -51 5091504 1X13,3X15 2506 279 1.66 In Hole DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 359.5 @ 2153.00000 40.3 @ 2318.00000 165.5 149.06215 FT /HR SURFACE TORQUE 7 @ 2456.00000 0 @ 1950.00000 3.8 6.60299 AMPS WEIGHT ON BIT 42 @ 2135.00000 0 @ 1658.00000 23.2 19.91406 KLBS ROTARY RPM 82 @ 2536.00000 1 @ 2054.00000 46.7 80.00000 RPM PUMP PRESSURE 2359 @ 2527.00000 196 @ 2200.00000 851.7 1881.11487 PSI DRILLING MUD REPORT DEPTH 2620 MW 10.1 VIS 165 PV 29 YP 61 FL 5.0 Gels 28/52/63 CL- 800 FC 2/ SOL 10 SD 1.5 OIL 1/89 MBL 27 pH 9.8 Ca+ 80 CCI MWD SUMMARY INTERVAL 2510 TO Current TOOLS Bit #1rr and Mud Motor, MWD (Surveys) GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 534 @ 2494.00000 2 @ 2006.00000 100.7 TRIP GAS 610u CUTTING GAS 0 @ 2785.00000 0 @ 2785.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 234383 @ 2058.00000 291 @ 2006.00000 18418.8 CONNECTION GAS HIGH ETHANE (C -2) 0 @ 2785.00000 0 @ 2785.00000 0.0 AVG 0 PROPANE (C -3) 0 @ 2785.00000 0 @ 2785.00000 0.0 CURRENT BUTANE (C -4) 0 @ 2785.00000 0 @ 2785.00000 0.0 CURRENT BACKGROUND /AVG 49u/80u PENTANE (C -5) 0 @ 2785.00000 0 @ 2785.00000 0.0 HYDROCARBON SHOWS Hydrates INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 40% Sand, 40% Claystone, 40% Siltstone PRESENT LITHOLOGY 40% Sand, 40% Claystone, 40% Siltstone DAILY ACTIVITY Drill from 1658' to 2506', rotating and sliding, dropping angle. Monitor well, and POOH for BHA. RIH, work through SUMMARY tight spot at 1468', 610 units of trip gas. Continue in hole and drill ahead, rotating and sliding to maintain angle, from 2506' to 2785'. Circulate out with pump no. 2 while work on pump no. 1. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 file: / /C:\ Documents% 20and% 20Settings \RigUser \My %20Documents \My %20 W ells \CON... 8/24/2007 Daily Report Page 2 of 2 REPORT BY Brian O'Fallon file: / /C:\ Documents% 20and% 20Settings\ RigUser \My %20Documents \My %20Wells \CON... 8/24/2007 Daily Report Page 1 of 2 CONOCOPHILLIPS Tarn Field DAILY WELLSITE REPORT U4 E �O ""T-T 2N310 REPORT FOR Breeden, Vaagen, Morris DATE Aug 24, 2007 DEPTH 3530.00000 PRESENT OPERATION Begin rig up for casing run TIME 23:59 YESTERDAY 2785.00000 24 HOUR FOOTAGE 745 CASING INFORMATION 16" @ 80' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2808.16 68.52 63.49 2151.64 2996.56 71.19 63.41 2216.54 SURVEY DATA 3184.84 70.09 63.27 2279.32 3372.96 70.56 63.07 2344.06 3458.84 70.30 62.41 2372.82 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1RR1 12.25 HTC- XML -S1 5091504 1X13,3X15 2506 3530 1024 6.26 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 307.4 @ 2788.00000 26.2 @ 2971.00000 171.9 124.21500 FT /HR SURFACE TORQUE 8 @ 3437.00000 0 @ 2978.00000 5.8 7.18000 AMPS WEIGHT ON BIT 37 @ 3143.00000 3 @ 3161.00000 23.1 19.90500 KLBS ROTARY RPM 85 @ 2972.00000 2 @ 2790.00000 69.8 79.00000 RPM PUMP PRESSURE 1881 @ 2785.00000 685 @ 2971.00000 1289.6 1061.29400 PSI DRILLING MUD REPORT DEPTH 3530 MW 10.0 VIS 158 PV 33 YP 59 FL 5.0 Gels 25/47/55 CL- 800 FC 2/ SOL 12 SD 0.75 OIL 1/87 MBL 25 pH 9.7 Ca+ 60 CC[ MWD SUMMARY INTERVAL 2506 TO 3530 TOOLS Bit #1rr and Mud Motor, MWD (Surveys) GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 590 @ 3428.00000 19 @ 294100000 162.7 TRIP GAS CUTTING GAS 0 @ 3530.00000 0 @ 3530.00000 0.0 WIPER GAS 1752u CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 93878 @ 3428.00000 3839 @ 2943.00000 29289.4 CONNECTION GAS HIGH ETHANE (C -2) 55 @ 3106.00000 0 @ 2786.00000 121 AVG 0 PROPANE (C -3) 7 @ 3106.00000 0 @ 3415.00000 0.5 CURRENT BUTANE (C -4) 0 @ 3530.00000 0 @ 3530.00000 0.0 CURRENT BACKGROUND /AVG 350u/160u PENTANE (C -5) 0 @ 3530.00000 0 @ 3530.00000 0.0 HYDROCARBON SHOWS None INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 50% Sand, 20% Siltstone, 30% Claystone PRESENT LITHOLOGY 70% Sand, 20% Siltstone, 10% Claystone DAILY ACTIVITY Finish repair pump #1 and drill from 2785' to 3530', rotating and sliding to maintain angle. Circulate and condition SUMMARY hole and wiper trip to BHA. Run in hole to the bottom and circulate condition, 1752 unit trip gas. Pull 5 stands, pump dry job, POOH and lay down BHA. Begin rig up to run casing. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY Brian 0 Fallon file: / /C:\ Documents% 20and% 20Settings\ RigUser \My %20Documents \My %2OWells \CON... 8/25/2007 Daily Report Page 2 of 2 i file: / /C:\ Documents% 20and% 20Settings\ RigUser \My %20Documents \My %20Wells \CON... 8/25/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS Tarn Field DAILY WELLSITE REPORT H EPO T-T 2N310 REPORT FOR Breeden, Vaagen, Morris DATE Aug 25, 2007 DEPTH 3530.00000 PRESENT OPERATION Finish Cement Casing TIME 23:59 YESTERDAY 3530.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 80'9 5/8" @ DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3458.84 70.30 62.41 2372.82 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3530 MW 10.0 VIS 56 PV 21 YP 22 FL 5.6 Gels 8/22/28 CL- 800 FC 2/ SOL 12 SD 0.75 OIL tr /88 MBL 25 pH 9.4 Ca+ 100 CC[ MWD SUMMARY INTERVAL TO TOOLS N/A GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 158u CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG - /30u PENTANE (C -5) @ @ HYDROCARBON SHOWS No Drilling Past 24 hours INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLO GY No Drilling Past 24 hours PRESENT LITHOLOGY DAILY ACTIVITY Rig up and RIH with 9 5/8" casing., circulating at 1007', 1588', 1975', 1975', and 3520', maximum gas 158 units at SUMMARY 3520'. Commenced cementing procedures. Completed procedures with cement to surface, and bumped plug. Rigging down cement equipment. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY Brian O'Fallon file: / /C:\ Documents% 20and% 20Settings\ RigUser \My %20Documents \My %2OWells \CON... 8/26/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS Tarn Field DAILY WELLSITE REPORT El _L_r� 2N310 REPORT FOR Breeden, Vaagen, Morris DATE Aug 26, 2007 DEPTH 3530.00000 PRESENT OPERATION P/U Drill Pipe TIME 23:59 YESTERDAY 3530.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 80' 9 518" @ 3520' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3458.84 70.30 62.41 2372.82 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3530 MW 9.6 VIS 54 PV 19 YP 20 FL 6.0 Gels 5/8/9 CL- 540 FC 1/ SOL 8.0 SD tr OIL tr /92 MBL 16 pH 9.0 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS N/A GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG N/A PENTANE (C -5) @ @ HYDROCARBON SHOWS No Drilling Past 24 hours INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY No Drilling Past 24 hours PRESENT LITHOLOGY DAILY ACTIVITY Finish rigging down after cement job, and flush stack. Nipple down diverter, while fix pump in mixing pit and SUMMARY clean pits, shakers, and rock washer. Nipple up and test BOPE. Picking up and racking back drill pipe. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY Brian O'Fallon file: / /C:\ Documents %20and %20 S ettings \RigUser \My %20Documents \My %20W ells \CON... 8/27/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS Tarn Field DAILY WELLSITE REPORT L4 h-+ r��xa 2N310 REPORT FOR Breeden, Vaagen, Morris DATE Aug 27, 2007 DEPTH 3530.00000 PRESENT OPERATION Fnish slip and cut drill line. TIME 23:59 YESTERDAY 3530.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 80' 9 5/8" @ 3520' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3458.84 70.30 62.41 2372.82 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 8.750 Hughes HCM605Z 7107627 5x15 3530 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3530 MW 9.6 VIS 54 PV 19 YP 20 FL 6.0 Gels 5/8/9 CL- 540 FC 1 /NA SOL 8.0 SD tr OIL tr /92 MBL 16 pH 9.0 Ca+ 80 CCI MWD SUMMARY INTERVAL 3530 TO Current TOOLS NB #2 and mud motor. MWD (Surveys) and LWD (Gamma, Resistivity, ECD). GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG N/A PENTANE (C -5) @ @ HYDROCARBON SHOWS No Drilling Past 24 hours INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY No Drilling Past 24 hours PRESENT LITHOLOGY DAILY ACTIVITY Continue picking up and racking back drill pipe. Pick up BHA and surface test MWD. RIH with singles untill SUMMARY above shoe track. Slip and cut drill line. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY Brian O'Fallon file: //C:\Documents%20and%20 S ettings\RigUser\My%20Documents\My%2OWells\CON... 8/28/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT Lj h� 2N -310 REPORT FOR MORRIS /HEIM DATE Aug 29, 2007 DEPTH 4765.00000 PRESENT OPERATION DRILLING TIME 00:00:50 YESTERDAY 3530.00000 24 HOUR FOOTAGE 1235' CASING INFORMATION 9.625" @ 3520' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4659.85 70.74 63.84 2793.54 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 8.75" HTC HCM605Z 7107627 5X15 3530 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 329.0 @ 3546.00000 18.6 @ 4161.00000 166.6 141.42604 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 48 @ 3871.00000 5 @ 4701.00000 16.4 8.44353 KLBS ROTARY RPM 103 @ 3812.00000 3 @ 4433.00000 87.6 97.00000 RPM PUMP PRESSURE 2654 @ 3995.00000 613 @ 3536.00000 2103.0 1253.09692 PSI DRILLING MUD REPORT DEPTH 4730' MW 9.7 VIS 44 PV 12 YP 24 FL 6.8 Gels 8/11/16 CL- 320 FC 1 1NA SOL 7 SD TR OIL 0 MBL 5 pH 9.0 Ca+ 20 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 471 @ 3530.00000 4 @ 3561.00000 34.5 TRIP GAS 0 @ 3520' CUTTING GAS 0 @ 4765.00000 0 @ 4765.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 71547 @ 3530.00000 753 @ 3561.00000 5229.1 CONNECTION GAS HIGH 70 @ 5362' ETHANE (C -2) 314 @ 3530.00000 3 @ 3561.00000 28.6 AVG 20 PROPANE (C -3) 0 @ 4765.00000 0 @ 4765.00000 0.0 CURRENT 15 BUTANE (C -4) 0 @ 4765.00000 0 @ 4765.00000 0.0 CURRENT BACKGROUND /AVG 22 PENTANE (C -5) 0 @ 4765.00000 0 @ 4765.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HRS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SILTSTONE, SANDSTONE, SAND, CLAYSTONE, DEVITTUFF PRESENT LITHOLOGY 4765'= 60% SILT, 30% CLAY, 10% SANDSTONE DAILY ACTIVITY RUN IN THE HOLE AND CIRCULATED MUD IN THE CASING, WASHED TO 3378', PRESSURE TEST SUMMARY CASING, DRILL OUT AND SWAP MUD OVER TO LSND, FIT TO 12.8 EMW AND DRILL AHEAD EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. O file: / /C:\ Documents %20and %20 S ettings\ RigUser\ My %20Documents \My %2OWells \Cono... 8/29/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT H EPOCH 2N -310 REPORT FOR MORRIS /HEIM DATE Aug 29, 2007 DEPTH 6365.00000 PRESENT OPERATION DRILLING TIME 12:01 AM YESTERDAY 4765.00000 24 HOUR FOOTAGE 1600' CASING INFORMATION 9.625" @ 3520' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6267.62' 69.28 62.56 3306.74' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 8.75" HTC HCM605Z 7107627 5X15 3530 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 319.1 @ 5181.00000 2.3 @ 6356.00000 164.6 22.43830 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 60 @ 6315.00000 5 @ 6227.00000 20.1 13.06826 KLBS ROTARY RPM 106 @ 4869.00000 1 @ SLIDE 89.3 85.00000 RPM PUMP PRESSURE 5545 @ 5959.00000 833 @ 5371.00000 3345.5 2719.07324 PSI DRILLING MUD REPORT DEPTH 6350' MW 9.6 VIS 42 PV 10 YP 22 FL 5.8 Gels 6/9/13 CL- 300 FC 1 /NA SOL 7 SD TR OIL TR MBL 12 pH 9.8 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 78 @ 5088.00000 5 @ 6355.00000 32.8 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C -1) 13791 @ 5088.00000 978 @ 6365.00000 5587.7 CONNECTION GAS HIGH 40 ETHANE (C -2) 131 @ 5088.00000 6 @ 6365.00000 41.0 AVG 15 PROPANE (C -3) 16 @ 5416.00000 0 @ 5114.00000 4.3 CURRENT 10 BUTANE (C -4) 0 @ 6365.00000 0 @ 6365.00000 0.0 CURRENT BACKGROUNDIAVG 25 PENTANE (C -5) 0 @ 6365.00000 0 @ 6365.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SANDSTONE, SILTSTONE PRESENT LITHOLOGY 6350'= 30% SILTSTONE, 10% SAND, 60% SANDSTONE DAILY ACTIVITY DRILL TO 4888' SERVICE THE TOP DRIVE, DRILL TO 5458' AND CIRCULATE AND REPLACE VALVE SEALS SUMMARY IN PUMPS #1 + 2, DRILL TO 6351' AND CIRCULATE AND CONDITION THE MUD AND CHANGE OUT SHAKER SCREENS, CHANGED TO COARSER SCREENS TO COMBAT LOSSES OVER THE SHAKERS. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file: / /C:\ Documents% 20and% 20Settings \RigUser \My %20Documents \My %20 W ells \Cono... 8/30/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT by v - 11 2N -310 REPORT FOR MORRIS /HEIM DATE Aug 31, 2007 DEPTH 7693.00000 PRESENT OPERATION DRILLING TIME 00:00:12 YESTERDAY 6365.00000 24 HOUR FOOTAGE 1328' CASING INFORMATION 9.625" @ 3520' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7686.09' 70.50 63.51 3837.41' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 8.75" HTC HCM605Z 7107627 5X15 3530' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 266.8 @ 6407.00000 11.4 @ 6402.00000 159.0 191.41809 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 106 @ 7443.00000 11 @ 6371.00000 33.5 37.44410 KLBS ROTARY RPM 102 @ 7248.00000 1 @ SLIDE 89.3 94.00000 RPM PUMP PRESSURE 3652 @ 7191.00000 1463 @ 6954.00000 2235.1 1607.74304 PSI DRILLING MUD REPORT DEPTH 7612' MW 9.7 VIS 43 PV 16 YP 22 FL 4.6 Gels 10/18/24 CL- 350 FC 1 /NA SOL 8 SD 0.25 OIL TR MBL 14 pH 9.0 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 51 @ 7577.00000 2 @ 7172.00000 24.8 TRIP GAS CUTTING GAS @ @ WIPER GAS 52 @ 7158' CHROMATOGRAPHY(ppm) SURVEY METHANE (C -1) 9941 @ 7577.00000 490 @ 6384.00000 4551.3 CONNECTION GAS HIGH 45 ETHANE (C -2) 98 @ 7208.00000 2 @ 6394.00000 37.9 AVG 15 PROPANE (C -3) 22 @ 7544.00000 0 @ 6749.00000 3.9 CURRENT 15 BUTANE (C -4) 0 @ 7693.00000 0 @ 7693.00000 0.0 CURRENT BACKGROUND /AVG 39 PENTANE (C -5) 0 @ 7693.00000 0 @ 7693.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SAND, SANDSTONE, SILTSTONE PRESENT LITHOLOGY 7650'= 90% SANDSTONE, 10% SILTSTONE DAILY DRILL TO 7158', CIRCULATE THE HOLE, PROBLEMS WITH PUMP #1, MONITOR THE WELL, PULL OUT OF ACTIVITY THE HOLE TO 3520' (SHOE), MONITOR THE WELL, SERVICE THE TOP DRIVE, REPAIR PUMP #1 AND TEST SUMMARY PUMP, CIRCULATE 1/2 HOUR @ 120 SPM, RUN IN THE HOLE TO 7063' AND WASH TO BOTTOM, DRILL AHEAD, WIPER GAS = 53 UNITS. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file: / /C:\ Documents% 20and% 20Settings\ RigUser\ My %20Documents \My %2OWells \Cono... 8/31/2007 Daily Report Page 1 of I CONOCOPHILLIPS TARN DAILY WELLSITE REPORT hr k- 2N -310 REPORT FOR MORRIS /HEIM DATE Sep 01, 2007 DEPTH 9678.00000 PRESENT OPERATION DRILLING TIME 00:00:48 YESTERDAY 7693.00000 24 HOUR FOOTAGE 1985' CASING INFORMATION 9.625" @ 3520' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9662.11' 69.89 63.56 4521.76 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 8.75" HTC HCM605Z 7107627 5X15 3530' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION 264.5 @ 9323.00000 27.5 @ 9326.00000 143.5 139.60522 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 94 @ 9348.00000 4 @ 8204.00000 24.5 35.44566 KLBS ROTARY RPM 100 @ 8801.00000 1 @ SLIDE 86.1 94.00000 RPM PUMP PRESSURE 3240 @ 8859.00000 592 @ 7909.00000 2163.9 2643.61255 PSI DRILLING MUD REPORT DEPTH 9550' MW 9.6 VIS 44 PV 17 YP 20 FL 5.8 Gels 8/18/19 CL- 300 FC 11 SOL 10 SD TR OIL 0 MBL 16 pH 8.8 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 217 @ 9668.00000 2 @ 7758.00000 45.6 TRIP GAS CUTTING GAS 0 @ 9678.00000 0 @ 9678.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C -1) 38758 @ 9668.00000 396 @ 7758.00000 8200.4 CONNECTION GAS HIGH 120 ETHANE (C -2) 741 @ 9668.00000 3 @ 7758.00000 107.8 AVG 25 PROPANE (C -3) 167 @ 9668.00000 0 @ 7875.00000 24.3 CURRENT 25 BUTANE (C -4) 76 @ 9668.00000 0 @ 8331.00000 8.3 CURRENT BACKGROUND /AVG 41 PENTANE (C -5) 0 @ 9678.00000 0 @ 9678.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS OF DRILLING INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SAND, SANDSTONE, SILTSTONE, CARBONACEOUS SILT AND SHALE PRESENT LITHOLOGY 9650'= 90% SILTSTONE, 10% CARBON SILT AND SHALE DAILY ACTIVITY SUMMARY DRILLING FORMATION EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file: / /C:\ Documents% 20 and% 20 Settings\ RigUser\ My% 20Documents \My %20Wells \Conoc... 9/1/2007 Daily Report Page 1 of 1 • CONOCOPHILLIPS TARN DAILY WELLSITE REPORT H EPOC-11 2N -310 REPORT FOR MORRIS /HEIM DATE Sep 02, 2007 DEPTH 10840.00000 PRESENT OPERATION WIPER TRIP TO SHOE TIME 12:01 AM YESTERDAY 9678.00000 24 HOUR FOOTAGE 1162' CASING INFORMATION 9.625" @ 3520' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 10840' 5161.09' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 8.75" HTC HCM605Z 7107627 5X15 3530 10840 7310 54.94 N/A TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 319.0 @ 9796.00000 17.1 @ 9926.00000 122.1 110.32800 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 102 @ 9818.00000 3 @ 10186.00000 24.4 13.55600 KLBS ROTARY RPM 102 @ 10800.00000 1 @ SLIDE 55.1 97.00000 RPM PUMP PRESSURE 2664 @ 9700.00000 1648 @ 10839.00000 2134.9 1655.76400 PSI DRILLING MUD REPORT DEPTH 10840' MW 9.6 VIS 42 PV 13 YP 15 FL 4.8 Gels 7/10/14 CL- 325 FC 1/ SOL 11 SD tr OIL 1% MBL 25 pH 9.2 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 676 @ 9697.00000 5 @ 10768.00000 50.3 TRIP GAS CUTTING GAS 0 @ 10840.00000 0 @ 10840.00000 0.0 WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C -1) 119736 @ 9697.00000 928 @ 10768.00000 8666.3 CONNECTION GAS HIGH 65 ETHANE (C -2) 2033 @ 9697.00000 36 @ 10768.00000 206.0 AVG 10 PROPANE (C -3) 468 @ 9697.00000 0 @ 10451.00000 43.8 CURRENT 45 BUTANE (C -4) 160 @ 9697.00000 0 @ 10451.00000 18.2 CURRENT BACKGROUND /AVG 0 (POOH) PENTANE (C -5) 10 @ 9798.00000 0 @ 10121.00000 0.2 HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION 9690 TO 9700' 80% SAND 20% SILT BEFORE 70 MAX SAND = UNCONS, VLTGY, MED UPR -FINE LWR,QTZ RICH, 676 AFTER 100 SL ORANGE SMPLE FLOR (MINERAL) NO CUTS LITHOLOGY SAND, SANDSTONE, SILTSTONE PRESENT LITHOLOGY 10840'= 70% SILT, 20% SANDSTONE, 10% SAND DAILY ACTIVITY DRILL FORMATION TO 10840', CIRCULATE BOTTOMS UP THREE TIMES AND BEGIN TO PULL OUT SUMMARY OF THE HOLE TO THE SHOE (WIPER TRIP). EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file://C:\ Documents %20and %20 S ettings \RigUser \My %20Documents \My %20W ells \Conoc... 9/2/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT U4 "+�0,11-'T-T 2N -310 REPORT FOR MORRIS /HEIM DATE Sep 03, 2007 DEPTH 10840.00000 PRESENT OPERATION LAY DOWN 5" DRILL PIPE TIME 12:01 AM YESTERDAY 10840.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625" @ 3520' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 10840' 5161.09' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 8.75" HTC HCM605Z 7107627 5X15 3530' 10840' 7310' 54.94 N/A TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10640 MW 9.6 VIS 54 PV 15 YP 22 FL 16 Gels 8/19/22 CL- 300 FC 1/ SOL 9 SD tr OIL 1/90 MBL 18 pH 9.2 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1400 @ WG @ TRIP GAS CUTTING GAS @ @ WIPER GAS 1400 @ TD CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY PULL OUT OF THE HOLE TO THE SHOE, CLEAN THE RIG FLOOR, CUT AND SLIP NEW DRILL LINE, SERVICE ACTIVITY THE TOP DRIVE, RUN IN THE HOLE TO 10769' AND CIRCULATE THE HOLE, WIPER GAS 1400', CONTINUE SUMMARY TO CIRCULATE DRILLING MUD AND CONDITION THE HOLE FOR 7" CASING, BEGIN TO PULL OUT OF THE HOLE WITH 5" DRILL PIPE AND LAY DOWN. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file: / /C:\ Documents %20and %20S ettings \RigUser \My %20Documents \My %20 Wells \Conoc... 9/3/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT U-1 E 2N -310 REPORT FOR MORRIS /HEIM DATE Sep 04, 2007 DEPTH 10840.00000 PRESENT OPERATION RUN 7" CASING TIME 12:01 AM YESTERDAY 10840.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625" @ 3520' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 10840' 5161.09' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 8.75" HTC HCM605Z 7107627 5X15 3530 10840' 7310' 54.94 1/1 -X TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10840' MW 9.6 VIS 58 PV 16 YP 21 FL 3.6 Gels 9/13/15 CL- 275 FC it SOL 9 SD tr OIL tr MBL 26 pH 8.8 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 27 @ 3484 (CIRC) @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 5 PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY LAY DOWN 5" DRILL PIPE, LAY DOWN BHA, DOWN LOAD MWD, WASH OUT BOP, CHANGE OUT PIPE SUMMARY RAMS TO 7" AND TEST, RUN 7" CASING TO 3484' AND CIRCULATE THE DRILLING MUD, MAX GAS WAS 27 UNITS, LOAD MORE CASING TO RUN. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. • file: / /C:\ Documents% 20and% 20Settings\ RigUser\ My% 20Documents \My %20Wells \Conoc... 9/4/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSiTE REPORT hi 2N -310 REPORT FOR BREEDEN /HEIM DATE Sep 05, 2007 DEPTH 10840.00000 PRESENT OPERATION RIG DOWN CEMENT EQUIPMENT TIME 12:01 AM YESTERDAY 10840.00000 24 HOUR FOOTAGE 0' CASING INFORMATION T' @ 10827' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 10840' 5151.09' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10827' MW 9.6 VIS 42 PV 8 YP 14 FL 4.8 Gels 4/5/6 CL- 250 FC 11 SOL 9 SD TR OIL TR MBL 22 pH 8.7 Ca+ 60 CCI MWD SUMMARY . INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 2613 (TG) @ 10827' @ TRIP GAS 2613 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 0 PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY CEMENT CIRCULATE AND CONDITION MUD WITH 7" CASING @ 3484' CIRCULATE OUT 27 UNITS, RUN IN THE HOLE DAILY TO 4467' CIRCULATE OUT 40 UNITS, RUN IN THE HOLE TO 6000' CIRCULATE OUT 40 UNITS, RUN IN THE ACTIVITY HOLE TO 8035' CIRCULATE OUT 30 UNITS, RUN IN THE HOLE TO 9852' CIRCULATE OUT 1160 UNITS, RUN IN SUMMARY THE HOLE TO 10828' AND CIRCULATE OUT TRIP GAS OF 2613 UNITS, MAKE UP CEMENT CEMENT HEAD AND PUMP CEMENT TO CASING MAX GAS PUMPING CEMENT IS 1604 UNITD, RIG DOWN CEMENT EQUIPMENT. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEEES F. BROWNE JR. file: / /C:\ Documents% 20and% 20Settings\ RigUser\ My% 20Documents \My %20Wells \Conoc... 9/5/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT E4 E UH 2N -310 REPORT FOR BREEDEN /HEIM DATE Sep 06, 2007 DEPTH 10840.00000 PRESENT OPERATION MAKE UP BHA TIME 12:01 AM YESTERDAY 10840.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 10827' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 10840' 5151.09' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 6.125" HTC HCM505Z 7009678 5X10 10840' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENTAVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10840' MW 9.6 VIS 41 PV 8 YP 13 FL 5 Gels 415/7 CL- 250 FC 1/ SOL 9 SD TR OIL TR MBL 22 pH 8.6 Ca+ 60 CCI • MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS NO MUD CIRCULATED THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY CEMENT DAILY CHANGE OUT UPPER RAMS TO 4 ", UNLOAD CASING EQUIPMENT FROM THE RIG, TEST 4" RAMS AND ACTIVITY LOAD 4" DRILL PIPE INTO RIG, PICK UP AND MAKE UP 4" DRILL PIPE AND RUN IN THE HOLE TO 3515' AND SUMMARY PULL OUT OF THE HOLE AND RACK BACK, CHANGE OUT LINERS IN MUD PUMPS, SERVICE THE TOP DRIVE, MAKE UP BHA. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. 0 0 0 0 file: / /C: \Documents /o20and /o20Settings \RigUser \My /o20Documents \My /o20Wells \Conoc... 9/6/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT by 2N -310 REPORT FOR BREEDEN /HEIM DATE Sep 07, 2007 DEPTH 10862.00000 PRESENT OPERATION DRILLING TIME 12:01 AM YESTERDAY 10840.00000 24 HOUR FOOTAGE 22' CASING INFORMATION 7" @ 10827' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 10840' 5151.09' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 6.125" HTC HCM505Z 7009678 5X10 10840' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 198.4 @ 10845.00000 7.0 @ 10861.00000 83.0 9.47234 FT /HR SURFACE TORQUE 19 @ 10841.00000 8 @ 10862.00000 12.3 8.89848 AMPS WEIGHT ON BIT 19 @ 10841.00000 1 @ 10862.00000 9.9 1.07980 KLBS ROTARY RPM 97 @ 10840.00000 55 @ 10843.00000 68.4 74.00000 RPM PUMP PRESSURE 2238 @ 10842.00000 1134 @ 10862.00000 2140.4 1134.39868 PSI DRILLING MUD REPORT DEPTH 10840' MW 9.6 VIS 170 PV 34 YP 20 FL 4.8 Gels 4/6/6 CL- 350 FC 1/ SOL 7 SD 0 OIL 0 MBL 8 pH 9.5 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 13 @ 10847.00000 4 @ 10851.00000 8.0 TRIP GAS 38 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C -1) 2291 @ 10840.00000 658 @ 10850.00000 1186.2 CONNECTION GAS HIGH ETHANE (C -2) 168 @ 10847.00000 56 @ 10850.00000 94.0 AVG PROPANE (C -3) 101 @ 10847.00000 34 @ 10850.00000 56.5 CURRENT BUTANE (C -4) 96 @ 10847.00000 24 @ 10859.00000 45.6 CURRENT BACKGROUND /AVG 6 PENTANE (C -5) 19 @ 10847.00000 4 @ 10841.00000 10.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SILTSTONE, SAND PRESENT LITHOLOGY 10860'= 80% SILTSTONE, 20% SAND MAKE UP BHA AND UPLOAD MWD AND SHALLOW TEST TOOL, LOAD NUKE SOURCES, RUN IN THE HOLE DAILY TO 10556', WASH TO 10650' AND CIRCULATE, TEST CASING TO 3000 PSI /30 MINS, WASH TO 10740' AND ACTIVITY TAG PLUG, DRILL THROUGH PLUG AND FLOAT AT 10743', DISDPLACE THE HOLE WITH NEW 9.6 MUD, SUMMARY DRILL TO 10860' ( +20' OF NEW HOLE), CIRCULATE THE HOLE CLEAN, L.O.T. @ 14.8 PPG MWE, 9.6 PPG, DRILL AHEAD EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file: / /C:\ Documents %20and %20S ettings \RigUser \My %20Documents \My %20 Wells \Conoc... 9/7/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT h- �rl 2N -310 REPORT FOR BREEDEN /HEIM DATE Sep 08, 2007 DEPTH 11172.00000 PRESENT OPERATION DRILLING TIME 12:01 AM YESTERDAY 10862.00000 24 HOUR FOOTAGE 310' CASING INFORMATION 7" @ 10827' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 11121 36.11 66.60 5379.43' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 6.125" HTC HCM505Z 7009678 5X10 10840' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 111.5 @ 11076.00000 4.2 @ 10883.00000 35.3 14.29729 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 91 @ 11052.00000 1 @ 10862.00000 25.1 70.45676 KLBS ROTARY RPM 99 @ 10879.00000 1 @ SLIDE 57.7 0.00000 RPM PUMP PRESSURE 2602 @ 11159.00000 311 @ 10913.00000 989.2 503.27295 PSI DRILLING MUD REPORT DEPTH 11170' MW 9.6 VIS 62 PV 23 YP 21 FL 5 Gels 5/5/7 CL- 500 • FC 1/ SOL 9 SD TR OIL 1 MBL 12 pH 9.9 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 111 @ 11170.00000 2 @ 10871.00000 13.9 TRIP GAS CUTTING GAS 0 @ 11172.00000 0 @ 11172.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 13008 @ 11170.00000 198 @ 10868.00000 1808.3 CONNECTION GAS HIGH 185 ETHANE (C -2) 1178 @ 11170.00000 19 @ 10885.00000 112.2 AVG 142 PROPANE (C -3) 547 @ 11170.00000 12 @ 10871.00000 66.5 CURRENT 56 BUTANE (C -4) 238 @ 11170.00000 6 @ 10870.00000 60.2 CURRENT BACKGROUND /AVG 54 PENTANE (C -5) 86 @ 10900.00000 0 @ 11122.00000 14.4 HYDROCARBON SHOWS VERY POOR SLIGHT OIL FLUORESCENCE WITH NO OIL CUTS THE LAST 24 HRS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SAND, SILTSTONE PRESENT LITHOLOGY 11170 = 100% SAND DAILY ACTIVITY SUMMARY DRILL AND SLIDE FORMATION EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file: / /C:\ Documents %20and %20S ettings \RigUser \My %20Documents \My %20 Wells \Conoc... 9/8/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT E4 hl! �H 2N -310 REPORT FOR BREEDEN /HEIM DATE Sep 09, 2007 DEPTH 11528.00000 PRESENT OPERATION DRILL I SLIDE TIME 12:01 AM YESTERDAY 11172.00000 24 HOUR FOOTAGE 356' CASING INFORMATION 7" @ 10827' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 11499.23 18.59 69.39 5714.95' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 6.125" HTC HCM505Z 7009678 5X10 10840' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 532.3 @ 11232.00000 4.4 @ 11352.00000 32.1 31.13621 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 70 @ 11172.00000 5 @ 11426.00000 33.8 15.26995 KLBS ROTARY RPM 81 @ 11426.00000 1 @ SLIDE 39.4 80.00000 RPM PUMP PRESSURE 3549 @ 11411.00000 366 @ 11309.00000 1282.4 1154.97888 PSI DRILLING MUD REPORT DEPTH N/A MW 9.6 VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCl MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 255 @ 11222.00000 4 @ 11291.00000 38.4 TRIP GAS CUTTING GAS 0 @ 11528.00000 0 @ 11528.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 31850 @ 11189.00000 240 @ 11414.00000 5019.2 CONNECTION GAS HIGH 490 ETHANE (C -2) 3792 @ 11189.00000 21 @ 11414.00000 500.8 AVG 135 PROPANE (C -3) 1819 @ 11222.00000 11 @ 11414.00000 285.3 CURRENT 87 BUTANE (C -4) 936 @ 11309.00000 13 @ 11478.00000 149.0 CURRENT BACKGROUND /AVG 11 PENTANE (0-5) 272 @ 11309.00000 2 @ 11291.00000 46.8 HYDROCARBON THREE POOR OIL SHOWS (BEST SHOW BELOW) SHOWS INTERVAL LITHOLOGYIREMARKS GAS DESCRIPTION 11215 TO 11230' 50 % SAND 50% BEFORE 60 MAX MIX OF MED TO FINE SAND AND VERY FINE TO FINE SANDSTONE 255 AFTER 20 SANDSTONE 50% EVEN TO PATCHY SAMPLE FLOR W/ POOR OIL CUTS LITHOLOGY SAND, SANDSTONE, SILTSTONE, CARBONACEOUS SILT PRESENT LITHOLOGY 11590'= 60% SILTSTONE, 40% CARBONACEOUS SILTS DAILY ACTIVITY SUMMARY DRILL AND SLIDE FORMATION THE LAST 24 HOURS EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. O file: / /C:\ Documents %20and %20 Settings \RigUser \My %20Documents \My %20 W ells \Conoc... 9/9/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT 2N -310 REPORT FOR BREEDEN /HEIM DATE Sep 10, 2007 DEPTH 11840.00000 PRESENT OPERATION TEST BOPE @ SHOE TIME 12:01 AM YESTERDAY 11528.00000 24 HOUR FOOTAGE 312' CASING INFORMATION 7" @ 10827' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 11840 19.28 65.81 6036.22' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 6.125" HTC HCM505Z 7009678 5X10 10840 11840 1000' 38.13 N/A TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 116.4 @ 11820.00000 12.4 @ 11563.00000 43.5 88.26800 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT 40 @ 11559.00000 15 @ 11534.00000 31.0 28.34500 KLBS ROTARY RPM 81 @ 11543.00000 1 @ 11569.00000 73.3 79.00000 RPM PUMP PRESSURE 1621 @ 11568.00000 715 @ 11707.00000 949.6 949.17700 PSI DRILLING MUD REPORT DEPTH 11840 MW 10.0 VIS 66 PV 27 YP 20 FL 4.2 Gels 5/616 CL- 400 FC it SOL 8.5 SD tr OIL 3 MBL 12 pH 9.6 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 35 @ 11705.00000 7 @ 11562.00000 16.9 TRIP GAS CUTTING GAS 0 @ 11840.00000 0 @ 11840.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 6250 @ 11705.00000 899 @ 11550.00000 2579.8 CONNECTION GAS HIGH 87 ETHANE (C -2) 429 @ 11705.00000 62 @ 11562.00000 164.5 AVG 55 PROPANE (C -3) 287 @ 11705.00000 51 @ 11562.00000 109.9 CURRENT 35 BUTANE (C -4) 239 @ 11794,00000 32 @ 11611.00000 68.0 CURRENT BACKGROUNDIAVG 0 PENTANE (C -5) 109 @ 11794.00000 2 @ 11569.00000 26.1 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SILTSTONE, CARBONACEOUS SILTSTONE, SANDSTONE, ASH PRESENT LITHOLOGY 11840'= 90% SILTSTONE, 10% CARBONACEOUS SILT DRILL FORMATION TO 11840' (TD), PUMP A HIGH VISCOSITY SWEEP, ROTATE AND RECIPROCATE THE DAILY DRILL PIPE, CIRCULATE AND CONDITION THE MUD (SWAB GAS 177 UNITS), MONITOR THE WELL, WELL ACTIVITY FLOWING SLOWLY, CIRCULATE BOTTOMS UP (DOWNTIME GAS 257 UNITS), CIRCULATE AND INCREASE SUMMARY MUD WEIGHT FROM 9.6 TO 10.0 ppg, MONITOR THE WELL, PULL OUT OF THE HOLE TO 10744', MONITOR THE WELL, SERVICE THE TOP DRIVE, SWIVEL AND CROWN, PREP TO TEST ROPE. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file: / /C:\ Documents% 20and% 20Settings\ RigUser\ My %20Documents \My %20Wells \Cono... 9/10/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT E -��H 2N -310 REPORT FOR BREEDEN /HEIM DATE Sep 11, 2007 DEPTH 11840.00000 PRESENT OPERATION PULL OUT OF HOLE TIME 12:01 AM YESTERDAY 11840.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 10828' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 11840' 19.28 65.81 6036.22' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 6.125" HTC HCM505Z 7009678 5X10 10840' 11840' 1000 38.13 N/A TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 11840' MW 10.0 VIS 70 PV 28 YP 20 FL 4.2 Gels 5/7/8 CL- 500 FC 1/ SOL 8.5 SD tr OIL 3 MBL 10 pH 9.8 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 259 @ SWAB GAS @ TRIP GAS CUTTING GAS @ @ WIPER GAS 259 @ TD CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 0 PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 11840'= 90% SILTSTONE, 10% CARBONACEOUS SILT TEST BOPE, RUN IN THE HOLE FROM THE SHOE TO 11840', PUMP A HIGH VISCOSITY SWEEP @ 4 bpm AND DAILY CIRCULATE AND CONDITION THE WELL, WIPER GAS = 259 UNITS, MONITOR THE WELL, CIRCULATE AND ACTIVITY CONDITION THE WELL, LOST 50 bbls OF MUD WHILE CIRCULATING, SWAB GAS OF 255 UNITS AND SUMMARY DOWNTIME GAS OF 115 UNITS, HOLE RECEIVED BACK 15 bbls in 15 MINUTES AND SLOWED TO 1 bbl /hr. TOTAL FLUID BACK WHILE MONITORING WAS 24 bbls. PULL OUT OF THE HOLE TO 10366', PUMP A DRY JOB AND BEGIN TO PULL OUT OF THE HOLE WITH BIT #3 EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file: //C:\Documents%20and%20 S ettings\RigUser\My%20Documents\My%2OWells\Cono... 9/11/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT L4 h �ri 2N -310 REPORT FOR BREEDEN/VAAGAN DATE Sep 12, 2007 DEPTH 11840.00000 PRESENT OPERATION SIDEWALL CORES TIME 12:01 AM YESTERDAY 11840.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 10828' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 11840' 19.28 65.81 6036.22' BIT INFORMATION INTERVAL CONDITION REASON NO, SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 6.125" HTC HCM505Z 7009678 5X10 10840' 11840' 1000 38.13 1 /1 -X -PN TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 11840' MW 10.0 VIS 69 PV 25 YP 21 FL 4 Gels 5/6/7 CL- 400 FC 1/ SOL 8.5 SD tr OIL 3 MBL 11 pH 9.9 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 34 @ RIH @ TRIP GAS 34 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 0 PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 11840 = 90% SILTSTONE, 10% CARBON SILT PULL OUT OF THE HOLE TO 397' (TOP OF BHA), LAY DOWN BHA, LAY DOWN HWDP, REMOVE AND LAY DAILY DOWN NUKE SOURCES, DOWNLOAD MWD DATA, RIG UP AND TEST LOGGING TOOLS, RUN IN THE HOLE ACTIVITY WITH DRILL PIPE AND DRILL PIPE CONVEY TOOLS AND SIDE WALL CORES, RUN IN THE HOLE TO 6125' AND SUMMARY CIRCULATE @ 4 BPM MAX GAS 22 UNITS, RUN IN THE HOLE TO 9165' AND CIRCULATE @ 4 BPM MAX GAS 34 UNITS, RUN IN THE HOLE TO 10630' MAX GAS 13 UNITS, RIG UP LOGGERS AND RUN IN THE HOLE WITH WIRELINE AND RUN SIDE WALL CORES. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file: //C:\D ocuments%20and%20 Settings\RigUser\My%20Documents\My%2OWells\Cono... 9/12/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT hr �,rl 2N -310 REPORT FOR BREEDEN/VAAGEN DATE Sep 13, 2007 DEPTH 11840.00000 PRESENT OPERATION TRIP IN WITH SIDEWALL CORE RUN #2 TIME 12:01 AM YESTERDAY 11840.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 10828' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 11840' 19.28 65.81 6036.22' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 11840' MW 10.0 VIS 70 PV 24 YP 22 FL 2 Gels 5/6/7 CL- 500 FC 1/ SOL 8.5 SD TR OIL 3 MBL 10 pH 9.9 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 12 @ FILLING DP @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 0 PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 11840'= 90% SILTSTONE, 10% CARBONACEOUS SILTSTONE TAKE SIDEWALL CORES TO 11307' PULL OUT OF THE HOLE, PULL OUT OF THE HOLE TO 11602' ON DRILL DAILY PIPE, PULL OUT OF THE HOLE WITH WIRELINE AND MONITOR THE WELL, RUN IN THE HOLE WITH DRILL ACTIVITY PIPE FROM 10602' TO 11200' AND CIRCULATE BOTTOMS UP @ 51 SPM AND MONITOR THE WELL, MAX GAS SUMMARY 12 UNITS, PUMP A DRY JOB, CUT AND SLIP NEW DRILL LINE, AND PULL OUT OF THE HOLE TO THE CORE ASSEMBLY, RIG DOWN AND LAY DOWN CORE ASSEMBLY, RIG UP AND MAKE UP CORE ASSEMBLY #2 AND LOGGING TOOLS AND TEST, RUN IN THE HOLE WITH TOOLS AND FILL EVERY 3000' EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file: / /C: \Documents %20and %20Settin s \Ri User \M %20Documents \M %20Wells \Cono... 9/13/2007 g g Y Y Daily Report Page 1 of 1 0 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT E�'QCH 2N -310 REPORT FOR BREEDENNAAHAN DATE Sep 14, 2007 DEPTH 11840.00000 PRESENT OPERATION TRIP IN FOR CLEAN OUT RUN TIME 12:01 AM YESTERDAY 11840.00000 24 HOUR FOOTAGE 0' CASING INFORMATION 7" @ 10828' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 11840' 19.28 65.81 6036.22' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED OB #3rr 6.125" HTC HCM505Z 7009678 11840 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 11840' MW 9.5 VIS 50 PV 15 YP 12 FL 4 Gels 3/4/5 CL- 400 FC 1/ SOL 7.5 SD TR OIL 3 MBL 10 pH 10.3 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 26 @ 11113' @ TRIP GAS CUTTING GAS @ @ WIPER GAS 26 CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 0 PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY RUN IN THE HOLE TOP 10402', PICK UP WIRELINE AND RUN IN THE HOLE WITH WIRELINE, PUMP AT 20 SPM, RUN IN THE HOLE WITH WIRELINE ON DRILL PIPE, TAG AT 11322' AND UNABLE TO GO DOWN AS REQUIRED, DAILY PULL TO SURFACE, RUN 19N THE HOLE FROM 10482' TO 11113', CIRCULATE BOTTOMS UP, WIPER GAS 26 ACTIVITY UNITS @ 3 BPM, MONITOR THE WELL, PULL OUT OF THE HOLE TO 11016', MONITOR THE WELL (STATIC), SUMMARY PULL OUT OF THE HOLE TO 102', RIG DOWN AND LAY DOWN LOGGING TOOLS, CLEAN RIG FLOOR, PICK UP AND MAKE UP BHA AND DUMB IRON FOR CLEAN OUT RUN, RUN IN THE HOLE WITH 4" DRILL PIPE (OB #3rr) MUD BROUGHT DOWN FROM 10.0 PPG TO 9.5 PPG. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file: / /C:\ Documents% 20and% 20Settings\ RigUser\ My %20Documents \My %2OWells \Cono... 9/14/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT :,Po�11 2N -310 REPORT FOR BREEDEN/VAAGEN DATE Sep 15, 2007 DEPTH 11840.00000 PRESENT OPERATION CIRCULATE HOLE AT TD TIME 12:01 AM YESTERDAY 11840.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 10828' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 11840' 19.28 65.81 6036.22' BIT INFORMATION INTERVAL CONDITION REASON NO, SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED OB #3 rr 6.125" HTC HCM505Z 7009678 11840' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 11840' MW 9.9 VIS 60 PV 17 YP 26 FL 4.2 Gels 7/8/9 CL- 400 FC 1/ SOL 8 SD TR OIL 3 MBL 12 pH 9.9 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 150 @ TD WG @ TRIP GAS CUTTING GAS @ @ WIPER GAS 150 CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 20498 @ TD WG @ CONNECTION GAS HIGH ETHANE (C -2) 1067 @ TD WG @ AVG PROPANE (C -3) 401 @ TD WG @ CURRENT BUTANE (C -4) 208 @ TD WG @ CURRENT BACKGROUND /AVG 15 (CIRC) PENTANE (C -5) 61 @ TD WG @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY RUN IN THE HOLE TO 10786', SWAP CASING VOLUME MUD FOR 9.8 MUD CIRC AT 3 BPM, MAX GAS 34 DAILY UNITS, RUN IN THE HOLE WITHOUT PUMPS TO 11520' WASH AND ROTATE TO 11840' AND CIRCULATE AND ACTIVITY CONDITION THE MUD AT 40 BPH, WIPER GAS WAS 122 UNITS, MONITOR THE WELL, PULL OUT OF THE SUMMARY HOLE TO 10805', MONITOR THE WELL, RUN IN THE HOLE TO 11655' AND CIRCULATE, RUN TO BOTTOM AND CIRCULATE, WIPER GAS WAS 150 UNITS, CIRCULATE MUD AND MOVE THE DRILL PIPE (LOWERING ECD AND INCREASING THE FLOWRATE. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file: / /C:\ Documents% 20and% 20Settings \RigUser \My %20Documents \My %20W ells \Cono... 9/15/2007 Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT 14 EPOCH 2N -310 REPORT FOR BREEDEN/VAAHEN DATE Sep 16, 2007 DEPTH 11840.00000 PRESENT OPERATION WIRELINE LOGGING TIME 12:01 YESTERDAY 11840.00000 24 HOUR FOOTAGE 0 CASING INFORMATION T' @ 10828' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 11840' 19.28 65.81 6036.22' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 11840' MW 9.9 VIS 62 PV 16 YP 24 FL 4 Gels 7/8/10 CL- 400 FC 1/ SOL 7 SD TR OIL 3 MBL 12 pH 9.7 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 6 (FILL DP) @ 10745' @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY(ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 0 PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY PULL OUT OF THE HOLE FROM 11840' TO 34.5' AND CUT AND SLIP NEW DRILL LINE, PICK UP AND MAKE ACTIVITY UP LOGGING TOOLS AND TEST, RUN IN THE HOLE FROM 102' TO 10745' AND FILL THE DRILL PIPE, RIG UP SUMMARY AND MAKE UP SWS SIDE ENTRY SUB, RUN IN THE HOLE FROM 10705' TO 10713' AND TEST TOOL, RUN IN THE HOLE FROM 10713' TO 11502 WITH WIRELINE. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file: / /C:\ Documents% 20and% 20Settings\ RigUser\ My %20Documents \My %20Wells \Cono... 9/16/2007 Daily Report Page 1 of 1 CONOCQPHILLIPS • TARN DAILY WELLSITE REPORT U4 "0 1 � "T-T 2N -310 REPORT FOR BREEDEN/VAAGEN DATE Sep 17, 2007 DEPTH 11840.00000 PRESENT OPERATION REPLACE TRACTION MOTOR TIME 12:01 YESTERDAY 11840.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 10828' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 11840' 19.28 65.81 6036.22' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 109 (circ) @ 10979' @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 0 PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY RUN IN THE HOLE WITH LOGGING TOOLS TO 11810', LOG TO 10836', RUN IN THE HOLE WITH LOGGING SUMMARY TOOLS TO 10979', SERVICE RIG, DRAW WORKS POWER PROBLEMS, REPLACING TRACTION MOTOR, CIRCULATE BOTTOMS UP MAXIMUM GAS WAS 109 UNITS. EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335 REPORT BY LEES F. BROWNE JR. file: / /C:\ Documents %20and %20S ettings \RigUser \My %20Documents \My %20 W ells \Cono... 9/17/2007