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211-062
Originated: Delivered to:17-Jan-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1E-07A 50-029-20495-01 909619502 Kuparuk River Packer Setting Record Field- Final 20-Oct-24 0 12 1E-28A 50-029-20832-01 n/a Kuparuk River Packer Setting Record Field- Final 16-Jan-25 0 13 1F-08 50-029-20836-00 909737879 Kuparuk River Plug Setting Record Field- Final 3-Dec-24 0 14 1H-101 50-029-23585-00 909606936 Kuparuk River Multi Finger Caliper Field & Processed 28-Oct-24 0 15 1R-20 50-029-22207-00 909678505 Kuparuk River Packer Setting Record Field- Final 11-Nov-24 0 16 2A-16 50-103-20042-00 909780661 Kuparuk River Multi Finger Caliper Field & Processed 1-Jan-25 0 17 2C-03 50-029-20968-00 909740014 Kuparuk River Plug Setting Record Field- Final 14-Jan-25 0 18 2M-07 50-103-20178-00 909618938 Kuparuk River Plug Setting Record Field- Final 25-Oct-24 0 19 2W-01 50-029-21273-00 909740411 Kuparuk River Radial Bond Record Field- Final 7-Jan-25 0 110 3B-04 50-029-21323-00 909740412 Kuparuk River Multi Finger Caliper Field & Processed 3-Jan-25 0 1PLEASE 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 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T39999T40000T40001T40002T40003T40004T40005T40006T40007211-062213-095182-162217-138191-108185-147183-089192-080185-010185-061T400081/23/20251E-07A50-029-20495-01909619502Kuparuk RiverPacker Setting RecordField- Final20-Oct-2401211-062213 095Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.01.23 15:13:51 -09'00' 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: Tubing patches 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 10898'feet none feet true vertical 6242'feet none feet Effective Depth measured 8953'feet 8520'feet true vertical 6457'feet 6118'feet Perforation depth Measured depth 9440' - 10900' slots feet True Vertical depth 6369' - 6339' slots feet Tubing (size, grade, measured and true vertical depth)3.5" J-55 8916' 6428' Packers and SSSV (type, measured and true vertical depth)Baker HB packer 8520' MD / 6118' TVD Camco TRDP-1A 1944' MD / 1791' TVD 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: Jan Byrne / Dusty Freeborn Authorized Title: Well Integrity Compliance Specialist Contact Email:N1617@conocophillips.com Contact Phone:907-659-7224 PO Box 100360, Anchorage, Alaska, 99510 ConocoPhillips Alaska, Inc WINJ WAG Water-Bbl MD 80' 3249' ADL0025651 Oil-Bbl measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure KRU 1E-07A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 211-062 50-029-20495-01 5. Permit to Drill Number:2. Operator Name 3. Address: 4. Well Class Before Work: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs Junk measured 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Size Authorized Signature with date: Authorized Name: Jan Byrne Liner Kuparuk River Field / Kuparuk River Oil Pool Conductor Surface Intermediate Production Length 52' 3218' 9258' Casing Structural 16" 10.75" 7"9289' TVD 80' 2679' 6400' Burst Senior Engineer:Senior Res. Engineer: Collapse t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: Working remotely from home Date: 2020-05-02 16:59:55 Foxit PhantomPDF Version: 9.7.0 jan.byrne@conocop hillips.com By Samantha Carlisle at 1:15 pm, May 03, 2020 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 2 May 2020 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 Report for Sundry Well Operations for ConocoPhillips Alaska, Inc. well KRU 1E-07A (PTD 211-062) for tubing patch repair. Please contact Dusty Freeborn or myself at 659-7224 if you have any questions. Sincerely, Jan Byrne Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: Working remotely from home Date: 2020-05-02 16:58:48 Foxit PhantomPDF Version: 9.7.0 jan.byrne@con ocophillips.com Last Tag Annotation Depth (ftKB) End Date Last Mod By Wellbore Last Tag: RKB osborl 1E-07AL2 Last Rev Reason Annotation End Date Last Mod By Wellbore Rev Reason: Set Patches 4/29/2020 famaj 1E-07A Notes: General & Safety End Date 11/13/2004 Annotation NOTE: C-SAND LEAK @ 8860', NEAR CSM Wellbore 1E-07 End Date 6/15/2011 Annotation NOTE: MILL CEMENT FROM 8609 - 8879 CTMD w/ 2.69" x 2.98" B: CENTER BIT Wellbore 1E-07 End Date 2/2/2015 Annotation NOTE: IA X OA COMMUNICATION Wellbore 1E-07A Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread Wellbore CONDUCTOR 16 15.06 28.0 80.0 80.0 65.00 H-40 WELDED 1E-07A SURFACE 10 3/4 9.95 31.2 3,249.0 2,679.2 45.50 K-55 BTC 1E-07A PRODUCTION 7 6.28 31.7 9,289.3 6,399.9 26.00 K-55 BTC 1E-07A WINDOW AL2-01 7 6.00 8,876.0 8,883.0 6,404.5 26.00 K-55 1E-07A WINDOW A 7 6.00 8,892.0 8,899.0 6,416.5 26.00 K-55 1E-07A LINER AL2-01 2 3/8 2.00 8,872.0 11,090.0 4.70 L-80 STL 1E-07AL2- 01 LINER AL1 2 3/8 2.00 8,892.6 10,857.0 6,330.3 4.70 L-80 STL 1E-07AL1 LINER AL2 2 3/8 2.00 9,373.0 11,132.0 4.70 L-80 STL 1E-07AL2 LINER A 2 3/8 2.00 9,429.1 10,900.0 4.70 L-80 STL 1E-07A Tubing Strings Des String Max Nominal OD (in)ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt (lb/ft) Grade Top Thread Wellbore TUBING 3 1/2 2.99 27.5 8,555.2 6,145.7 9.20 J-55 AB MOD-BTC 1E-07A TUBING Original 3 1/2 2.92 8,554.3 8,917.9 6,429.0 9.20 K-55 FL4S 1E-07A Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 27.5 27.5 0.00 HANGER FMC GEN I RETROFIT HANGER 3.500 1E-07A 1,944.2 1,790.5 45.83 SAFETY VLV CAMCO TRDP-1A-ENC SAFETY VALVE 2.812 1E-07A 8,467.7 6,076.7 38.32 NIPPLE OTIS X SELECTIVE LANDING NIPPLE 2.813 1E-07A 8,506.1 6,106.8 37.92 PBR BAKER PBR w/ 10' STROKE 3.000 1E-07A 8,519.8 6,117.6 37.75 PACKER BAKER HB RETRIEVABLE PACKER 2.890 1E-07A 8,533.0 6,128.1 37.59 SBR BAKER G-SEAL SBR w/ OTIS PROFILE STABBE INTO EXISTING SLICK STICK IN ORIGINAL COMPLETION 2.813 1E-07A 8,554.3 6,145.0 37.32 SLICK STICK 3.000 1E-07A 8,559.3 6,149.0 37.26 PACKER BAKER HB-1 PACKER 2.890 1E-07A 8,673.5 6,240.2 37.30 BLAST RINGS CARBIDE BLAST RING (6) ID = 2.867" 2.920 1E-07A 8,876.3 6,399.4 40.48 LOCATOR BAKER LOCATOR SUB 3.000 1E-07A 8,877.2 6,400.1 40.51 PACKER BAKER FB-1 PACKER 4.000 1E-07A 8,879.7 6,402.0 40.59 SBE BAKER SEAL BORE EXTENSION 2.813 1E-07A 8,899.7 6,417.0 44.39 NIPPLE CAMCO D NIPPLE NO GO, MILLED OUT TO 2.80, 5/12/2011 2.800 1E-07A 8,916.3 6,428.0 51.69 SOS BAKER SHEAR OUT SUB 2.992 1E-07A Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) Wellbore 7,062.0 5,074.7 51.25 Upper Packer 2.72" P2P Packer (CPP35139) w/ 12.5' of 2 1/16" P-110 Spacer Pipe and Anchor Latch (CPAL35149) Max OD 2.725" OAL 17' 4/28/2020 1.600 1E-07A 7,066.0 5,077.2 51.25 Spacer Pipe 2 1/16" P-110 Spacer Pipe 4/28/2020 1.600 1E-07A 7,070.0 5,079.7 51.25 Tubing Leak Tubing Leak at 7070' 3/30/2018 2.992 1E-07A 7,079.0 5,085.3 51.25 Lower Packer 2.72" P2P Packer (CPP35223) Max OD 2.725" OAL 4'. 4/27/2020 1.625 1E-07A 7,673.5 5,482.7 44.20 Upper Packer 2.72" P2P Packer (CPP35158) w/ 26' of 2 1/16" P-110 Spacer Pipe and Anchor Latch (CPAL35148) Max OD 2.725" OAL 31' 4/27/2020 1.600 1E-07A 7,677.5 5,485.5 44.17 Spacer Pipe 2 1/16" P-110 Spacer Pipe 4/27/2020 1.600 1E-07A 7,700.0 5,501.7 44.00 Tubing Leak Tubing Leak at 7700' 2/10/2016 2.992 1E-07A 7,704.0 5,504.6 43.98 Lower Packer 2.72" P2P Packer (CPP35232) Max OD 2.725" OAL 4'. 4/26/2020 1.625 1E-07A 8,434.7 6,050.8 38.65 Upper Packer 2.72" P2P Packer (CPP35051) w/ 25.75' of 2 1/16" P-110 Spacer Pipe and Anchor Latch (CPAL35109) Max OD 2.725" OAL 1730.5' 4/24/2020 1.600 1E-07A 8,438.8 6,054.0 38.61 Spacer Pipe 2 1/16" P-110 Spacer Pipe 4/24/2020 1.600 1E-07A 8,448.0 6,061.2 38.52 Tubing Leak Tubing Leak at 8448' 4/20/2020 2.992 1E-07A 8,465.0 6,074.5 38.35 Lower Packer 2.72" P2P Packer (CPP35207) Max OD 2.725" OAL 4'. 4/23/2020 1.625 1E-07A 8,876.0 6,399.2 40.47 WHIPSTOCK 3.5 MONOBORE RETRIEVABLE FLOW- THRU WHIPSTOCK 6/23/2011 0.000 1E-07A 8,892.0 6,411.3 40.99 WHIPSTOCK 3.5 MONOBORE RETRIEVABLE FLOW- THRU WHIPSTOCK 6/12/2011 0.000 1E-07A 9,010.0 6,498.6 43.43 PLUG SAND PLUG, 20/40 RIVER SAND 5/14/2010 0.000 1E-07 9,193.0 6,628.9 45.00 FISH Arm off OK-1 lost in Rathole 4/12/1987 1E-07 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 28.0 28.0 0.00 CONDUCTOR 15.060 1E-07A 31.7 31.7 0.00 HANGER 6.276 1E-07A 8,872.0 6,396.1 40.34 DEPLOY BAKER FULL SEALBORE SLEEVE 1.995 1E-07AL2- 01 8,876.0 6,399.2 40.47 WINDOW AL2-01 6.000 1E-07A 8,892.0 6,411.3 40.99 WINDOW A 6.000 1E-07A 8,892.6 6,411.8 41.27 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.995 1E-07AL1 Comment DEVIATED, 1E-07AL2-01, 5/2/2020 2:35:31 PM Vertical schematic (actual) LINER AL2-01; 8,872.0- 11,090.0 SLOTS; 10,455.7- 11,089.7 SLOTS; 9,171.1-10,363.9 LINER AL1; 8,892.6- 10,857.0 SLOTS; 9,227.9-10,857.0 PRODUCTION; 31.7- 9,289.3 SOS; 8,916.3 NIPPLE; 8,899.7 WINDOW A; 8,892.0- 8,899.0 WHIPSTOCK; 8,892.0 WINDOW AL2-01; 8,876.0-8,883.0 SBE; 8,879.7 WHIPSTOCK; 8,876.0 PACKER; 8,877.2 LOCATOR; 8,876.3 PRODUCTION; 8,860.1 PRODUCTION; 8,667.2 PRODUCTION; 8,598.1 PACKER; 8,559.3 SLICK STICK; 8,554.3 SBR; 8,533.0 PACKER; 8,519.8 PBR; 8,506.0 NIPPLE; 8,467.7 Lower Packer; 8,465.0 GAS LIFT; 8,452.8 Spacer Pipe; 8,438.8 Tubing Leak; 8,448.0 Upper Packer; 8,434.7 Lower Packer; 7,704.0 Tubing Leak; 7,700.0 GAS LIFT; 7,693.6 Spacer Pipe; 7,677.5 Upper Packer; 7,673.5 Lower Packer; 7,079.0 Spacer Pipe; 7,066.0 GAS LIFT; 7,068.6 Tubing Leak; 7,070.0 Upper Packer; 7,062.0 GAS LIFT; 6,347.9 GAS LIFT; 5,662.4 GAS LIFT; 4,488.6 SURFACE; 31.2-3,249.0 GAS LIFT; 2,398.4 SAFETY VLV; 1,944.2 CONDUCTOR; 28.0-80.0 HANGER; 27.5 KUP PROD KB-Grd (ft) 39.49 Rig Release Date 10/13/1980 Annotation Last WO: End Date 2/8/1992 H2S (ppm) 47 Date 1/31/2019... TD Act Btm (ftKB) 11,090.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292049562 Wellbore Status PROD Max Angle & MD Incl (°) 102.33 MD (ftKB) 9,270.37 Legal Wellname 1E-07 Common Wellname1E-07A AK All Wellbores Schem Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) Wellbore 9,170.3 6,412.7 98.43 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.995 1E-07AL2- 01 9,373.0 6,376.9 100.08 BILLET OH ANCHORED BILLET 1.995 1E-07AL2 9,429.1 6,371.3 102.52 BILLET LINER TOP ANCHORED ALUMINUM BILLET 1.995 1E-07A 9,468.9 6,360.7 99.44 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.995 1E-07AL2 9,572.2 6,339.3 102.65 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.995 1E-07A Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com Wellbore 9,171.1 10,363.9 6,412.6 6,343.6 C-2, 1E-07AL2- 01 7/4/2011 32.0 SLOTS Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 1E-07AL2- 01 10,455.7 11,089.7 6,343.0 6,325.8 C-4, 1E-07AL2- 01 7/4/2011 32.0 SLOTS 1E-07AL2- 01 9,401.7 9,468.4 6,371.9 6,360.8 C-1, 1E-07AL2 6/30/2011 32.0 SLOTS Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 1E-07AL2 9,469.8 11,131.6 6,360.6 C-1, 1E-07AL2 6/30/2011 32.0 SLOTS 1E-07AL2 9,227.9 10,857.0 6,412.0 6,330.3 C-2, 1E-07AL1 6/22/2011 32.0 SLOTS Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 1E-07AL1 9,439.9 9,571.7 6,368.9 6,339.4 C-2, 1E-07A 6/19/2011 32.0 SLOTS Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 1E-07A 9,573.0 10,899.6 6,339.1 C-2, 1E-07A 6/19/2011 32.0 SLOTS 1E-07A 8,686.0 8,832.0 6,250.1 6,365.4 C-4, C-3, C-2, 1E -07 8/22/1981 4.0 IPERF SOS ENERJET 0 deg 1E-07 8,855.0 8,860.0 6,383.1 6,387.0 C-2, 1E-07 5/19/2011 6.0 IPERF 2" x 5' GUNS, 60 DEG PHASE, 11 GM RDX, BH CHARGES 1E-07 8,877.0 8,882.0 6,399.9 6,403.7 C-1, 1E-07 5/19/2011 6.0 IPERF 2" x 5' GUNS, 60 DEG PHASE, 11 GM RDX, BH CHARGES 1E-07 8,892.0 8,897.0 6,411.3 6,415.1 C-1, UNIT B, 1E- 07 5/19/2011 6.0 IPERF 2" x 5' GUNS, 60 DEG PHASE, 11 GM RDX, BH CHARGES 1E-07 9,106.0 9,128.0 6,567.4 6,582.9 A-5, 1E-07 8/27/1993 4.0 RPERF SOS Titan 2 1/2" H.C 1E-07 9,106.0 9,128.0 6,567.4 6,582.9 A-5, 1E-07 8/22/1981 4.0 IPERF SOS ENERJET 0 deg 1E-07 9,138.0 9,175.0 6,590.0 6,616.2 A-4, 1E-07 8/22/1981 4.0 IPERF SOS ENERJET 0 deg 1E-07 9,138.0 9,175.0 6,590.0 6,616.2 A-4, 1E-07 8/27/1993 4.0 RPERF SOS Titan 2 1/2" H.C 1E-07 Mandrel Inserts St ati on No /S Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com Wellbore 1 2,398.4 2,106.9 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,263.0 4/29/2020 1E-07A 2 4,488.6 3,421.7 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 4/28/2020 1E-07A 3 5,662.4 4,172.0 CAMCO KBUG 1 GAS LIFT DMY BTM 0.000 0.0 5/7/2011 12:30 1E-07A 4 6,347.9 4,620.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 5/7/2011 7:00 1E-07A 5 7,068.6 5,078.8 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 2/8/1992 1:00 1E-07A 6 7,693.6 5,497.1 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 2/8/1992 6:00 1E-07A 7 8,452.8 6,064.9 OTIS LBX 1 1/2 GAS LIFT DMY RM 0.000 0.0 2/25/2016 1:00 1E-07A 8 8,598.1 6,180.0 CAMCO KBUG 1 PROD OPEN 0.000 0.0 5/22/2011 1E-07A 9 8,667.2 6,235.2 CAMCO KBUG 1 PROD DMY None 0.000 0.0 2/25/1992 Close d 1E-07A 1 0 8,860.1 6,387.0 CAMCO KBUG 1 PROD OPEN 0.000 0.0 5/17/2011 1E-07A DEVIATED, 1E-07AL2-01, 5/2/2020 2:35:32 PM Vertical schematic (actual) LINER AL2-01; 8,872.0- 11,090.0 SLOTS; 10,455.7- 11,089.7 SLOTS; 9,171.1-10,363.9 LINER AL1; 8,892.6- 10,857.0 SLOTS; 9,227.9-10,857.0 PRODUCTION; 31.7- 9,289.3 SOS; 8,916.3 NIPPLE; 8,899.7 WINDOW A; 8,892.0- 8,899.0 WHIPSTOCK; 8,892.0 WINDOW AL2-01; 8,876.0-8,883.0 SBE; 8,879.7 WHIPSTOCK; 8,876.0 PACKER; 8,877.2 LOCATOR; 8,876.3 PRODUCTION; 8,860.1 PRODUCTION; 8,667.2 PRODUCTION; 8,598.1 PACKER; 8,559.3 SLICK STICK; 8,554.3 SBR; 8,533.0 PACKER; 8,519.8 PBR; 8,506.0 NIPPLE; 8,467.7 Lower Packer; 8,465.0 GAS LIFT; 8,452.8 Spacer Pipe; 8,438.8 Tubing Leak; 8,448.0 Upper Packer; 8,434.7 Lower Packer; 7,704.0 Tubing Leak; 7,700.0 GAS LIFT; 7,693.6 Spacer Pipe; 7,677.5 Upper Packer; 7,673.5 Lower Packer; 7,079.0 Spacer Pipe; 7,066.0 GAS LIFT; 7,068.6 Tubing Leak; 7,070.0 Upper Packer; 7,062.0 GAS LIFT; 6,347.9 GAS LIFT; 5,662.4 GAS LIFT; 4,488.6 SURFACE; 31.2-3,249.0 GAS LIFT; 2,398.4 SAFETY VLV; 1,944.2 CONDUCTOR; 28.0-80.0 HANGER; 27.5 KUP PROD ... Legal Wellname 1E-07 Common Wellname1E-07A AK All Wellbores Schem STATE OF ALASKA RECEIVED •ASKA OIL AND GAS CONSERVATION COISSION REPORT OF SUNDRY WELL OPERATIONS APR 1 1 2018 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Op ati s n 111Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ ChaAkjiJ aawm ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Patch Q 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhllllps Alaska, Inc. DevelopmentEx ❑ Exploratory ry ❑ 211-062-0 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service ❑ 6.API Number: 99510 50-029-20495-01 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1E-07A ADL0025651 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10,898 feet Plugs measured None feet true vertical 6,242 feet Junk measured None feet Effective Depth measured 8,953 feet Packer measured)63,7079,7684,77 feet true vertical 6,457 feet true vertical)75,5085,5490,55 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 52 feet 15 " 80' MD SURFACE 3,218 feet 9 3/4 " 3,249' MD PRODUCTION 9,258 feet 9II 9,289' MD j JEWELERY TYPI MD spth MD&TVD feet Composite Tubing(size,grade,measured and true vertical depth) 3.5" K-55 8,916' MD 6,428'TVD Packers and SSSV(type,measured and true vertical depth) UPPER PACKER- UPPER 2.72" PARA 7,063' MD 5,075'TVD LOWER PACKER-2.72" PARAGON 2 7,079' MD 5,085'TVD UPPER PACKER- UPPER PARAGON 7,684' MD 5,490'TVD LOWER PACKER-2.72" PARAGON III 7,711' MD 5,510'TVD SAFETY VLV-CAMCO TRDP-IA-ENC 1,944' MD 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 Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Name: Jan Byrne/Kelly Lyons Authorized Name: Jan Byrne Contact Email: N1617@conocophillips.com Authorized Title: Well Integrity Supervisor Authorized Signature: 9c.--,. ! , ( C� Date: 4/4/18 Contact Phone: 907-659-7224 VT_1 4/2411; ,A. 01,// RBDMSIC APR 1 12018 Form 10-404 Revised 4/2017 Submit Original Only • • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 4th, 2018 Commissioner Hollis S. French Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner French: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well KRU 1E-07A (PTD 211-062) for tubing patch repair. If you need additional information, please contact us at your convenience. Sincerely, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM 1 E-07A • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 1E-07A failed a TIFL on 3-21-18 after which dignostics culminated in a LDL locating at leak at 7070'. A 17', 2.72" retrievable patch was set across the tubing leak, passing MITs were acquired and the well was BOL. The pertinent work is copied below. 03/21/18 (WC) MITOA PASSED TO 1800 PSI. TIFL FAILED. Initial T/I/O/OO =250/1150/1200/30. IA FL @ 4277'211' above (Sta#2 OV @ 4488') OA FL NS. Bled OOA to 0 psi in 4 minutes. Bled OA to 750 psi in 2 minutes SI couple times for breakout. T/I/O/OO = 250/1125/750/12. Pressured OA to 1800 psi with 36 gallons. T/I/O/OO = 250/1125/1800/12. 15 min T/I/O/OO=250/1125/1760/13 (-40 psi). 30 min T/I/O/OO = 250/1125/1740/13 (-20 psi). 45 min T/I/O/OO = 250/1125/1735/13 (-5 psi). Bled OA to 600 psi in 5 minutes. SI WH @ WV double block lift gas @ manifold bldg. Stack T x IA in 20 min T/I/O/OO = 1240/1230/700/15. IA FL @ 4096' 181' inflow. T FL @ 3944' Bled IA 40 minutes to T/I/O/OO = 1370/740/650/18 IA FL 4106' T FL @ 3900'. 15 min T/I/O/OO= 1420/900/650/18 (+160 psi) IA FL @ 3934' 172' inflow T FL @ same. 30 min T/I/O/OO = 1440/970/625/18 (+ 70 psi) IA FL @ 4251' 317' outflow T FL @ 4303'. Final T/I/O/OO = 1440/970/625/18. 03/30/18 SET 3"A.P TEST TOOL IN UPPER PACKER @ 7670' RKB. PERFORM LDL FROM 7670' RKB TO SURFACE, OBSERVED TBG LEAK @ 7070' RKB. ATTEMPT TO PULL DV @ 7069' RKB. IN PROGRESS. 04/02/18 SET LOWER 2.72" PIIP PACKER WITH AGGRESSIVE SLIPS MID ELEMENT©7080.7' RKB. CMIT TBG x IA 2500 PSI ( PASS )ATTEMPT TO SET UPPER 2.72" PIIP PATCH ASSEMBLY, UNSUCCESSFUL SET. PULLED UPPER PATCH ASSEMBLY. IN PROGRESS. BEGIN CMIT. INITIAL T/I/O/OO/FL 360/310/800/26/200 LRS PT TBG/IA TO 2500 PSI W/3.4 BBLS DSL START=2800/2550/810/26/200 15 MIN =2740/2510/825/29/200 30 MIN = 2730/2495/825/29/200 04/03/18 WITH MAXFIRE! SET UPPER 2.72" PARAGON 2 PACKER, SPACER PIPE & LATCH SEAL MID ELEMENT @ 7062.58' RKB. SET TEST TOOL IN UPPER PACKER @ SAME. MITT TO 2500 (PASS). CMIT TO 2500 (PASS). JOB COMPLETE. MITT TO 2500. PRE T/I/O= 500/150/775. PSI UP w/0.9 BBLS. START=2500/200/775 15 MIN= 2350/200/775 **FAIL** BUMP UP w/0.3 BBLS START=2525/225/775 15 MIN= 2500/225/775 30 MIN=2500/225/775 ***PASS*** CMIT TO 2500. PRE T/I/O=2475/270/775 START=2625/2500/800 15 MIN=2625/2475/800 30 MIN=2625/2475/800 • ,E-07A S DESCRIPTION OF WORK COMPLETED SUMMARY KUP PROD • 1E-07A ConocoPhiIIips Well Attributes Max Angle&MD TD Op Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Alaska,Inc. . 500292049501 KUPARUK RIVER UNIT PROD 106.01 9,150.52 10,900.0 - al Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) '1 Rig Release Date ... SSSV:TRDP 60 11/10/2014 Last WO: 2/8/1992 39.49 10/13/1980 DEVIATED-1E-07A,4/6/2018 1.30:35 PM Last Tag Vertical schematic(actual) Annotation Depth(RKB) End Date Last Mod By _ Last Tag:RKB 8,953.0 3/25/2018 jhansen8 HANGER;27.5 *1_lil■ Last Rev Reason It'll Annotation End Date Last Mod By Rev Reason:Install new patch 4/6/2018 famaj "MIL Casing Strings v- - h.CONDUCTOR;28.0-800• r N"��Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.060 28.0 80.0 80.0 65.00 H-40 WELDED SAFETY VLV;1,944.2 ,,_X( Casing Description OD(in) ID(In) Top(RKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.950 31.2 3,249.0 2,679.2 45.50 K-55 BTC - Casing Description OD(in) ID lin) Top(ftKB) Set Depth(RKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 31.7 9,289.3 6,399.9 26.00 K-55 BTC GAS LIFT;2,3984 y - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE;31.2-32460 WINDOWAL2-01 7 6.000 8,876.0 8,883.0 6,404.5 26.00 K-55 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread WINDOWA 7 6.000 8,892.0 8,899.0 6,416.5 26.00 K-55 GAS LIFT;4.488.6 Casing Description OD(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread LINERA 23/8 1.995 9,429.1 10,900.0 4.70 L-80 STL Liner Details GAS LIFT;5,662.4 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;6,347.9 3. 9,429.1 6,371.3 102.52 BILLET LINER TOP ANCHORED ALUMINUM BILLET - 1.995 9,572.2 6,339.3 102.65 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.995 Upper Packer;7,062.6 IF GAS LIFT;7.068.6 Tubing Strings tring Spacer Pipe 8latch seal; � Tubing Description SMa...ID lin) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection 7'064.7 �' TUBING 1 31/2_ 2.992 27.5 8,555.2 6,145.7 9.20 J-55 AB MOD-BTC Lower Packer;7,078.7 P:, Completion Details Top(ND) Top Incl Nominal UPPER PACKER;7,684.0 - ,-M1 Top(RKB) (91(13) (°) Item Des Com ID(in) -yr{ 27.5 27.5 0.00 HANGER FMC GEN I RETROFIT HANGER 3.500 GAS LIFT;7,693.61 I 1,944.2 1,790.5 45.83 SAFETY VLV CAMCO TRDP-IA-ENC SAFETY VALVE 2.812 SPACER PIPE PIPE r SNAP I LATCH;7,688.0 8,467.7 6,076.7 38.32 NIPPLE OTIS X SELECTIVE LANDING NIPPLE 2.813 (�i 8,506.1 6,106.8 37.92 PBR BAKER PBR w/10'STROKE 3.000 LOWER PACKER;7,711.0 __ 8,519.8 6,117.6 37.75 PACKER BAKER HB RETRIEVABLE PACKER 2.890 8,533.0 6,128.1 37.59 SBR BAKER G-SEAL SBR w/OTIS PROFILE STABBE INTO 2.813 GAS LIFT;8,452.8 EXISTING SLICK STICK IN ORIGINAL COMPLETION Tubing Description String Ma...ID(in) Top(RKB) Set Depth(ft..'Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection NIPPLE;8.467.7 TUBING Original 31/2 2.920 8,554.3 8,917.9 6,429.0 9.20 K-55 FL4S Completion Details Top(ND) Top Incl Nominal Top(RKB) (RKB) Cl Item Des Com ID(in) PBR;8,5060 8,554.3 6,145.0 37.32 SLICK STICK 3.000 PACKER;8,519.88,559.3 6,149.0 37.26 PACKER BAKER HB-1 PACKER 2.890 711 8,673.5 6,240.2 37.30 BLAST RINGS CARBIDE BLAST RING(6)ID=2.867" 2.920 SBR;9,633.0 8,876.3 6,399.4 40.48 LOCATOR BAKER LOCATOR SUB 3.000 ij SLICK STICK;8,554.3 ;. 8,877.2 6,400.1 40.51 PACKER BAKER FB-1 PACKER 4.000 PACKER;8,559.3 - 8,879.7 6,402.0 40.59 SBE BAKER SEAL BORE EXTENSION 2.813 8,899.7 6,417.0 44.39 NIPPLE .CAMCO D NIPPLE NO GO,MILLED OUT T02.80,5/12/2011 2.800 • PRODUCTION;8,598.1 8,916.3 6,428.0 51.69 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl PRODUCTION;8,667.2 IP Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 7,062.6 5,075.0 51.25 Upper Packer Upper 2.72"Paragon 2 packer(SN:CPP35149)(OAL 4/3/2018 1.625 OF UPPER PATCH ASSEMBLY=20'/MIN ID=1.60") MID ELEMENT @ 7062.58 - PRODUCTION;8,860.1 7,064.7 5,076.4 51.25 Spacer Pipe& 14'X 2 1/16"SPACER PIPE&LATCH SEAL 4/3/2018 1.600 latch seal ASSEMBLY(CPAL35069)1.6"ID 7,078.7 5,085.1 51.25 Lower Packer 2.72"PARAGON 2 LOWER PACKER WITH 4/2/2018 1.625 AGGRESSIVE SLIPS(SN:CPP35139/4.01"OAL/ LOCATOR;9,e76.3 f i 1.625"ID)MID ELEMENT @ 7080.7 PACKER;8,877.2 5 WHIPSTOCK 8676.0fir, 7,684.0. 5,490.2 44.12 UPPER UPPER PARAGON II PACKER[CPP350541,MIN ID- 3/2/2016 1.620 58E;8,879.7 13 PACKER 1.62",@7,684'(Mid Element),OAL=4' WINDOW AL2-01;8.876.0-S 8,883.0 -j; 7,688.0 5,493.1 44.09 SPACER PIPE SPACER PIPE,ANCHOR LATCH SEAL ASSY 3/2/2016 1.620 • PIPE 8.SNAP [CPAL35022];MIN ID-1.62",OAL-23) I LATCH is 7,711.0 5,509.6 43.95 LOWER 2.72"PARAGON II PACKER(SER#CPP35051),ID- 3/2/2016 1.620 WHIPSTOCK;0,e92.0 f PACKER 1.62",OAL-4'@7,711'(Mid Element) WINDOW A 6.892.0-B,e95.0 . 8,876.0 6,399.2 40.47 WHIPSTOCK 3.5 MONOBORE RETRIEVABLE FLOW-THRU 6/23/2011 0.000 a WHIPSTOCK NIPPLE;8,899.7 I 8,892.0 6,411.3 40.99 WHIPSTOCK 3.5 MONOBORE RETRIEVABLE FLOW-THRU 6/12/2011 0.000 SOS;8616.3 = WHIPSTOCK Perforations&Slots I r Shot Dens MB) Top(TVD) Btm(TVD) (shots/ft (ftKB) Btm B) (RKB) (RKB) Zone Date I Type Corn 9,439.9' 9,571.7 6,368.9 6,339.4 6/19/2011 32.0 SLOTS Alternating solid/slotted pipe -0.125'X2.5"@4 circumferential adjacent rows,3"centers staggered SLOTS;9,171.1-10,363.9- 18 deg,3'non-slotted ends . ..g.- PRODUCTION;31.75,289.3 UM SLOTS;9227.9-10,857.0 9,573.0 10,899.6 6,339.16/1912011 32.0 SLOTS LINER AL2-01;8,872.0-11,090.0 Mandrel Inserts LINER AL1;8,892.6-10,857.0 1•- St SLOTS;9,439.9-9,571.7 , ati on Top(ND) Valve Latch Port Size TRO Run k Ni, Top(ftKB) (RKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,398.4 2,106.9 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,174.0 1/31/2016 11:00 SLOTS;9673.0.10699.6 2 4,488.6 3,421.7 CAMCO KBUG 1 GAS LIFT OV BK 0.188 0.0 3/26/2018 9:00 • 3 5,662.4 4,172.0 CAMCO KBUG 1 GAS LIFT DMY BTM 0.250 1,408.0 5/7/2011 '12:30 LINER A 9,429.1-10,900.0 1—\\ - o(5) 2 RLGEIVED M i 2-Ger MAR 2 9 2016 WELL LOG TRANSMITTAL#903118426 AOGCC To: Alaska Oil and Gas Conservation Comm. March 21, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED .44/t /201Ce Anchorage, Alaska 99501 K.BENDER RE: Multi Finger Caliper(MFC) and Leak Detect Log: 1E-07A Run Date: 2/10/2016 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 1E-07A Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20495-01 Leak Detect Log 1 Color Log 50-029-20495-01 SCANWELI Multi Finger Caliper log 1 Color Log 50-029-20495-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / / A4ga.icL, , � / • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well Re-enter Susp Well r Other: Tubing patch pi 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 211-062-0 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-20495-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025651 KRU 1 E-07A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10898 feet Plugs(measured) None true vertical 6242 feet Junk(measured) None Effective Depth measured 10898 feet Packer(measured) 8520 true vertical 6242 feet (true vertical) 6118 Casing Length Size MD TVD Burst Collapse CONDUCTOR 52 16 80 80' SURFACE 3218 10.75 3249 2679' PRODUCTION 9258 7 9289 6400' RECEIVED MAR 1 1 2016 Perforation depth: Measured depth: Slotted liner from 9440'-10,898' True Vertical Depth: Slotted liner from 6369'-6242' AOGCC Tubing(size,grade,MD,and TVD) 3.5",J-55, 8555 MD,6146 TVD 27' SOS retrievable patch set from 7684'-7711' Packers&SSSV(type,MD,and ND) SAFETY VLV-CAMCO TRDP-IA-ENC SAFETY VALVE @ 1944 MD and 1791 TVD PACKER-BAKER HB RETRIEVABLE PACKER @ 8520 MD and 6118 TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations pr Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil I Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Brent Rogers/Kelly Lyons Email: N 1617(C�conocophillips.com Printed Name :ent Roger Title: Problem Well Supervisor Signature / Phone:659-7224 Date 03/09/16 / / i 3/10' /1 l- Form 10-404 Revised 5/2015 A iktAi RBDMS LL MAR 1 1 2016 Submit Original Only • • Nov ConocoPhillips RECEIVED Alaska P.O. BOX 100360 MAR 1 1 2016 ANCHORAGE,ALASKA 99510-0360 AOGGC March 9, 2016 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 1E-07A (PTD 211-062-0) for a retrievable tubing patch set in the tubing above the packer. Please call Kelly Lyons or myself at 659-7224 or Dusty Freeborn/Jan Byrne at 659-7126 if you have any questions. Sincerely, Brent Rogers Problem Well Supervisor Attachments • S a 1 E-07A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/01/16 PERFORMED BRUSH AND FLUSH IN PATCH SET INTERVAL FROM 7600-7750' RKB WHILE LRS PUMPED 25 BBLS DIESEL. SET 2.72" PIIP @ 7110' RKB (MID ELEMENT). SET TEST TOOL IN SAME. ***DURING CMIT TxIA, PACKER SHIFTED DOWNHOLE APPROX 14'.*** PULLED 2.72" PIIP FROM TBG. *JOB IN PROGRESS 03/02/16 SET 2.72" PARAGON II PACKER IN TBG @ 7711' RKB (MID ELEMENT). SET TEST TOOL IN SAME. LRS PERFORMED PASSING CMIT TxIA TO 2500#. PULLED TEST TOOL&SET UPPER PATCH ASSEMBLY @ 7684.4' RKB (MID ELEMENT). SET TEST TOOL IN TOP OF PATCH. LRS PERFORMED PASSING MIT-T TO 2500#.PULLED TEST TOOL. *JOB COMPLETE CMIT TxIA passed. Initial T/I/0=750/400/200. Start CMIT T/I/0=2525/2175/200, 15 min T/I/0=2525/2150/200, 30 min T/I/0=2500/2140/200, 45 min T/I/0=2475/2125/200. Bumped back up, restart CMIT T/I/0=2600/2250/200, 15 min T/I/0=2600/2250/200, 30 min T/I/0=2600/2250/200. MITT passed. Initial T/I/0=750/450/200. Start MITT T/I/0=2575/475/200, 15 min T/I/0=2450/475/200, 30 min T/I/0=2425/475/200. 03/08/16 (AC EVAL)TIFL (PASS). Initial T/I/O/OOA=275/1200/647/28 control line 3450 psi IA FL @ 4360' 128' above OV @ 4488'. Double block lift gas at manifold bldg SI well @ WV.BIed NL line. Stack T x IA for 20 min T/I/O/OOA= 1280/1220/618/0. Bled IA 30 min T/I/O/OOA= 1390/615/541/6 .Shot IA FL @ 4467'. 15 min monitor T/I/O/OOA= 1410/615/522/10. 30 min monitor T/I/O/OOA= 1425/615/505/11 Shot IA FL @ 4467'. 45 min monitor T/I/O/OOA= 1450/615/493/11. 60 min monitor T/I/O/OOA= 1450/615/480/13 Shot IA FL @ 4467'. Final T/I/O/OOA= 1450/615/480/13. Summary A 27' (element to element) Statewide Oilfield Services retrievable patch was set in the tubing to repair a tubing leak @ 7700'. The TIFL passed following the patch set showing a successful repair. ✓ KUP PROD 1E-07A ConocoPhillips Well AttributesMax Angle&K M)D TD ' Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(") MD(ftKB) Act Blm(ftKB) __c.ocoar+mg":' 500292049501 KUPARUK RIVER UNIT PROD 106.01 9,150.52 10,900.0 ... Comment 112S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date DEVIATED-1E-07A,3/6/2016 2'.19:01 PM SSSV:TRDP 60 11/10/2014 Last WO: 2/8/1992 39.49 10/13/1980 Vertical schematic(actual) Annotation Depth ORB) End Date Annotation Last Mod By End Date --- -- - - - _. •••Last Tag: Rev Reason:SET PLUG,GLV C/O,SET PATCH pproven 3/6/2016 lt 'HANGER 275 '***-` (I!:j Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread I CONDUCTOR 16 15.060 28.0 80.0 80.0 65.00 H-40 WELDED isimmuummemaxwelauxeutweeo um,Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread � SURFACE 10 3/4 9.950 31.2 3,249.0 2,679.2 45.50 K-55 BTC ��coNDUCTOR;280-809- r Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 31.7 9,289.3 6,399.9 26.00 K-55 BTC SAFETY VLV;1,944.2t.TIP, Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) •Set Depth(TVD)...Wt/Len(I...Grade Tap Thread MWINDOW AL2-01 7 6.000 8,876.0 8,883.0 6,404.5 26.00 K-55 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread _ WINDOWA 7 6.000 8,892.0 8,899.0 6,416.5 26.00 K-55 GAS LIFT;2,398.4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE;31.2-3,249.0 • K i LINER A 2 3/8 1.995 9,429.1 10,900.0 4.70 L-80 STL Liner Details Nominal ID GAS LIFT;4,488.6 Li. - Top(kKB) Top(TVD)(ftKB) Top Incl 7) Item Des Com (in) • 9,429.1 6,371.3 102.52 BILLET LINER TOP ANCHORED ALUMINUM BILLET 1.995 9,572.2 6,339.3 102.65 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.995 GAS LIFT;5,662.4 Tubing Strings GAS LIFT;6,347.0 Tubing Description (String Ma...I ID(in) (Top(ftKB) I Set Depth(ft..f Set Depth(TVD)(...I Wt(lb/ft) !Grade 'Top Connection TUBING 3 1/2 2.992 27.5 8,555 2 6,145 7 9.20.1-55 AB MOD-BTC GAS LIFT;7,068.6 Completion Details Nominal ID N, s Top(ftKB) 'Top(ND)(ftKB) Top Incl(°) Item Des Com (in) PATCH;7,670.5 27,5 27.5 0.00 HANGER FMC GEN I RETROFIT HANGER 3.500 GAS LIFT;7,693.6 I I 1,944.2 1,790.5 45.83 SAFETY VLV CAMCO TRDP-1A-ENC SAFETY VALVE 2.812 8,467.7, 6,076.7 38.32 NIPPLE OTIS X SELECTIVE LANDING NIPPLE 2.813 8,506.1 6,106.8 37.92 PBR BAKER PBR w/10'STROKE 3.000 PACKER;7,709.0 _e_� 8,519.8 6,117.6- 37.75 PACKER BAKER HB RETRIEVABLE PACKER 2.890 8,533.0 6,128.1 37.59 SBR BAKER G-SEAL SBR w/OTIS PROFILE STABBE INTO 2.813 EXISTING SLICK STICK IN ORIGINAL COMPLETION GAS LIFT;8,452.8 Tubing Description 'String Ma...I ID(in) I Top(ftKB) I Set Depth(ft..lSet Depth(TVD)(...I Wt(Ib/ft) (Grade (Top Connection NIPPLE;8,467.7 TUBING Original 3 1/21 2.920 8,554.3 8,917.91 6,429.0 9.20 K-55 FL4S Completion Details Nominal ID III Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Sent Des Com (in) PER;8,508.0 8,554.3 6,145.0 37.32 SLICK STICK ' 3.000 PACKER;8,519.8ild 8,559.3 6,149.0 37.26 PACKER BAKER HB-1 PACKER 2.890 J 8,673.5 6,240.2 37.30 BLAST RINGS CARBIDE BLAST RING(6)ID=2.867" 2.920 SBR;8,533.0 1 [ 8,876.3- 6,399.4 40.48 LOCATOR BAKER LOCATOR SUB 3.000 SLICK STICK;5554,3 '�, 8,877.2 6,400.1 40.51 PACKER BAKER FB-1 PACKER 4.000 PACKER;8,559,3 .`' 8,879.7 6,402.0 40.59 SBE BAKER SEAL BORE EXTENSION 2.813 8,899.7 6,417.0 44.39 NIPPLE CAMCO D NIPPLE NO GO,MILLED OUT TO 2.80, 2.800 BK(2011 PRODUCTION;8,598.1 8,916.3 6,428.0 51.69 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PRODUCTION;8,667.2 Top(ND) Top Incl Top(ftKB) (ftKB) ("1 Des Com Run Dale ID(i n) 7,670.5 5,480.5 44.22 PATCH UPPER PATCH ASSY(PARAGON II PACKER 3/2/2016 1.620 [CPP35054],SPACER PIPE,ANCHOR LATCH SEAL ASSY[CPAL35022];MIN ID-1.62",OAL-27') PRODUCTION;8,860.1 @7,684'(Mid Element) 7,709.0 5,508.2 43.96 PACKER 2.72"PARAGON II PACKER(SER#CPP35051,ID- 3/2/2016 1.620 1.62",OAL-4')@7,711'(Mid Element) LOCATOR;8,876.3 11, ,' 8,876.0 6,399.2 40.47 WHIPSTOCK 3.5 MONOBORE RETRIEVABLE FLOW-THRU 6/23/2011 0.000 PACKER;8,877.21WHIPSTOCK WHIPSTOCK 8,876.0, 8,892.0 6,411.3 40.99 WHIPSTOCK 3.5 MONOBORE RETRIEVABLE FLOW-THRU 6/12/2011 0.000 SBE;8,879.7 ;. WHIPSTOCK WINDOW AL2-01;8,876.0-, 4 5883.0 :A r Perforations&Slots Shot Dens �' Top(ND) Btm(TVD) (shots/f WHIPSTOCK;8,892.0 ;. Top(MB) Btm(ftKB) (ftKB) (ftKB) Zone Data t) Type Com 9,439.9 9,571.7 6,366.9 6,339.4 6/19/2011 32.0 SLOTS Altemating solid/slotted WINDOW A;8,892.0-8,899.0 , pipe-0.125"x2.5"@4 circumferential adjacent NIPPLE;5899.7 rows,3"centers I staggered 18 deg,3'non SOS;5916.3 -ill I- -slotted ends I 9,573.0 10,899.6 6,339.1 6/19/2011 32.0 SLOTS Mandrel Inserts St ae on Top(ND) Valve Latch Port Size TRO Run ll N Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com II 1 2,398.4 2,106.9 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,174.0 1/31/2016 11:00 2 4,488.6 3,421.7 CAMCO KBUG 1 GAS LIFT OV BK 0.188 0.0 1/30/2016 9:00 SLOTS;9,171.1-10,363.9 PRODUCTION;31.7-9,289.3, -. •-• 3 5,662.4 4,172.0 CAMCO KBUG 1 GAS LIFT DMY BTM 0.250 1,408.0 5/7/2011 12:30 SLOTS;9,227.9-10,857.01 4 6,347.9 4,620.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.250 0.0 5/7/2011 7:00 LINER AL2-01;6,872.0-11,090.0 LINER AL1;8,892.6-10,857.0• 5 7,068.6 5,078.8 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 2/8/1992 1:00 SLOTS;9/309-9,571.7 6 7,693.6 5,497.1 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 2)8/1992 6:00 7 8,452.8 6,064.9 OTIS LBX 1 1/2 GAS LIFT DMY RM 0.000 0.0 2/25/2016 1:00 [� 8 8,598.1 6,180.0 CAMCO KBUG 1 PROD OPEN 0.000 0.0 5/22/2011 14 9 8,667.2 6,235.2 CAMCO KBUG 1 PROD DMY None 0.000 0.0 2/25/1992 Close SLOTS;9,573.0-10,899.6 _ d , 1 8,860.1 6,387.0 CAMCO KBUG 1 PROD OPEN 0.000 0.0 5/17/2011 0 LINER A;9,429.1-10,800.0 • KUP PROD 1E-07A ConocoPhillips Alaska,Inc. �xowrmpc DEVIATED-1E-07A,31612016 2'.19'.03 PM Vertical schematic(actual) HANGER',27.5 II-1,..11 Notes:General&Safety End Date Annotation 7(16)2011 NOTE:WELL SIDETRACKED w/LATERALS AL1,AL2,AL2-01 . A°°'2/2/2015 NOTE:IA X OA COMMUNICATION MA-CONDUCTOR;28.0-80A- SAFETY VLV;1,944.2 �-s") GAS LIFT;2,398.4 vi S 31.2-3,249.0 111 GAS LIFT;4,488.6 GAS LIFT;5,662.4 GAS LIFT;6,347.9 GAS LIFT;7,068.6 PATCH;7,670.5 7 1114 II GAS LIFT;7,693.6 PACKER;7,709.0 GAS LIFT;8,452.8 } NIPPLE;8,467.7 PER;8,506.0 PACKER;8,519.8 SBR;8,533.0 - SLICK STICK;8,554.3 PACKER;8,559.3 PRODUCTION;8,598.1 PRODUCTION;8,6672 � . PRODUCTION;8,860.1 111 a LOCATOR;8,876.3 4. ', PACKER;8,877.2 WHIPSTOCK;8,876.0, SBE;8,879.7 ' WINDOW AL2-01;8,876.0-� 8,883.0 WHIPSTOCK;8,892.0 WINDOW A;8,892.0-8,899.0 NIPPLE;8,899.7 I SOS;8,9162 - - MI III 111 SLOTS;9,171.1-10263.9 ME MN PRODUCTION;31.7-9,289.3� SLOTS;9,227.9-10,857.0 LINER AL2-01;8,872.0-11,090.0 N LINER AL1;8,892.6-10,857.0 SLOTS;9,439.9-9,571.7 ■ SLOTS;9,573.0-10,899.6 1111 LINER A;9,429.1-10,900.0 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable b direct inspection of the file. ,i I_ - O7 Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RES N: OVERSIZED: NOTES: Color Items: ❑ Ma s: 1'Grayscale Items: Logs: ❑ Poor Quality Originals: D Other: ❑ Other: BY: dE10 Date: 7/11/IL1. /s/ M P Project Proofing BY: AM Date: /s/ V4f Scanning Preparation I x 30 = 3 O + 17 = TOTAL PAGES 4 ,1 1 (Count does not include cover sh t) BY: WM Date: /s/ V Production Scanning L� Stage 1 Page Count from Scanned File: ✓^O (Count does include cover eet) Page Count Matches Number in Scanning Preparation: YES NO BY: - Date: ft/ 11 fii,i. /s/ W1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO jIJIJ BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michel Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc o c 9 I WI o O J a as o� c� o) U 1 Z ilti m 4, cc ce EY dU u a o d C7 C7 a > j a a (��to �, E w C a E5 0 a d U a c a) 2 o 2 2 U i.au Z o U 0 0 0 Q ur W F- I— a m o a m _ ‘•-•0 0 > 1....J 0 d 0 O O O O N N EL-) co o y N N N N Q p re ca a T a) m ZJ 0O Co 00 CO C Cl)To O — a) = C C C C c C E y Q Y O U 0 0 0 0 0 0 o Tel Ce a 2 CO U O N j co 2O coo 0ra co co co co 0o co Co 0co 03 00 00o d N Z Z JU a ," N O O O O O O Q CU M (;) "y W D:: d t + N N (N N Oto N Z 0 0 00 M 0 0 U CO CO0CO Co CO CO C•' W z a > O J m a) U 0O aa)) a) Z 7 0 CC o Q Z I-- 0 y V) o 0 T Ea N o ZI UJ U U un WI • r D n d O LO Q a) co I E Q J f) f) I N ' n U � 0 as E u) J a Q 0 W Q 0 5r I— co 0 MCN I m CI) CC Q Y• o 0 oI Q p Q Z >_ �`` Q z oo > > > > E JU 03 = CL CL Ct (I ) z m To C C C C C m a) 3 g g o o o • v IEO > > > a 2 i O CV CO re CA z 0 0 z a) ccsi oo j O 2 41 E co ° <a m V .� E c tea/ a cu N 2 0 0 o W 0 Z ai O } d Ocu Ce F_ (0 0. a) LL (. > i 0 aa Z +� En . \ , JCO Q =' z a C'in -o N O W Z W p 0 \ 1 p 0 O N > I rpy F= U vi >_0 a y J _ U _ a aa) 0 CI F- p, N 0143 Q O O O 0 Q O u 0 cO L C a) O a R' 0 H 3 3 0 H J J J W CC W a > 0 <IX 0 U t 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION I WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development E Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ Z'Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: July 5,2011 211-062/ G 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 June 13,2011 50-029-20495-01 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 893'FSL,631'FEL,Sec. 16,T11N,R10E,UM June 17,2011 1E-07A Top of Productive Horizon: 8. KB(ft above MSL): 39'RKB 15.Field/Pool(s): 1730'FNL, 965'FEL,Sec. 15,T11N, R10E,UM GL(ft above MSL): 105.5'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD):4 24 R 2484'FSL, 707'FEL,Sec. 15,T11N,R10E,UM 10898'MD/272 rVD ju Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 4 x.i A 16.Property Designation: Surface: x-549889 y- 5960480 Zone-4 10898'MD/.2'TVD 40 ADL 25651 TPI: x-554811 y- 5963171 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-555079 y- 5962107 Zone-4 1944'MD/1791'TVD 469 18.Directional Survey: Yes ❑✓ No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1650'MD/1570'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MDITVD GR/Res 8892'MD/6411'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 65# H-40 Surf. 80' Surf. 80' 24" 200 sx Permafrost 10.75" 45.5# K-55 Surf. 3249' Surf. 2678' 13.75" 1500 sx Fondu,350 sx AS 7" 26.0# K-55 Surf. 9289' Surf. 6697' 8.75" 315 sx Class G ` 2.375" 4.7# L-80 9429' 10898' 6371' 6272' 3" slotted liner ✓ 24.Open to production or injection? Yes ❑✓ No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 8916' 8519'MD/6116'TVD, slotted liner 559'MD/6149'TVD,8877'MD/6400'TV 9440'-10898'MD 6369'-6272'TVD - )�pLET--- ' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. LODEPTH INTERVAL( MD) AMOUNT AND KIND OF MATERIAL USED ilk; i 9010'MD sand plug 9010'-8609' cement 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) July 11,2011 gas lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 7/11/2011 18 hours Test Period--> 595 1029 3641 176 Bean 1963 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 189 psi 1245 24-Hour Rate-> 724 1420 4761 23 deg 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ 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. NONE F :.a 3s." ReDMSJUL 2 71011 11, (.ii f3ii.s r,Fst a t➢ftfs. : s rililission Form 10-407 Revised 12/2009 CONTINUED ON REVERSE9 t� .5-.4 Submit original only � / G 28. GEOLOGIC MARKERS(List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? 0 Yes Q 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 1650' 1570' needed,and submit detailed test information per 20 AAC 25.071. top B shale 8904' 6419' top B shale/base Cl 9230' 6411' top Cl /base C2 9360' 6386' top C2/base C3 9632' 6326' top C3/base C4 9771' 6300' N/A Formation at total depth: Kuparuk C4 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Long @ 263-4093 ila51►I Printed Nam L.G ntt Title: CTD Engineering Supervisor I Signature 1( Phone 263-4021 Date 7/2-5`/7 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 12/2009 ' '-.1.Z a. KUP 1 E-07A Iv- ConOCOPhilli 03 , y Well Attributes .Max Angle&MD TD T ',", Wellbore APVUWI Field Name Well Status Incl(") IMO(ftKB) Act Btm(RKB) Al`' ''Inc" [1xx+cnPIaINVs i% 500292049501 KUPARUK RIVER UNIT PROD 106 01 9,150 52 10,900.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "- SSSV:TRIP1 80 9/15/2010 Last WOE 2/8/1992 39.49 10/13/1980 -"" Scnerne0c ygial . Annotation Depth(ftKB) End Date AnnotationLast Mod..End Dab Last Tag:RKB 1 ,9,034.0 5/14/2011 Rev Reason:ADD LATERALS,GLV 0/0 ninam 7/16/2011 Casing Strings r Casing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(7VD)...String Wt. String...String Top Thrd HANGER,28------- i, LINER A_ -.. 23/8 1995 1...9,429.1 I 10,9000 4.70 L80 STL Liner DetailsI Top Depth (ND) Top Incl Noml... . Top(ryl(g) (RKB) (ry Re/n Deselp6on Comment 10(in) CONDUCTOR, . 9,429.1 6,371.3 102.52 BILLET UNER TOP ANCHORED ALUMINUM BILLET 1.995 0-80 9,572.1 6,339.7 103.44 DEPLOY SHORTY DEPLOYMENT SLEEVE SAFETY VLV, —__ Perforations&Slots 1.944 - -.._ _ _.. --- Shot Top(TVD) Btm(TVD) Dens Top(RKB)Ben(EKE) (ftKB) (RKB) Zone Dab (sh... Type Comment GAS LIFT, n-_.!' 9,440 9,572 6,368.9 6,339.8 6/19/2011 32.0 SLOTS Alternating solid/slotted pipe- 2,398 0.125-x2.5"@ 4 circumferential SURFACE, adjacent rows,3"centers staggered 31-3,249 ; 18 deg,3'non-slotted ends 9,5731 10,900 6,339.5 6/19/2011 32.0 SLOTS GAS LIFT, _ 4,489 �F. GAS LIFT, i - 5,662 t GAS LIFT, 6,348 GAS LIFT.____....... - 7,069 I'. lir GAS LIFT, 7,694 GAS LIFT, 8,463 f NIPPLE,8,468— tA L PBR,8,506- - L 1 PACKER,8,520 SBR,8,5331 SLICK STICK ___{1 8,554 tk PRODUCTION, 8,598 F.1. PRODUCTION,PRODUCTION, 8,667 a 88,832ii, /PERF,_. - ' 8,66 IPERF,�_ ` 8,855-8,860 -cps.E. .. PRODUCTION. _ .. 8,860 LOCATOR. 8,876 PACKER,8.877 IPERF, 8,877-8,882 _ WHIPSTOCK, 8,876 SBE,8,880 - " _""' Mandrel Details_ , Top Dpthlop __.. Pod (PERF, (TVD) OD Valve Latch Size TRO Run 8,892-8,897 Stn Top(RKB5 (RKB) (`) Make Model (in) Sery TYPO Type 0n) (psi) Run Date Can... NIPPLE,8,900 _._ WHIPSTOCK, .., ':. . . 1 2,398.4 2,106.9 4525 CAMCO KBUG 1 GAS UFT OV BK 0.250 0.0 7/9/2011 8P \\u\ '�V 2 4,488.6 3,421.6 54.55 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,308.0 7/9/2011 Cementg, t 8,614 PRODUCTION, 3 5,662.4 4,171.9 47.81 CAMCO KBUG 1 GAS LIFT DMY BTM 0.250 1,408.0 5/7/2011 32-5,298 4 6,347.9 4,620.2 50.00 CAMCO KBUG 1 GAS UFT DMY BK 0.250 0.0 5/7/2011 5 7,068.6 5,078.9 51.33 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 2/8/1992 SLOTS, 6 7,693.6 5,497.1 44.03 CAMCO KBUG 1 GAS LIFT DMY BK-2 0.000 0.0 2/8/1992 9,4409,572 7 8,452.8 6,065.1 38.59 OTIS 1.8X 1 12 GAS LIFT DMY RM 0.000 0.0 1/3/2000 SLOTS, 8 8,598.1 6,180.0 36.74 CAMCO KBUG 1 PROD OPEN 0.000 0.0 5/22/2011 9.573-10.900 - 9 8,667.2 6,235.2 37.34 CAMCO KBUG 1 PROD DMY None 0.000 0.0 2/25/1992 Closed LINER A, 9,429-10.900 10 8,860.1 6,386.9 40.45 CAMCO KBUG 1 PROD OPEN 0.000 0.0 5/17/2011 10,900 N Cf —C:7AoC�5 ,U W m ro Q'-'02- c rg a- in m ,..! 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CO CO CO CO U 7 7 C > Zr-' N N N N N N N N - I- O CO fO a) O O O) O co a) u) (O .-' _ 7.-, C 13 M R CO ILO N- CO Cr, CO n anti CO a, L 10 Ian (co CO r-- 1-- - N. iris L >ft- w eL icier0 Y Y AMMO U i •� h r- N- 0 CO n 10 (D N CO CO O (6 N O O C) N CO IO CO N 0) In 10 C d a O 7 O W W W C °� Li U Y Y n CO rn o o i Cr, rn O < (j V li ± - O 00 O N I- N 0 0 4 N CO CO (0 O Oj C T .. 0 O O O 10 a, O OD oi C i) 0 V. co_ r n co coOm co co S 0 nr - _ O. Q O) 0 O O O O O O O N } oO O .0.. d d y a w 0 d U, 0 (0 Conoco Phillips Time Log & Summary We!Mew Web Reporting Report Well Name: 1 E-07 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 6/10/2011 6:00:00 PM Rig Release: 7/6/2011 12:00:00 AM Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 06/09/2011 24 hr Summary Complete reel swap&wire pressure Bulk head. RDMO 2K-13.***Exempt rig move to 1E-07.*** 00:00 06:00 6.00 MIRU MOVE MOB P Continue MOB off 2K-13-Complete injector skate change and roll chains. Plumb inner reel iron, R/U and stab coil. 06:00 12:00 6.00 MIRU MOVE MOB P Make up Pressure bulk head&rig down BOP&Managed pressure lines. Peak trucks dispatched at noon. 12:00 00:00 12.00 MIRU MOVE MOB P Off Hi-line power at noon. Peak trucks arrived at 14:00 hrs.Start moving rig from 2K-13 to 1E-07. ***Exempt rig move*** 06/10/2011 Spot Rig over well, MIRU,Start BOPE Test.Waived by Matt Herrera,AOGCC 00:00 04:00 4.00 0 0 MIRU MOVE MOB P Move onto 1E-pad 04:00 10:00 6.00 0 0 MIRU MOVE PRLO T Wait on wellhouse removal&pad prep due to high winds 20 MPH& ASRC weekly safety meeting. 10:00 13:00 3.00 0 0 MIRU MOVE PRLO T Remove Wellhouse-Wind down to 11 MPH. Remove cellar grating and grade pad to tree. 13:00 15:00 2.00 0 0 MIRU MOVE MOB P Spot rig over well&pit module 15:00 18:00 3.00 0 0 MIRU MOVE MOB P Install containment in cellar-Start rigging up hard lines and BOP stack. External CT grapple-pull test to 20K 18:00 22:00 4.00 0 0 MIRU WHDBO NUND P Crew change, PJSM,Start Nipple up BOPE,Open SSV and install fusable cap Scaffold crew rig up scaffold/TT rigged up. Pull Lubricator and change 0-rings Accept Rig @ 18:00 22:00 23:00 1.00 0 0 MIRU WHDBO SFTY P Hold Pre Spud Meeting 23:00 00:00 1.00 0 0 MIRU WHDBO BOPE P PJSM,Start BOPE Test 06/11/2011 Complete BOPE test,Swap out wing valves, Perform slack mgmt,M/U Coil Connector&BHA#1, RIH to mill / ik cement / 00:00 01:00 1.00 0 0 MIRU WHDBO BOPE P Continue BOPE Test.T-2 failed initial test. Continue with testing. 01:00 03:00 2.00 0 0 MIRU WHDBO BOPE T Trouble shoot leak Tango valves not holding,continue with test 03:00 06:00 3.00 0 0 MIRU WHDBO BOPE P Continue BOPE Test,Callout valve crew Page 1 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 07:30 1.50 0 0 MIRU WHDBO BOPE P BOPE test Low 250-High 3500psi. Test all rig alarms. 07:30 08:00 0.50 0 0 MIRU WHDBO BOPE P BOPE testing 08:00 09:00 1.00 0 0 MIRU WHDBO SEQP T Valve crew arived-re-grease T-2& T-1.Valve stem failed on T-1 while testing T-2. Both valves need replacing. 09:00 11:00 2.00 0 0 MIRU WHDBO BOPE P Continue with BOPE testing on the rest of the stack. BOPE test completed minus inner reel valve& T1,T2. 11:00 12:00 1.00 0 0 MIRU WHDBO CTOP P Clean up rig floor&skid injector over well. Blow stack dry.Swap to Hi-line power 12:00 14:00 2.00 0 0 MIRU WHDBO SEQP T PJSM-Double isolate Tango valves. Remove MPD line&start removing the 3.08"T1 &T2 valves. 14:00 15:30 1.50 0 0 MIRU WHDBO CTOP P Start reverse circulating CT,fill coil. Pump slack back into reel. Pressure test inner reel valve&pack-off to 4000 psi. Continue installing Tango 1 &Tango 2 valves. 15:30 16:30 1.00 0 0 MIRU WHDBO PRTS P Pressure test PDL&tiger tank lines to 1500 psi. 16:30 17:00 0.50 0 0 MIRU WHDBO BOPE P Final BOP test on T-1,T-2,&MPD line connection. Low 250-High 3500 psi.Good. 17:00 18:00 1.00 0 0 MIRU WHDBO BOPE P Pull BPV. 18:00 19:00 1.00 0 0 SURPRI UREAM CTOP P Clear rig floor, Pack out pipe samples,Cut coil to find wire post slack mgmt.Cut 19'to find wire, cut 28'total. 19:00 20:00 1.00 0 0 SURPRI UREAM CTOP P Trouble shoot wire went to back up wire in PUTZ,all good with back up. Dress coil and install connector, Pull test to 35K 20:00 21:30 1.50 0 0 SURPRI UREAM CTOP P BHI Heading up upper quick connect PT 4K PSI 21:30 23:00 1.50 0 77 SURPRI UREAM PULD P PJSM,M/U BHA#1 2.73PDC Mill, Hailey Under reamer,Weatherford straight motor,20'joint,Coiltrack tool 23:00 00:00 1.00 77 2,588 SURPRI UREAM TRIP P RIH 06/12/2011 RIH and underream cement 8879 to 8930, Run Dummy whipstock to 8930, Run whipstock,Set TOWS@8892,Start OOH 00:00 01:45 1.75 2,588 8,560 SURPRI UREAM TRIP P Continue in well to Underream cement 01:45 02:00 0.25 8,560 8,628 SURPRI UREAM DLOG P Start tie in pass,Tie into K-1 marker for a+19, Corrected from 8609 Page 2 of 19 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 02:00 02:24 0.40 8,628 8,879 SURPRI UREAM TRIP P Trip in to tag TOC,CC Locator 55' from bit,Tag TOC @ 8879, PUH pumps on 1.5 BPM @ 3120PSI FS,WHP 80PSI,Going to TT PUW=38K 02:24 03:48 1.40 8,879 8,930 SURPRI UREAM REAM P 8878 tag up with pumps on,start reaming down, 1.5-2FPH Getting cement on shaker 03:48 04:42 0.90 8,930 8,700 SURPRI UREAM REAM P 8930', Ream up, PUW=38.5,didn't see any evidence of nipple, Bring rate up to 1.6@3970PSI. Looking for nipple 04:42 05:00 0.30 8,700 8,930 SURPRI UREAM DLOG P 8700', RIH for CCL log lower production mandrel, Log Mandrel @ 8852 vs 8847 reported MD Vs 8860 on original tally Have enough rathole under TT,within 1'of PDC Log 05:00 05:24 0.40 8,930 8,830 SURPRI UREAM TRIP P PUH while checking log 05:24 07:54 2.50 8,830 77 SURPRI UREAM TRIP P Open EDC and POOH 07:54 09:24 1.50 77 0 SURPRI UREAM PULD P Shut down pumps 100'from surface. PJSM-flow check-no flow.Close SSSV and lay down U/R BHA. Break down BHA. 09:24 10:24 1.00 0 0 PROD1 RPEQP1SVRG P Service injector, reel&replace Reel swivel.-Retest to 4300psi. Make up Dummy WS. 10:24 11:48 1.40 0 71 PROD1 RPEQP1PULD P P/U BHA run#2.Make up injector& Open SSSV 11:48 14:00 2.20 71 8,930 PROD1 RPEQP1TRIP P RIH EDC closed,pumping Bio fluid 1 bpm.Tie in @ 8560'+11ft correction. RIH-lower pumps to.2 bpm to tag TD. Down 1.7K on bit. 14:00 14:45 0.75 8,930 8,910 PROD1 RPEQP1CIRC P P/U 40 ft.CT weight 44K.-Circulate flo-pro down to bit-RIH to 8910' pumping 1.7 bpm. 14:45 17:00 2.25 8,910 71 PROD1 RPEQP1TRIP P POOH pumping Flo-Pro pumping 1.7 bpm. Light cement cutting to surface during trip to surface. 17:00 18:00 1.00 71 0 PROD1 RPEQP1PULD P PJSM for breaking off bha- flow-check-No flow. 18:00 19:30 1.50 0 71 PROD1 RPEQP1PULD P_Crew change, PJSM P/U Lower Whipstock BHA#3.Confirm no kick pad on tray,Make up to coil track and surface test,Tag up and set counters. RA 6'from TOWS 19:30 21:54 2.40 71 8,550 PROD1 RPEQPITRIP P RIH with whipstock, EDC confirmed Open 21:54 22:09 0.25 8,550 8,581 PROD1 RPEQPI DLOG P Log Gamma tie in, +12'correction (8593.64) 22:09 22:21 0.20 8,581 8,870 PROD1 RPEQP1TRIP P Trip into setting depth,8892'TOWS, 8901.65 Bit depth 8870 Close EDC, PUW=38K, RIH to set depth Page 3 of 19 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 22:21 22:30 0.15 8,870 8,902 PROD1 RPEQP1WPST P At set depth,Orientation HS, Kick pumps on,tool shifted @ 4100PSI, Set down 2.5K. TOWS 8892 22:30 00:00 1.50 8,902 3,244 PROD1 RPEQP1TRIP P POOH, PUW=37.5K, 3244 Midnight depth 06/13/2011 First window run Mill 3.5"exit 8892.7 to 8898,Start 2nd mill run to exit 7"@ 8898.5 00:00 00:45 0.75 3,244 71 PROD1 RPEQP1TRIP P PJSM-No Flo Check. 00:45 01:15 0.50 71 0 PROD1 RPEQP1PULD P Lay down BHA#3 whipstock setting BHA 01:15 02:15 1.00 0 73 PROD1 WHPST PULD P M/U BHA#4,Whipstock milling run, .6 degree motor. First window run M/U to coil track,Surface test tools, Tag up and set counters Confirm wear pad turned inside 02:15 04:51 2.60 73 8,565 PROD1 WHPST TRIP P RIH, BHA#4.6 degree motor first window run, EDC Shut Pw k 04:51 05:03 0.20 8,565 8,584 PROD1 WHPST DLOG P Log tie in for+14', New depth 8598.15 05:03 05:15 0.20 8,584 8,892 PROD1 WHPST TRIP P Trip in to dry tag whipstock 8892, PUH and bring pumps online PUW=37.5K 05:15 07:45 2.50 8,892 - 8,894 PROD1-WHPST MILL P PUH 10'Bring pumps online 1.5 BPM @ 3600PSI FS . / RIW=16K.Start milling pinch point V 8892.7'. ,!(.„✓ Stall @ 8893.7'Light metal shavings over shaker. 07:45 12:15 4.50 8,894 8,895 PROD1 WHPST MILL P 1.50 bpm,3780, BHP 4100, ROP 1fph,WOB 2K,CT weight 16K. Start Auto drill @ 8894.50'.Metal returns over shaker. 12:15 15:15 3.00 8,895 8,898 PROD1 WHPST MILL P WOB decrease-8895.3'. Increase ROP to 1.3 fph. Light metal shaving in returns,with a trace of cement. Second WOB decrease @ 8897.3' more defined WOB drop. Light metal shavings and light cement/sand returns.Continue milling 6ft from TOWS. 15:15 16:15 1.00 8,898 8,898 PROD1 WHPST REAM P Make 2 reaming passes&1 dry run- clean. 16:15 18:00 1.75 8,898 73 PROD1 WHPST TRIP P POOH for Second Stage BHA 18:00 19:30 1.50 73 0 PROD1 WHPST PULD P PJSM,At surface, Flo check well. Lay down BHA#4 Window mill 2.80 go,2.79 No Go String Mill 2.80 Go,2.79 No go. Observed light rotational markings on motor bit box 19:30 20:36 1.10 0 74 PROD1 WHPST PULD P M/U BHA#5,2.80 Fat radius mill on 2.0 degree fixed bend Weatherford motor with kick pad removed,M/U to coil track and surface test.Tag up and set counters 20:36 22:51 2.25 74 8,565 PROD1 WHPST TRIP P Trip in with BHA#5 Window milling 7"exit Page 4 of 19 Time Logs Date From To Dur S.Depth E.Deot_h Phase Code Subcode T Comment 22:51 23:03 0.20 8,565 8,598 PROD1 WHPST DLOG P Log Gamma tie in, +13.5 23:03 23:18 0.25 8,598 8,899 PROD1 WHPST TRIP P RIH and dry tag whipstock @ 8899, PUH 10 feet and bring pumps online PUW=37K, 1.43 BPM @ 3650PSI FS, RIW=16.5 23:18 00:00 0.70 8,899 8,899 PROD1 WHPST MILL P Observe Motor work @ 8898.5 Start time drilling per schedule 8898.7 Midnight drpth 06/14/2011 Completed window milling operations,drill build section to 9190' 00:00 03:15 3.25 8,899 8,902 PROD1 WHPST MILL P Continue milling 7"casing exit per milling schedule 03:15 05:15 2.00 8,902 8,903 PROD1 WHPST MILL P Weight drop to zero,calling 7" casing exit 1.44 BPM @ 3650 PSI FS 9.6'down from TOWS Looking for formation in sample. Light formation in samples during time milling. 05:15 06:15 1.00 8,903 8,920 PROD1 WHPST MILL P Increase ROP to 6 fph&WOB 1.5K for additional 17'. 06:15 07:45 1.50 8,920 8,920 PROD1 WHPST REAM P Back ream as per procedure from 8918-8892'.Clean.Trap WHP-Dry run @ 10 fpm.Clean no weight bobbles.Open EDC 07:45 11:00 3.25 8,920 99 PROD1 WHPST TRIP P POOH with EDC open holding MPD. 11:00 13:00 2.00 99 0 PROD1 WHPST PULD P 500'from surface hold PJSM,Tag up and space down, PUD BHA#5 13:00 13:48 0.80 0 0 PROD1 DRILL CTOP P M/U nozzle,jet BOP stack / 13:48 15:48 2.00 0 62 PROD1 DRILL PULD P M/U build section BHA#6 with 2.3 AKO setting, PD,make up to coil and surface test.tag up and set counters 15:48 18:18 2.50 62 8,550 PROD1 DRILL TRIP P RIH 18:18 18:36 0.30 8,550 8,585 PROD1 DRILL DLOG P Tie in,+18' 18:36 18:54 0.30 8,585 8,920 PROD1 DRILL TRIP P Continue RIH,close EDC,34K PUW, 17K RIW 18:54 22:54 4.00 8,920 9,070 PROD1 DRILL DRLG P Drilling, 1.4 BPM, 3000 CTP,3890 BHP 22:54 23:18 0.40 9,070 9,070 PROD1 DRILL WPRT P Wiper to window 23:18 00:00 0.70 9,070 9,098 PROD1 DRILL DRLG P Continue drilling, 1.5 BPM,3200 CTP, 3930 BHP 06/15/2011 Drilled build to 9190'. Tripped for BHA. Drilled lateral to 9493' 00:00 02:06 2.10 9,098 9,190 PROD1 DRILL DRLG P Continue drilling, 1.5 BPM,3200 CTP,3930 BHP 02:06 05:06 3.00 9,190 83 PROD1 DRILL TRIP P POOH, 05:06 10:30 5.40 83 72 PROD1 DRILL PULD P PJSM,Tag Up, PUD BHA#6,Crew change, Continue with BHA swap, M/U BHA#7 with .9 degree motor and 2.7 X 3"Bi Center bit, PD and surface test,Tag up and reset counters Page 5 of 19 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 06/15/2011 24 hr Summary Drilled build to 9190'. Tripped for BHA. Drilled lateral to 9493' 10:30 12:30 2.00 72 8,560 PROD1 DRILL TRIP P RIH 12:30 12:42 0.20 8,560 8,595 PROD1 DRILL DLOG P Gamma tie into K-1 for+13' 12:42 12:57 0.25 8,595 8,930 PROD1 DRILL TRIP P Trip in to log RA,Close EDC 12:57 13:03 0.10 8,930 8,938 PROD1 DRILL DLOG P Log RA @ 8898,TOWS @ 8892 13:03 13:18 0.25 8,938 9,190 PROD1 DRILL TRIP P Trip in to drill 13:18 18:48 5.50 9,190 9,340 PROD1 DRILL DRLG P 9190', Drill ahead 1.42 BPM @ 3000PSI FS, RIW=15K BHP=4421 18:48 19:48 1.00 9,340 9,340 PROD1 DRILL DLOG P Mad pass, 19:48 23:18 3.50 9,340 9,490 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM,3200 CTP,3934 BHP, 23:18 00:00 0.70 9,490 9,493 PROD1 DRILL WPRT P Wiper to window,34K PUW, 16K RIW 06/16/2011 Drilled lateral to 10240'. 00:00 03:30 3.50 9,493 9,640 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM, 3100 CTP,3910 BHP, 03:30 04:24 0.90 8,960 9,640 PROD1 DRILL WPRT P Wiper trip with Tie In, PUW=33K Tie In for no correction, 04:24 09:24 5.00 9,640 9,790 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM, 3100 CTP,3915 BHP, 09:24 10:24 1.00 9,790 9,790 PROD1 DRILL WPRT P Wipe to window, PUW=32K BHP=4517, ECD=12.3 10:24 13:00 2.60 9,790 9,872 PROD1 DRILL DRLG P 9790', Drill ahead 1.4 BPM @ 3270 PSI FS RIW=14.1 K, BHP=4587 13:00 15:30 2.50 9,872 9,940 PROD1 DRILL DRLG P BHA Wiper,Stacking out, PUW=43K, Drill ahead 15:30 17:00 1.50 9,940 9,940 PROD1 DRILL WPRT P 9940',wiper to window, PUW=40K Clean wiper out and in 17:00 19:30 2.50 9,940 10,090 PROD1 DRILL DRLG P 9940', Drill ahead 1.41 BPM @ 3200PSI FS BHP=4485 19:30 20:18 0.80 10,090 8,920 PROD1 DRILL WPRT P Wiper to window,33K PUW 20:18 20:30 0.20 8,920 8,950 PROD1 DRILL DLOG P Tie-in,-4' 20:30 21:12 0.70 8,950 10,090 PROD1 DRILL WPRT P Wiper back in hole, 17K RIW 21:12 23:30 2.30 10,090 10,240 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM,3330 CTP,4000 BHP, 23:30 00:00 0.50 10,240 10,240 PROD1 DRILL WPRT P Wiper to window,33K PUW,4K over pull at 10013' Tie in for-5'correction,Wipe to bottom 06/17/2011 Drilled lateral to 10759'. 00:00 01:06 1.10 10,240 10,240 PROD1 DRILL WPRT P Wiper to window, 33K PUW 01:06 01:42 0.60 10,240 10,307 PROD1 DRILL DRLG P drilling ahead, 1.4 BPM,3440 CTP, 4000 BHP, Page 6 of 19 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 01:42 03:24 1.70 10,307 10,307 PROD1 DRILL WPRT P Started losing some returns, .3 BPM. Very sticky on bottom,43K PUW. Wiper to window. 4K overpull at 10013' 03:24 03:30 0.10 10,307 10,311 PROD1 DRILL DRLG P On bottom, 1.4 BPM in,3400 CTP, 3900 BHP As WOB increasess the return rate drops to.7 BPM and BHP drops as well Pulling 50K off bottom increased rate to 1.56 BPM,3750 CTP 03:30 04:48 1.30 10,311 10,314 PROD1 DRILL DRLG P P/U and work pipe. Having hard time getting drilling.50 to 53K pulls off bottom returns falling off 04:48 07:03 2.25 10,314 10,460 PROD1 DRILL DRLG P Bust through and take off drilling 100-140 FPH 1.5 BPM @ 3776 PSI FS 07:03 09:57 2.90 10,460 10,460 PROD1 DRILL WPRT P Wiper to window with tie in for-10' correction Pulled heavy by 10311-10314,set down @ 10303,Adj TF and go through Swap Mud 09:57 14:12 4.25 10,460 10,610 PROD1 DRILL DRLG P 10460, Drill Ahead 1.4 BPM @ 3365 BHP=4505, RIW 7.4K w/1.5K WOB 14:12 16:27 2.25 10,610 10,610 PROD1 DRILL WPRT P Wiper trip to window, PUW=37K Slight over pull in 10300 area smoth on way in 16:27 23:03 6.60 10,610 10,759 PROD1 DRILL DRLG P 10610',drill ahead 1.4 BPM @ 3335 PSI FS BHP=4508. Loosing.2BPM 23:03 00:00 0.95 10,759 10,759 PROD1 DRILL WPRT P Wiper to window 06/18/2011 TD well at W00',preformed long wiper to surface, layed in liner running pill and KWF to surface, PU 40 joints of slotted liner. 00:00 01:12 1.20 10,759 10,759 PROD1 DRILL WPRT P Wiper trip back inhole 01:12 04:24 3.20 10,759 10,900 PROD1 DRILL DRLG P 1.4 BPM,3300 CTP,4011 BHP, 04:24 07:54 3.50 10,900 85 PROD1 DRILL WPRT P TD at 10900', Low/High vis sweeps and wiper to the sawb valve,31K PUW 07:54 10:24 2.50 85 72 PROD1 DRILL WPRT P Tag stuffing box, reset counters, Run back to bottom 10:24 10:36 0.20 72 8,565 PROD1 DRILL DLOG P Log gamma tie in for+12 10:36 12:12 1.60 8,565 10,898 PROD1 DRILL WPRT P Continue wiper to bottom 12:12 15:30 3.30 10,898 98 PROD1 DRILL TRIP P POOH laying in Beaded liner pill in KWF,then KWF to surface Paint EOP @ 9400&7400 15:30 17:15 1.75 98 0 PROD1 DRILL PULD P Tag up, PJSM while flo checking well, Pull tools out of well,blow down , Lay down 17:15 17:30 0.25 0 0 PROD1 DRILL BOPE P Function test BOPE 17:30 18:00 0.50 0 0 COMPZ CASING PUTB P Rig up floor for liner operations Page 7 of 19 • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 18:00 18:30 0.50 0 0 COMPZ CASING SFTY P PJSM for liner operations and crew changeout 18:30 19:12 0.70 0 0 COMPZ CASING PUTB P Complete RU for liner operations, hole fill was less than one Bbls. 19:12 22:00 2.80 0 1,372 COMPZ CASING PUTB P PU guide shoe,40 joints slotted liner,deployment sleeve and Coiltrak liner running BHA. Safety joint drill after joint#10, 22:00 22:42 0.70 1,372 1,371 COMPZ CASING SVRG P Maintain injector 22:42 23:06 0.40 1,371 -1,371 COMPZ CASING PUTB P MU injector to well 23:06 00:00 0.90 1,371 4,000 COMPZ CASING RUNL P RIH 06/19/2011 Ran liner and anchored billet in"A"lateral. Started drilling off billet at 9427'. Lost 220 Bbls of 11.9 KWF during all liner operations and displacements 00:00 01:42 1.70 4,000 10,899 COMPZ CASING RUNL P Continue to RIH with liner,correct depth at flag, +12'. 34K PUW,20K RIW 01:42 03:42 2.00 10,899 0 COMPZ CASING RUNL P Tag bottom at 10899',bump at 1.5 BPM 4300 CTP to rlease from liner. POOH 03:42 06:06 2.40 0 204 COMPZ CASING PUTB P Lay down liner running BHA, PU guide shoe,4 joints slotted liner and anchored billet. MU coiltrack BHA. Surface test tool 06:06 08:36 2.50 204 8,695 COMPZ CASING RUNL P RIH with EDC open 08:36 08:42 0.10 8,695 8,728 COMPZ CASING DLOG P Log Gamma Tie in for+13 08:42 09:18 0.60 8,728 9,572 COMPZ CASING RUNL P RIH to 8845, PUW=35K, RIW=20.3K,Close EDC RIH and tag TOL @ 9572, PUH to 31K and set anchor @ 190 RHS.Good indication of set.Tool shifted @ 2800 PSI, POOH pumping down backside. Lost 56 BBIs on trip in.Top Liner top billet @ 9429 09:18 11:54 2.60 9,572 100 COMPZ CASING RUNL P POOH 11:54 13:24 1.50 100 0 COMPZ CASING PULD P PJSM,Tag up and flo check well, Lay down Billet running tool 13:24 14:00 0.60 0 72 PROD2 STK PULD P M/U Drill By/Lateral BHA#10, .9 degree motor and Bi Center bit M/U to coil track and surface test. Open EDC 14:00 16:30 2.50 72 8,563 PROD2 STK TRIP P RIH 16.07AL- 16:30 16:42 0.20 8,563 8,590 PROD2 STK DLOG P Log Gamma Tie, +11 16:42 17:03 0.35 8,590 8,870 PROD2 STK TRIP P RIH to circulate out KWF. 17:03 18:00 0.95 8,870 8,870 PROD2 STK CIRC P Attempt to recover KWF,Start off @ .3 BPM, BHP=3775. Minimal returns 18:00 18:24 0.40 8,870 8,870 PROD2 STK SFTY P PJSM and crew changeout 18:24 18:48 0.40 8,870 9,427 PROD2 STK TRIP P RIH,dry tag at 9427' 18:48 19:48 1.00 9,427 9,427 PROD2 STK KOST P Time drill billet startina at 9426.5'. 1.4 BPM,3200 CTP,3930 BHP, 1 FPH Page 8of19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:48 00:00 4.20 9,427 9,427 PROD2 STK KOST P Stalled,clean PU and then unable to get past 9427.4'without stalling. Varied rate from 1.3 to 1.6 BPM, Multiple attempts to stop above this depth and time drill down and still stalled. 06/20/2011 Kicked off billet at 9427'and drilled lateral to 10050' 00:00 02:18 2.30 9,427 9,429 PROD2 STK KOST P Continue attempting to time drill billet,pumped 30 flo-pro pill with 3.5%lo-torq, no help. Drilled down at 90 R TF for.4',adjusted TF to 160R as we drilled ahead at 2 FPH 02:18 03:42 1.40 9,429 9,437 PROD2 STK KOST P Continue time drilling at 3 FPH. 1.5 BPM, 3300 CTP,3930 BHP. then 10 FPH for 5'then 10FPH for 2'. Backream billet then dry drift clean. 03:42 07:42 4.00 9,437 9,585 PROD2 DRILL DRLG P Drilling ahead, 1.45 BPM,3300 CTP, 3920 BHP 07:42 08:27 0.75 9,585 9,585 PROD2 DRILL WPRT P Wiper to window, PUW=32K, BHP=3935 Clean trip out and in 08:27 12:09 3.70 9,585 9,735 PROD2 DRILL DRLG P 9585, Drill ahead, 1.5 BPM @ 3414 PSI FS RIW=12.2K, BHP=3961 12:09 13:15 1.10 9,735 9,735 PROD2 DRILL WPRT P Wiper to window, PUW=34K Clean trip 13:15 17:39 4.40 9,735 9,885 PROD2 DRILL DRLG P 9735', Drill ahead, 1.4 BPM @ 3220 PSI FS RIW=12.4K, BHP=3976 17:39 18:21 0.70 9,885 8,925 PROD2 DRILL WPRT P Wiper to window 18:21 18:36 0.25 8,925 8,950 PROD2 DRILL DLOG P Tie-in,zero correction 18:36 19:06 0.50 8,950 9,885 PROD2 DRILL WPRT P Wiper back in hole 19:06 22:24 3.30 9,885 10,035 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM, 3300 CTP,3980 BHP, 12K RIW 22:24 23:36 1.20 10,035 10,035 PROD2 DRILL WPRT P Wiper to window 23:36 00:00 0.40 10,035 10,050 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3300 CTP,3980 BHP, 12K RIW 06/21/2011 Drilled AU lateral to 10751' 00:00 02:00 2.00 10,050 10,185 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3350 CTP,3990 BHP, 12K RIW 02:00 03:36 1.60 10,185 10,185 PROD2 DRILL WPRT P Wiper to the window, 33K PUW 03:36 05:48 2.20 10,185 10,335 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3350 CTP, 3990 BHP, 12K RIW 05:48 06:48 1.00 10,335 8,920 PROD2 DRILL WPRT P Wiper to window,33K PUW 06:48 07:00 0.20 8,920 8,950 PROD2 DRILL DLOG P Tie in at RA, minus 1' 07:00 07:42 0.70 8,950 10,335 PROD2 DRILL WPRT P Wiper back in hole, 16K RIW 07:42 12:18 4.60 10,335 10,485 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3350 CTP,3980 BHP, 12K RIW 12:18 14:18 2.00 10,485 10,485 PROD2 DRILL WPRT P Wiper to window,35K PUW Page 9 of 19 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 14:18 18:48 4.50 10,485 10,635 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3350 CTP,4020 BHP, 13K RIW 18:48 20:48 2.00 10,635 10,635 PROD2 DRILL WPRT P Wiper trip to window,35K PUW 20:48 23:36 2.80 10,635 10,751 PROD2 DRILL DRLG P Continue drilling, 1.4 BPM,3350 CTP,4020 BHP, 13K RIW 23:36 00:00 0.40 10,751 10,751 PROD2 DRILL WPRT P Wiper trip to window 06/22/2011 TD AL1 lateral 10900'. POOH to swab valves to condition hole. RBIH tagging TD. POOH laying in liner running pill in OH and KWF to surface. PU/MU AL1 liner. 00:00 02:00 2.00 10,751 10,751 PROD2 DRILL WPRT P Wiper trip 02:00 04:00 2.00 10,751 10,850 PROD2 DRILL DRLG P Drill Ahead 10K CTW,2K WOB, 3780 CTP,4116 BHP,WOC 04:00 06:00 2.00 10,850 10,850 PROD2 DRILL WPRT P Pump sweeps wiper trip up hole. Wait on decision from town Geo.for offical TD 06:00 07:06 1.10 10,850 10,900 PROD2 DRILL DRLG P Back on bottom to drill an additional 50', 1.4 BPM,3750 CTP,4158 BHP, 07:06 11:24 4.30 10,900 0 PROD2 DRILL WPRT P TD, Pump sweeps and POOH t0n� 11:24 14:54 3.50 0 10,900 PROD2 DRILL WPRT P RBIH, 14:54 18:09 3.25 10,900 0 PROD2 DRILL WPRT P Tag TD, lay in flo-pro liner running pill to 9000', KWF beaded pill to 8000' and KWF to surface. Paint EOP flags at 18:09 18:39 0.50 0 0 PROD2 DRILL SFTY P At surface,flow check, PJSM 18:39 19:09 0.50 0 0 PROD2 DRILL PULD P LD BHA 19:09 19:39 0.50 0 0 COMPZ CASING SVRG P Prepare to run liner 19:39 22:09 2.50 0 0 COMPZ CASING PUTB P PU/MU AL1 liner 22:09 22:39 0.50 0 0 COMPZ CASING SVRG P Service injector head 22:39 23:39 1.00 0 0 COMPZ CASING PUTB P MU coil track 23:39 00:00 0.35 0 COMPZ CASING RUNL P RIH 06/23/2011 RIH with AL1 liner. Release liner at 10857'TOL 8893'. POOH. PU/RIH whipstock BHA setting TOWS 8876'. POOH, PU/RIH milling BHA.6 AKO.Tag WS 8876.8',mill window#2 at 8876.3'-8880.1'. 00:00 01:00 1.00 4,000 8,800 COMPZ CASING RUNL P Cont. RIH with liner 01:00 01:45 0.75 8,800 10,856 COMPZ CASING RUNL P Correct to EOP flag+10.5',CT up weight 34K, Offline with pumps RIH to 10856' 01:45 02:00 0.25 10,856 10,856 COMPZ CASING RUNL P Second EOP flag+.5'correction. Continue RIH 02:00 02:15 0.25 10,856 8,545 COMPZ CASING RUNL P Release liner,CTW PUW=33.6K, PUH to tie in depth with gamma Remove liner length from depth, Cont. POOH to tie in depth. 02:15 02:21 0.10 8,545 0 COMPZ CASING DLOG P +1.5'TOL=8893.2'. 02:21 04:36 2.25 8,545 0 COMPZ CASING RUNL P POOH 04:36 04:51 0.25 0 0 COMPZ CASING OWFF P Flow check, PJSM, 04:51 05:21 0.50 0 0 COMPZ CASING PUTB P LD BHA Page 10 of 19 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:21 05:54 0.55 0 0 PROD3 RPEQP1 PULD P PU WS BHA 05:54 07:54 2.00 0 8,520 PROD3 RPEQP1TRIP P RIH with whipstock BHA 0( 07:54 08:12 0.30 8,520 8,550 PROD3 RPEQP1DLOG P Tie-in, +12' L.2 08:12 08:30 0.30 8,550 8,886 PROD3 RPEQP1TRIP P Continue RIH ?j %' 08:30 08:42 0.20 8,886 8,886 PROD3 RPEQP1 WPST P Set WS,8876 TOWS,zero deg orientation, .6 BPM,set at 3100 CTP,set down 3K 08:42 10:42 2.00 8,886 0 PROD3 RPEQP1TRIP P POOH 10:42 11:18 0.60 0 0 PROD3 RPEQP1PULD P Lay down WS running BHA 11:18 12:00 0.70 0 0 PROD3 WHPST PULD P PU window milling BHA , 12:00 12:42 0.70 0 0 PROD3 WHPST SVRG P Injector maintenence 12:42 14:54 2.20 0 8,825 PROD3 WHPST TRIP P RIH 14:54 15:12 0.30 8,825 8,850 PROD3 WHPST DLOG P Tie in to RA, +12' 15:12 16:42 1.50 8,850 8,876 PROD3 WHPST CIRC P Displace well to flo-pro 16:42 23:30 6.80 8,876 8,879 PROD3 WHPST MILL P Tag WS at 8876.8',33K PUW, 19K RIW, 1.4 BPM at 3300 CTP,3980 BHP w/WOC. Start time milling from 8876.3' 23:30 00:00 0.50 8,879 8,880 PROD3 WHPST MILL P WOB and Bore psi increase. Pop through 3"tubing,Continue milling. 17K CTW, 1.4 BPM at 3506 CTP, 3964 BHP w/WOC 06/24/2011 Mill window#2 with.6 AKO down to 8882.3', POOH, PU/RIH 2.0 AKO mill window 8882'-8886.5'plus 17'of rat hole.(8903'TD). Begin BOPE testing. (Waived by John Crisp) 00:00 00:45 0.75 8,880 8,881 PROD3 WHPST MILL P Continue milling. 17K CTW, 1.4 BPM at 3506 CTP,3964 BHP w/WOC 00:45 02:00 1.25 8,881 8,882 PROD3 WHPST MILL P WOB and Bore psi increase,then drop off.Cont. milling 18K CTW, 1.4 BPM at 3408 CTP,3966 BHP w/WOC 02:00 02:45 0.75 8,882 8,882 PROD3 WHPST MILL P 6'milled. PUH, Backream X 2 to 8874', 1 FPM.35K CTW, Drift window no pumps.Small weight bobbles at 8879'. 02:45 03:18 0.55 8,882 8,882 PROD3 WHPST MILL P Dress window 4 passes 2 down and 2 up 1 FPM. Drift window no pumps. Looks good 03:18 05:18 2.00 8,882 0 PROD3 WHPST TRIP P Open EDC, POOH 05:18 05:42 0.40 0 0 PROD3 WHPST SFTY P PJSM 05:42 09:42 4.00 0 0 PROD3 WHPST PULD P Undeploy milling BHA#13, Deploy BHA#14 09:42 11:54 2.20 0 8,550 PROD3 WHPST TRIP P RIH 11:54 12:12 0.30 8,550 8,580 PROD3 WHPST DLOG P Tie-in, +10.5' 12:12 12:42 0.50 8,580 8,882 PROD3 WHPST TRIP P Close EDC,Continue RIH, 32K PUW, 18K RIW, Dry tag at 8882.8' 12:42 19:03 6.35 8,882 8,904 PROD3 WHPST MILL P Start time milling window,1.4 BPM, 3550 CTP,3960 BHP.8886'out of 7" casing Page 11 of 19 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment • 19:03 20:33 1.50 8,904 8,904 PROD3 WHPST MILL P Backream window 15R up, 15R down,30L up, 15 down,60R up of milled TF. Drift no pumps. Looks good 20:33 23:03 2.50 8,904 0 PROD3 WHPST TRIP P POOH 23:03 23:18 0.25 0 0 PROD3 WHPST SFTY P At surface, PJSM 23:18 00:00 0.70 0 0 PROD3 WHPST PULD P Undeploy 06/25/2011 Complete BOPE testing. PU/MU/Deploy/RIH build section BHA(2.3+AKO). Drill build section 8904-8987. POOH. Undeploy BHA. 00:00 01:00 1.00 0 0 PROD3 WHPST PULD P LD Tools.2.79 No-go,2.80 go on mill 01:00 02:45 1.75 0 0 PROD3 DRILL SVRG P Flush stack,Grease tree,stack, prepare for BOP testing 02:45 12:45 10.00 0 0 PROD3 DRILL BOPE P BOP testing. AOGCC witnessing waived by John Crisp. Tested to ��1 3500 PSI with no failures. '1 ' 12:45 13:06 0.35 0 0 PROD3 DRILL SFTY P PJSM for pressure deployment 13:06 15:06 2.00 0 0 PROD3 DRILL PULD P Deploy BHA#14 for drilling build section of AL2 lateral 15:06 17:18 2.20 0 8,550 PROD3 DRILL TRIP P Circulate FW out of coil and RIH 17:18 17:33 0.25 8,550 8,550 PROD3 DRILL DLOG P Tie-in, +11'correction 17:33 17:48 0.25 8,550 8,904 PROD3 DRILL TRIP P RIH 17:48 18:18 0.50 8,904 8,955 PROD3 DRILL DRLG P Drill Ahead 18:18 18:48 0.50 8,955 8,550 PROD3 DRILL TRIP P PUH to tie into K1 and RA 18:48 19:03 0.25 8,550 8,876 PROD3 DRILL DLOG P .5'correction on K1, No correction on RA marker TOW-8876' RA marker-8882.3' BOW-8886' 19:03 19:18 0.25 8,876 8,955 PROD3 DRILL TRIP P RIH to drill 19:18 19:48 0.50 8,955 8,979 PROD3 DRILL DRLG P Drill Ahead 1.4 BPM,3500 CTP, 4066 BHP, 16K CTW,2.5K WOB 19:48 20:03 0.25 8,979 8,982 PROD3 DRILL DRLG P Ratty drilling,stacking.7K overpull. Land build section 20:03 22:33 2.50 8,982 0 PROD3 DRILL TRIP P POOH 22:33 22:48 0.25 0 0 PROD3 DRILL SFTY P At surface, PJSM 22:48 00:00 1.20 0 0 PROD3 DRILL PULD P Undeploy BHA 06/26/2011 PU/MU/Deploy/RIH Lateral Drilling Assembly(.9-AKO).Swap out mud. Drill AL2 lateral 8982'to 9760' 00:00 02:00 2.00 0 0 PROD3 DRILL PULD P PU/MU Deploy lateral BHA(.9-AKO) 02:00 04:00 2.00 72 8,550 PROD3 DRILL TRIP P RIH 04:00 04:15 0.25 8,550 8,550 PROD3 DRILL DLOG P Tie in depth to K1 correct+9.5'. RIH 04:15 06:00 1.75 8,982 9,060 PROD3 DRILL DRLG P Swap out mud, Drill Ahead, 1.37 BPM,3550 CTP,4076 BHP 06:00 08:06 2.10 9,060 9,160 PROD3 DRILL DRLG P Continue drillingahead, 1.4 BPM ,3100 CTP,3937 BHP with 130 WHP,31K PUW, 17K RIW Page 12 of 19 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 08:06 08:12 0.10 9,160 8,990 PROD3 DRILL WPRT P Wiper to the window,29K PUW 08:12 08:30 0.30 8,990 8,900 PROD3 DRILL DLOG P MAD pass 08:30 08:42 0.20 8,900 9,160 PROD3 DRILL WPRT P Wiper in hole16.5K RIW 08:42 11:30 2.80 9,160 9,310 PROD3 DRILL DRLG P Drilling, 1.4 BPM,3100 CTP,3940 BHP with 100 WHP, 16.5K RIW 11:30 12:00 0.50 9,310 9,310 PROD3 DRILL WPRT P Wiper to window, 31K PUW 12:00 14:54 2.90 9,310 9,460 PROD3 DRILL DRLG P Drilling, 1.4 BPM,3100 CTP, 3970 BHP with 120 WHP, 16.5K RIW 14:54 15:18 0.40 9,460 8,900 PROD3 DRILL WPRT P Wiper to window,31K PUW 15:18 15:30 0.20 8,900 8,930 PROD3 DRILL DLOG P Tie-in, 0 correction 15:30 15:48 0.30 8,930 9,460 PROD3 DRILL WPRT P Wiper back in hole, 17K RIW 15:48 19:00 3.20 9,460 9,610 PROD3 DRILL DRLG P Drilling, 1.4 BPM,3200 CTP,3980 BHP with 100 WHP, 16.5K RIW 19:00 20:00 1.00 9,610 9,610 PROD3 DRILL WPRT P Wiper trip to window 30K PUW 20:00 21:00 1.00 9,610 9,652 PROD3 DRILL DRLG P Drilling, 1.4 BPM,3200 CTP,3920 BHP with 90 WHP, 16.5K RIW 21:00 21:15 0.25 9,652 9,652 PROD3 DRILL WPRT P BHA Wiper 30K 21:15 23:00 1.75 9,652 9,760 PROD3 DRILL DRLG P Drilling, 1.4 BPM,3200 CTP,3920 BHP with 90 WHP, 16.5K RIW 23:00 00:00 1.00 9,760 9,760 PROD3 DRILL WPRT P Wiper Trip to window 30K CTW. 06/27/2011 Drilled AL2 Lateral 9760'to 10482. .25 BPM losses. 00:00 03:45 3.75 9,760 9,910 PROD3 DRILL DRLG P Drilling, 1.4 BPM,3200 CTP,3920 BHP with 90 WHP, 16.5K RIW 03:45 05:00 1.25 9,910 9,910 PROD3 DRILL WPRT P Wiper trip to window. 30K PUW.Tie _ in depth, No correction. RIH 05:00 08:12 3.20 9,910 10,060 PROD3 DRILL DRLG P Drilling, 1.4 BPM,3200 CTP,3970 BHP with 80 WHP, 16.5K RIW 08:12 09:36 1.40 10,060 10,060 PROD3 DRILL WPRT P Wiper to the window,31K PUW, 17K RIW / 09:36 13:00 3.40 10,060 10,210 PROD3 DRILL DRLG P Drilling, 1.3 BPM,3150 CTP,3970 ✓ BHP with 70 WHP, 15K RIW 13:00 14:30 1.50 10,210 10,210 PROD3 DRILL WPRT P Wiper to window,30K PUW 14:30 18:30 4.00 10,210 10,360 PROD3 DRILL DRLG P Drilling, 1.3 BPM,3250 CTP,3990 BHP with 30 WHP, 15K RIW 18:30 20:15 1.75 10,360 10,360 PROD3 DRILL WPRT P Wiper trip back to window,30K PUW. +2.5'correction 20:15 20:27 0.20 10,360 10,373 PROD3 DRILL DRLG P Drill Ahead, 1.3 BPM, 3350 CTP, 3990 BHP,30 WHP, 13K RIW 20:27 20:30 0.05 10,373 10,373 PROD3 DRILL WPRT P Stacked out,Weight check.34K. . RIH 20:30 23:00 2.50 10,373 10,426 PROD3 DRILL DRLG P Drill Ahead, 1.3 BPM,3350 CTP, 3990 BHP, 30 WHP, 13K RIW 23:00 00:00 1.00 10,426 10,482 PROD3 DRILL DRLG P Start losing .25 BPM-10426.5, Drill Ahead 1.. BPM in, 1.05 BPM out, 3356 CTP, 06/28/2011 Drill AL2 Lateral total 24 hour losses=277 bbls. 00:00 00:45 0.75 10,482 10,510 PROD3 DRILL DRLG P Drill Ahead, 1.3 BPM,3350 CTP, 3990 BHP,30 WHP, 13K RIW Page 13 of 19 • Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 00:45 02:45 2.00 10,510 10,510 PROD3 DRILL WPRT P Wiper trip to window,34K PUW 02:45 07:39 4.90 10,510 10,651 PROD3 DRILL DRLG P Drill Ahead, 1.3 BPM in 1.17 BPM out, 3370 CTP,4005 BHP,40 WHP, 16K RIW 07:39 08:54 1.25 10,651 10,651 PROD3 DRILL WPRT P Wiper trip to window,40K PUW. 08:54 15:09 6.25 10,651 10,810 PRODS DRILL DRLG P Drill Ahead, 1.3 BPM in 1.17 BPM out, 3370 CTP,4005 BHP,40 WHP, 16K RIW 15:09 18:00 2.85 10,810 10,810 PROD3 DRILL WPRT P Wiper trip to window,33K PUW.-8ft correction 18:00 00:00 6.00 10,810 10,933 PROD3 DRILL DRLG P Drilling ahead-1.30 bpm,3800, BHP ' 3996, ECD 12.3, ROP 40,WOB 1.1, CT weight 5K. rate out 1.1bpm. Difficult time sterring down. Slow ROP 06/29/2011 TD AL2 lateral 11,130ft.Wipe to swab valves, RIH to TD, POOH laying in liner pill followed by KWF. Lay down BHA&start P/U 50 jnts of liner.Total of 187 bbls losses for 24 hours. 00:00 01:00 1.00 10,933 10,958 PROD3 DRILL DRLG P Drilling ahead 01:00 03:30 2.50 10,958 10,958 PROD3 DRILL WPRT P Wiper trip-P/U 32K, slight drag at 10,650'.Tie in with-1ft correction. III 03:30 09:00 5.50 10,958 11,130 PROD3 DRILL DRLG P Drilling ahead-1.30 bpm,3380, BHP 4030, ECD 12.4, ROP 35,WOB 1.8, CT weight 11K, roughly 9 bbls losses per hour 09:00 12:30 3.50 11,130 0 PROD3 DRILL WPRT P TD lateral,pumped low/high sweep. POOH to swab valves. f1)130`�0 12:30 15:00 2.50 0 8,550 PROD3 DRILL WPRT P RBIH 15:00 15:15 0.25 8,550 8,550 PROD3 DRILL DLOG P Tie in depth. No correction 15:15 16:30 1.25 8,550 11,130 PROD3 DRILL WPRT P RIH 16:30 21:30 5.00 11,130 71 PROD3 DRILL TRIP P Tag, POOH laying in flo-pro with beads,follwed by 10bbrls KWF w/beads,followed by KWF to surface.Good KWF returns at 2200' -tag up and flow check at surface. 21:30 22:15 0.75 71 0 PROD3 DRILL PULD P Lay down BHA 22:15 23:00 0.75 0 0 COMPZ CASING SVRG P Service top drive&injector. Set up rig floor for running liner. 23:00 00:00 1.00 0 0 COMPZ CASING PUTB P PJSM-Start P/U 50 jnts opf slotted liner 06/30/2011 Safety Stand down from 05:00-07:00.Set liner in two runs from 11,130',anchored billet at 9372'. Swap to flo-pro.Total losses of KWF 157 bbls. P/U BHA#19 with.9 AKO&2.73"Bi-center. 00:00 01:30 1.50 0 1,663 COMPZ CASING PUTB P P/U 50 jnts of liner with shorty deployment sleeve.Change out BHI counter. 01:30 02:00 0.50 1,663 1,707 COMPZ CASING PULD P P/U Coiltrack assembly 02:00 04:45 2.75 1,707 11,130 COMPZ CASING RUNL P RIH pumping.3bpm. +21 ft correction. P/U weight 35K at window.tag bottom @ 11135'. P/U weight 50K. RIH set down 3K.start pumpng and release off GS. P/U weight 34K. Page 14 of 19 Time Logs Date From To Dur S.Deoth E.Depth Phase Code Subcode T Comment 04:45 05:00 0.25 11,130 8,800 COMPZ CASING SFTY P POOH to cased hole and shut down for safety stand down. 05:00 07:00 2.00 8,800 8,800 COMPZ CASING SFTY P Hold Safety stand down 07:00 09:30 2.50 8,800 0 COMPZ CASING RUNL P PJSM, POOH 09:30 09:45 0.25 0 0 COMPZ CASING OWFF P At surface, Flow check. PJSM. 09:45 10:15 0.50 0 0 COMPZ CASING PULD P LD BHA 10:15 11:30 1.25 0 0 COMPZ CASING PUTB P PU 2jnts slotted and 2 pup jnts with OH anchored billet. 11:30 13:15 1.75 0 0 COMPZ CASING RUNL P RIH, 13:15 13:30 0.25 0 8,650 COMPZ CASING DLOG P Tie in depth to K1, +27' 13:30 13:45 0.25 8,650 9,468 COMPZ CASING RUNL P RIH 13:45 14:00 0.25 9,468 9,468 COMPZ CASING RUNL P Set OH anchor,single slip 190R TF 4500 CTP.TOB=9372 14:00 16:30 2.50 9,468 68 COMPZ CASING RUNL P POOH swapping hole over to FLo-Pro 16:30 18:00 1.50 68 0 COMPZ CASING PULD P Undeploy BHA-crew change 18:00 19:30 1.50 0 0 COMPZ CASING SVRG P Service injector&MP choke. Weekly function test of BOPE. Make up new BHA with .9 AKO 19:30 21:00 1.50 0 72 PROD4 STK PULD P PJSM-deploy BHA#19 with .9 AKO and 2.73"Bi-center. 21:00 00:00 3.00 72 8,550 PROD4 STK TRIP P RIH following MPD,tie in at K1 =+ 48ft correction. Inspect injector counter. 07/01/2011 KOTB from 9373'with a total of 5 stalls.Clean KO,continue drilling ahead on AL2-01 lateral as planned.81 bbls loss for 24 hours. 00:00 00:30 0.50 8,550 9,373 PROD4 STK TRIP P RIH dry tag TOB @ 9373'-P/U weight 34K. 00:30 03:00 2.50 9,373 9,374 PROD4 STK KOST P KOTB as per new procedure.Time L 2._ milling-1.40 bpm,3260, BHP 3900, ECD 12, ROP.5 fph,WOB.6,CT weight 17K,rate out 1.33bpm.Al. fillings to surface. First stall at 9374'. on the first increase to.8 fph.time mill. 03:00 08:30 5.50 9,374 9,410 PROD4 STK KOST P Milling 9373.80'-Stall @ 9373.90' doing.5 fph time milling stages. P/U and set in auto drill @ 1 fph. cleaner weight transfer.did not stall. 1.40 bpm,3210, BHP 3915, ECD 12, ROP 1 fph,WOB.3K,Ct weight 18K, rate out 1.33 bpm.Continue to follow procedure.Stall 9374.13'.- Continue milling. 08:30 08:45 0.25 9,410 9,410 PROD4 STK KOST P Drift ST, looks good 08:45 09:45 1.00 9,410 9,525 PROD4 DRILL DRLG P Drill Ahead 1.4 BPM,3470 CTP, 3885 BHP, 13K CTW 09:45 10:15 0.50 9,525 9,525 PROD4 DRILL WPRT P Wiper trip back to window 31K 10:15 11:45 1.50 9,525 9,675 PROD4 DRILL DRLG P Drill Ahead 1.4 BPM, 3470 CTP, 3885 BHP, 13K CTW Page 15 of 19 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 11:45 12:30 0.75 9,675 9,675 PROD4 DRILL WPRT P Wiper trip to window 31K 12:30 13:45 1.25 9,675 9,825 PROD4 DRILL DRLG P Drill Ahead 1.4 BPM, 3470 CTP, 3885 BHP, 13K CTW 13:45 15:00 1.25 9,825 9,825 PROD4 DRILL WPRT P wiper trip to window 31K 15:00 16:15 1.25 9,825 9,975 PROD4 DRILL DRLG P Drill Ahead 1.4 BPM,3470 CTP, 3900 BHP, 13K CTW 16:15 17:30 1.25 9,975 9,975 PROD4 DRILL WPRT P Wiper trip to window,32K PUW.Tie in depth to RA marker.-10' correction 17:30 19:00 1.50 9,975 10,125 PROD4 DRILL DRLG P Drilling ahead 19:00 20:30 1.50 10,125 10,125 PROD4 DRILL WPRT P Wiper trip-P/U weight 36K 20:30 22:00 1.50 10,125 10,275 PROD4 DRILL DRLG P Drilling ahead-1.38 bpm,3500, BHP 3965, ECD 12.2, ROP 70,WOB 1.3K,Ct weight 15K. rate out 1.30 bpm. 22:00 00:00 2.00 10,275 10,275 PROD4 DRILL WPRT P Wiper trip-35K Tie in-10 ft. 07/02/2011 Drilled ahead AL2 lateral.Crossed fault @ 10,275'&encountered higher mud losses. Continue drilling ahead as planned in C-4 sands.24 hour losses=702 bbls 00:00 01:30 1.50 10,275 10,375 PROD4 DRILL DRLG P Drilling ahead-1.38 bpm,3490, BHP 4000, ECD 12.2, ROP 125,WOB 1.4K,CT weight 14, Rate out 1.30 bpm. 01:30 02:00 0.50 10,375 10,377 PROD4 DRILL DRLG P Hit fault-stall-slow ROP&fluid losses.3 bpm. P/U weight 35K. Drill ahead 2 ft and lost all returns. Heavy P/U of 47K.Work pipe a couple of times and popped free. BHA Wiper to establish returns. Losses.5-.6 bpm. 02:00 02:30 0.50 10,377 10,379 PROD4 DRILL DRLG P Try drilling-1.45 bpm,rate out.6 bpm,WOB 1K,CT weight stacking- P/U weight 43K. Pull wiper early to clean up. 02:30 03:30 1.00 10,379 8,826 PROD4 DRILL WPRT P Pump Low/High sweep.Wiper trip- t� 36K P/U. rate in 1.40 bpm, rate out .95bpm 03:30 05:00 1.50 8,826 8,826 PROD4 DRILL CIRC P Pull in cased hole open EDC.Circ. bottoms up and fix counter&roller. 1.45 bpm, Rate out 1.20 bpm, holding 50 psi on choke for BHP. Normal cuttings over shaker for 1st B/U. Cleaned up after 1.5 B/U 05:00 06:00 1.00 8,826 10,379 PROD4 DRILL WPRT P Trap pressure and close EDC. RIH& tie in at R/A marker-6'correction. RIH. 06:00 06:30 0.50 10,379 10,385 PROD4 DRILL DRLG P Drill ahead, Unable to get started, stacking. 1.4 BPM in, .75 BPM out. 3K WOB,3260 CTP. 06:30 07:00 0.50 10,385 10,385 PROD4 DRILL DRLG P Weight check 35K Clean PU, RIH cont to try and drill. 07:00 09:00 2.00 10,385 10,385 PROD4 DRILL DRLG P Cont.weight checks 35K-45AK. Attempt to drill ahead,slow drilling 09:00 09:15 0.25 10,385 10,411 PROD4 DRILL DRLG P Drill ahead, 1.4 BPM in. 1.05 BPM out. 3150 CTP, 10K CTW. Page 16 of 19 Time Logs Date From To Dur S.Death E. Depth Phase Code Subcode T Comment 09:15 09:24 0.15 10,411 10,411 PROD4 DRILL WPRT P Weight check,drop in BHP, PU to 10300'35-45K. RIH 09:24 11:24 2.00 10,411 10,525 PROD4 DRILL DRLG P Drill Ahead, 1.4 BPM in, .9 BPM out, 3131 CTP, 11K CTW 11:24 13:24 2.00 10,525 10,525 PROD4 DRILL WPRT P Wiper trip to window,33K PUW, Over Pull 13K through Fault 10485'. Tie in depth to RA marker.0 correction. RBIH 13:24 14:54 1.50 10,525 10,638 PROD4 DRILL DRLG P Drill Ahead. 1.4 in, .95 out,3224 CTP, 10K CTW, 3878 BHP 14:54 15:03 0.15 10,638 10,638 PROD4 DRILL WPRT P PU,weight check.40K. Pump 10bbrls Low/high sweep. 15:03 16:03 1.00 10,638 10,675 PROD4 DRILL DRLG P Drill Ahead, 1.36 in, .78 out,2836 CTP 16:03 18:33 2.50 10,675 10,675 PROD4 DRILL WPRT P Wiper trip to window,36K PUW,Tie in depth to RA marker,0 correction, RIH-pump HI visc pill prior to TD. 18:33 21:33 3.00 10,675 10,825 PROD4 DRILL DRLG P Drilling ahead 1.40 bpm,3400, BHP 3900, ECD 12, ROP 65,WOB 1.2, Rate out.90 bpm. Losing roughly 30 bbls/hour. 21:33 23:48 2.25 10,825 10,825 PROD4 DRILL WPRT P Wiper trip-36K-lower rates through faulted section&billet. 23:48 00:00 0.20 10,825 10,833 PROD4 DRILL DRLG P Drill ahead 07/03/2011 TD AL2-01 lateral @ 11090'Wiper trip to swab valves, RIH work through troubled fault zone.Tag TD @ 11082' POOH laying in liner pill followed by KWF.Total losses for 24 hours 668 bbls. 00:00 03:00 3.00 10,833 10,967 PROD4 DRILL DRLG P Drilling ahead-1.40 bpm,3400, BHP 3908, ECD 12.1, ROP 60,WOB 1.1, CT weight 11K, rate out.98 bpm. Returns starting dropping dro in at 10,910' to.80 bpm.Weight check 10,930- 38K. Pump hi Visc sweep. rate out slowly dropping to.7bpm.Annular 3840psi.Slow ROP. Pump Sweep. 03:00 05:30 2.50 10,967 10,967 PROD4 DRILL WPRT P Wiper trip 38K-contiuous cuttings over shaker during entire wiper trip to window.Getting slight shale returns over shaker.Slow speed POOH after billet to 10 fpm. 1.35 bpm in-1.0 bpm out. 05:30 09:00 3.50 10,967 11,067 PROD4 DRILL DRLG P Drill ahead 1.4 BPM,3426 CTP on bottom,220 psi motor work 09:00 09:45 0.75 11,067 11,067 PROD4 DRILL WPRT P Stacking,slow ROP's, pump 30 low/high sweep, PUH 500'.35K PUW 09:45 11:15 1.50 11,067 11,090 PROD4 DRILL DRLG P Drill ahead 1.4 BPM in,3218 CTP, 11:15 15:30 4.25 11,090 11,090 PROD4 DRILL WPRT P TD AL2-01 Lateral. Pump low/hioh , sweeps POOH to swab valves 15:30 17:30 2.00 11,090 200 PROD4 DRILL WPRT P RBIH 17:30 19:30 2.00 200 10,450 PROD4 DRILL TRIP P Tie in correction-10ft. RIH Page 17 of 19 Time Logs Date From To Dur S. Death E.Deoth Phase Code Subcode T Comment 19:30 20:30 1.00 10,450 10,300 PROD4 DRILL WPRT P Weight loss @ 10,388' Pumping min. rate=.7 bpm.trapped pressure, work down to 10,450'Wipe back through it at.7 bpm,overpull to 41K @ 10,410'-Wipe up to 10,300'-RIH stacking again @ 10,388'-trap more WHP-BHP 3850psi &lower pump rate to.25 bpm.-drifted through clean-RIH to 10,500'-Wipe up through.7 bpm.one more time to condition faulted/shale area.Clean. 20:30 21:30 1.00 10,300 8,888 PROD4 DRILL WPRT P Continue to wipe up to pump a B/U= 47 bbls.-cuttings steady over shaker.Wipe up to window.Cuttings cleaned up. 21:30 23:00 1.50 8,888 11,082 PROD4 DRILL TRIP P Tie in-2 ft correction. RIH-clean through trouble section.Tagged @ 11065'P/U and adjust to drill TF- clean down to hard tag of 11082'. 23:00 00:00 1.00 11,082 9,200 PROD4 DRILL TRIP P POOH laying in liner pill 18 bbl, KWF pill 12 bbls, KWF to surface. pumping.4bpm @ 45 fpm speed. Sit at 5000'to recover KWF.8 bpm returns.Start pumping diesel down CT string. 07/04/2011 Pumped KWF to surface losing roughly 16 bbls/hour of KWF. Ran AL2-01 Lower&Upper liner runs with a seal bore deployment sleeve.24 hour total fluid losses=459 bbls(420 bbls KWF). BOL 11090-TOL 8872' 00:00 03:00 3.00 9,200 72 PROD4 DRILL TRIP P POOH laying in KWE_Good KWF to sir ace at 1100'from surface. Pumping.8 bpm, returns.2bpm. 03:00 04:30 1.50 72 0 PROD4 DRILL PULD P Flow-check at surface no-flow.Well on vac. PJSM for laying down BHA. -lay down BHA-notice heavy crude on outer BHA.Start topping up well before liner run.Took 14 bbls to fill the well. Fluid swapping out with air. 04:30 05:00 0.50 0 0 COMPZ CASING SFTY P Monitor well for 10 minutes- no-flow/no pressure. PJSM for P/U liner.Top up well again 3 bbls. 05:00 06:00 1.00 0 0 COMPZ CASING PUTB P Start P/U liner 19 slotted.3 solid.36 slotted 06:00 06:30 0.50 0 0 COMPZ CASING SFTY P Crew change PJSM 06:30 08:30 2.00 0 0 COMPZ CASING PUTB P Cont running liner 08:30 09:45 1.25 1,964 8,763 COMPZ CASING RUNL P RIH 09:45 10:00 0.25 8,763 8,763 COMPZ CASING RUNL P Tie in depth to EOP flag. +19.3' correction, Record up weight 36K, RIW 20K 10:00 11:00 1.00 8,763 11,093 COMPZ CASING RUNL P RIH to TD 11:00 11:30 0.50 11,093 8,800 COMPZ CASING RUNL P Release off liner.4000 CTP, PUH to RA marker tie in.-2'correction BOL 11090' TOL 9170' Page 18 of 19 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 11:30 14:00 2.50 8,800 0 COMPZ CASING RUNL P POOH 14:00 14:15 0.25 0 0 COMPZ CASING SFTY P At surface, Flow check PJSM 14:15 15:00 0.75 0 0 COMPZ CASING PULD P LD BHA 15:00 16:00 1.00 0 0 COMPZ CASING PUTB P PU/MU upper liner.9 jnts.(solid) 16:00 18:00 2.00 0 8,830 COMPZ CASING RUNL P RIH 18:00 18:30 0.50 8,830 9,172 COMPZ CASING RUNL P Tie in correction+18 ft correction. RIH-P/U weight 9100'-36K.tag @ 9172'with 2.2K down. 18:30 19:00 0.50 9,172 8,550 COMPZ CASING RUNL P Bring pumps up to 1.5 bpm,4000 psi -P/U weight 34K-Pull up hole to K-1 marker for tie in&circ out wellbore to SW. Correction-1.5ft=TOL 8872'-BOL =11090' 19:00 22:30 3.50 8,550 48 COMPZ CASING TRIP P POOH 60 fpm pumping SW @ 1 bpm,trying to catch returns. KWF returns to surface @ 6000'. Circulate SW followed by Diesel to freeze protect from 2500'.Take returns to TT. 22:30 00:00 1.50 48 0 COMPZ CASING PULD P PJSM for undeploying.Trapped 600 psi WHP-Bled down to 360psi prior to undeploying. Undeploy BHA. lay down tools. 07/05/2011 Set BPV, N2 Reel blowdown,Change out CT String, Nipple down stack,Clean pits 00:00 02:00 2.00 0 0 DEMOB WELLPF CIRC P Set up rig floor and pits for corrossion circulation. Flush all surface lines/BOP's&CT string. 02:00 03:30 1.50 0 0 DEMOB WELLPF CIRC P Set up to pump N2.-Purge CT& Stack to Tiger tank. p' 03:30 05:30 2.00 0 0 DEMOB WELLPF SEQP P PJSM-setting BPV 05:30 15:00 9.50 0 0 DEMOB WELLPF CTOP P Blow down rig, unstab CT,secure reel&remove outer braces.Tear down injector for skate&chain swap out. Replace Gooseneck rollers. Swap out reels 15:00 17:00 2.00 0 0 DEMOB WELLPF CTOP P New reel inside rig-tighten up flanges&hard line. 17:00 21:00 4.00 0 0 DEMOB WELLPF CTOP P Install inserts on BOP's for Big hole tools prior to tearing down stack. Install new chains on injector. 21:00 00:00 3.00 DEMOB WELLPF MOB P Nipple down stack, Prep rig for mobilization to 3H-10 Rig release @ 24:00 Page 19 of 19 FCw, Letter of Transmittal ERE -,sv\ Date: iSSion BAKER July 15 20i tot*. ,�,m HUGHES `; To: From: Christine Mahnken Carl Ulrich/ Sachin Gandra AOGCC Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the lowing well(s): 1E-07A //_ 0 1 1E-07AL1 1E-07AL2 1E-07AL2-01 (4) total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Sachin Gandra, Baker Hughes Operations Engineer Sachin.Gandra@BakerHughes.com Carl.Ulrich, Baker Hughes Survey Manager Carl.Ulrich@BakerHughes.com scilErE 8 E SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMIT S SION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 V. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-07A ConocoPhillips Alaska, Inc. Permit No: 211-062 Surface Location: 893' FSL, 631' FEL, SEC. 16, T11N, R 10E, UM Bottomhole Location: 2556' FSL, 671' FEL, SEC. 15, T11N, R10E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted 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. Sincerely, Daniel T. Seamount, Jr. Chair DATED this/ b day of May, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 6, 2011 RECEIVED Commissioner- State of Alaska MAY 0 9 2011 Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oil&Gas Coln.&mission Ancnorage Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Permit to Drill (PTD) applications to drill and complete four lateral sidetracks out of Kuparuk producing well 1E-07 (PTD# 180-080). Coiled tubing drilling (CTD) operations are scheduled to begin June 1, 2011. The objective of the CTD project is to drill four lateral sidetracks (1 E-07A, 1 E-07AL1, 1 E-07AL2, and 1 E-07AL2- 01) targeting the C2, C3, and C4 sands. The laterals will be drilled from 1 E-07 via two, dual-string _window exits milled through the 3.5"tubing and the 7" casing. Two sidetracks are planned from each window. Some pre-rig wellwork is necessary to prepare the wellbore for the arrival of Nabors CDR2-AC. A Sundry application to cover this work was submitted to the State on May 3, 2011. • In conjunction with the Sundry application for 1E-07, ConocoPhillips requested a variance from 20 AAC 25.112 (c)which requires a cement plug across and above all perforations to be abandoned in cased hole wells. The proposed plugging procedure for the 1 E-07 perforations does meet the overall objective of this section, providing an equally effective plugging of the well to prevent migration of fluids to other hydrocarbon zones or freshwater. Attached to this application are the following documents: - 4 Permit to Drill Application Forms: 1 E-07A, 1 E-07AL1, 1 E-07AL2, 1 E-07AL2-01 - Summary of Planned Operations - Proposed Schematic - Directional Plans - Anti-collision Review - BOP Schematic If you have any questions or require additional information please contact me at 907-263-4093 (office) or 907- 230-7550 (cell). Sincerely, 0/00 " Jill Long Coiled Tubing Drilling Engin6er RECEIVED' STATE OF ALASKA ;ihy 9 9 2O1 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Maga Oil& Gag Cans.Commission 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Development-Oil 0• Service-Winj ❑ Single Zone 0' lc.Specify if well is proposed for: Drill ❑ Re-drill 0 Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates Cl Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 ' 1E-07A - 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 10900' • TVDSS: 6210' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:893'FSL,631'FEL,Sec. 16,T11N,R10E, UM • ADL 25651 • Kuparuk River Oil Pool ' Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1110'FNL, 1244'FEL,Sec. 15,T11N,R10E, UM 469 6/1/2011 Total Depth: 9.Acres in Property: 14.Distance to 2556'FSL,671'FEL,Sec. 15,T11N,R10E, UM 2560 Nearest Property: 18100 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL:4c' eet 15.Distance to Nearest Well Open Surface:x- 549889 ' y- 5960480• Zone- 4 GL Elevation above MSL1SD$4Qfeett to Same Pool: 1E-20,895' 16.Deviated wells: Kickoff depth: 8892• ft. 17.Maximum Anticipated Pressures"in psig(see 20 AAC 25.035) Maximum Hole Angle: 104° • deg Downhole:2680 psig • Surface:2050 psig • 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVDSS MD TVDSS (including stage data) - 3" 2.375" 4.7# L-80 ST-L 1450' 9450' 6253' 10900' 6210' slotted liner , 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) 9310' 6712' 9203' 6636' 9193' Casing Length Size Cement Volume MD TVD Conductor/Structural 16" 200 sx Permafrost 80' 80' Surface 10.75" 1500 sx Fondu,350 sx AS 3249' 2678' Intermediate Production 7" 315 sx Class G 9289' 6697' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 8686-8832',9106-9128',9138'-9175' 6250'-6365',6567'-6583',6590'-6616' 20.Attachments: Property Plat❑ BOP Sketch 0 Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Jill Long @ 263-4093 ----7-eD51D511I Printed Name 4V. Cawvey Title Alaska Wells Manager Signature �I_ Phon265-6306 Date .-/6/ // ccc999.ZUZU�,7 t L C_q u.1,1 ct/ • /Commission Use Only Permit to Drill API Number: _ j Permit Approv (�I See cover letter Number:....2_ /�.�i�� 50-c l- % li7 S-L_l`�_)Date: nal 1 X 1 1 1 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: a , 3 SOo rO S4. Rd P / S.# Samples req'd: Yes ❑;No 7 Mud log req'd: Yes ❑ No [,' Other: 4"ZS'Ov /o5.. ,Qh't w(� - 2S measures: Yes [r No ❑ Dire '-.nal svy req'd: Yes L - No Cl/ Com%„, 517/e9/// APPROVED BY THE COMMISSION DATE: • /j' ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is valid fo 'v. t$444rl�K approval(20 AAC 25.005(g)) Submit in Duplicate ` LLL...... 7/ 5'/$ f( 41„ ic, i/ P&..nit to Drill Summary of Opel.Lions KRU 1 E-07A, 1 E-07AL1, 1 E-07AL2, 1 E-07AL2-01 Well History The C-sand production in 1E-07 has decreased significantly over the past 10 years. Over the same period of rate decline, injection rates in offset injectors have remained fairly consistent leading to the conclusion that the current wellbore placement is not optimal for maximizing production. Pressure trends from the C-sand in the area support this conclusion. Therefore, the purpose of the CTD project is to increase throughput and develop the under-produced oil resource in the Kuparuk C-sand by drilling four CTD laterals away from the original 1E-07 wellbore. Prior to drilling, the perforations in the parent wellbore will be plugged off via a cement squeeze making the wellbore a dedicated C-sand only producer after the CTD sidetracks are complete. Operational Outline Pre-Rig Work 1. Changeout all gas lift valves to dummy valves. 2. Mill out the 2.75" D nipple at 8900' RKB to a 2.80" ID. 3. Cover the A-sand perforations with sand. The top of the sand will be left above the top A-sand perforation but below the tubing tail. 4. Pull the gas lift valve from mandrel#10 at 8860' RKB and leave it open. 5. Perforate the 3.5" tubing tail across from potential CTD kickoff locations. Planned kickoff points are -8876' MD and -8892' MD. 6. Place cement below the 3.5" tubing tail and between the tubing tail and the 7.0" casing. Also, using the open gas lift mandrel, place cement in the straddle packer annulus between the 3.5" tubing and the 7" casing. The top of cement will be left at the top of the C sands (-8680' MD). 7. Drift and tag the top of the cement. 8. Cleanout the cement inside the 3.5" tubing down to just above the gas lift mandrel at 8860' RKB. 9. Set BPV and prepare wellsite for rig arrival. �A CTD Procedure Overview 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Cleanout the remaining cement in the 3.5"tubing from -8860' RKB to the tubing tail. Set the lower whipstock at 8892' MD. Mill a 2.80", two-string window exit with high-side orientation. 3. 1 E-07A Lateral a. Drill 2.70" x 3" bi-center lateral in the C-sands to a TD of 10900' MD b. Load well with kill weight fluid. Run 2%" slotted liner from TD to the kickoff point for the 1E- PTP 07AL1 lateral with an anchored aluminum billet on top (9450' MD) 1k..) 4. 1 E-07AL1 Lateral a. Drill 2.70" x 3" bi-center lateral in the C-sands to a TD of 10850' MD b. Load well with kill weight fluid. Run 2%" slotted liner from TD to just inside the window with a deployment sleeve on top 5. Set the upper whipstock at-8876' MD. Mill a 2.80", single-string window exit with high-side orientation off of the upper whipstock. 6. 1 E-07AL2 Lateral a. Drill 2.70" x 3" bi-center lateral in the C-sands to a TD of 11150' MD b. Load well with kill weight fluid. Run 2%" slotted liner from TD to the kickoff point for the 1 E- 07AL2-01 lateral with an anchored aluminum billet on top (9400' MD) 7. 1 E-07AL2-01 Lateral a. Drill 2.70" x 3" bi-center lateral in the C-sands to a TD of 11150' MD b. Load well with kill weight fluid. Run 2%" slotted liner from TD to up inside the tubing with a deployment sleeve on top 8. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. Handover to Production group. Page 1 of 3 `1 5/6/2011 PTD Applications- KRI, .d-07A, 1 E-07AL1, 1 E-07AL2, 1 E•. L2-01 Operational Details Hazards - When drilling C-sand laterals in Kuparuk, lost returns are common. Significant thief zone are also possible particularly at fault crossings. - Drillsite 1E is an H2S pad. The maximum recorded H2S reading on the pad in 2010 was 130 ppm at well 1E-02 (09/15/2010). The most recent H2S reading on well 1E-07 was 80 ppm on (09/15/2010). All H2S monitoring equipment should be operational. Fluids Program - Chloride-based Biozan brine (8.6 ppg), ill be used for window milling operations. - Chloride-based Flo-Pro mud (9.2 ppg) for drilling operations. - 1 E-07 does contain a subsurface safety valve (SSSV) however, in order to maintain managed pressure on shales that will be open, completion kill weight fluid (11.8 ppg)will be used for running completions. In the event that significant losses are experienced and the hole cannot hold 11.8 ppg fluid, the SSSV may be used for running completion. Disposal - No annular injection on this well. - Class II liquids to KRU 1R Pad Class II disposal well - Class II drill solids to Grind & Inject at PBU Drill site 4 - Class I wastes will go to Pad 3 for disposal. New Completion Details Lateral Name Liner Liner Liner Liner Liner Details Top Btm Top Btm MD MD TVDSS TVDSS 1E-07A 9450 10900 6253 6210 23/", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. > 1 E-07AL1 8892 10850 6306 6254 2%" 4.7#, L-80, ST-L slotted liner; shorty deployment sleeve on top. 1 E-07AL2 9400 11150 6271 6454 23/", 4.7#, L-80, ST-L slotted liner; aluminum billet on top. r 1E-07AL2-01 8860 11150 6281 6273 ept d 4.7#, L-80, ST-L slotted liner; deployment sleeve on top. Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 65 H-40 Welded 0 80 0 80 1640 630 Surface 10%" 45.5 K-55 BTC 0 3249 0 2680 3580 2090 Casing 7" 26 K-55 BTC 0 9289 . 0 6697 4980 4330 Tubing 3'/ " 9.2 K-55 ABM-BTC 0 8917 0 6430 6990 7400 Page 2 of 3 O I G I NA L 5/6/2011 PTD Applications- KR1 -07A, 1 E-07AL1, 1 E-07AL2, Directional Planning - See attached directional plans for each of the three laterals. - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1E-07A 18100' 1 E-07AL1 18100' 1 E-07AL2 18450' 1 E-07AL2-01 18450' - Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Well 1E-07A 895' 1 E-20 1 E-07AL1 915' 1E-20 1 E-07AL2 1410' 1C-03A 1 E-07AL2-01 1410' 1C-03A Logging MWD directional, resistivity, and gamma ray will be run over the entire openhole section. Reservoir Pressure The most recent bottomhole pressure at the lower kickoff point (8892' MD/6306' TVD) is estimated to be 2680 psi (8.2 ppg EMW). This pressure estimation is based on static bottomhole pressure data acquired in January 2011. Assuming a gas gradient to surface, the maximum surface pressure anticipated is 2050 psi. An additional pressure reading is planned to take place prior to any cementing work. Well Control - Two well bore volumes (-195 bbl) of 11.8 ppg kill weight fluid will be within a short drive to the rig during drilling operations. In this situation, a "wellbore volume" is defined as the tubing volume plus the volume of the longest lateral. - BOP diagram is attached for operations with 2" coil tubing. -3500 - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3080 psi. Maximum surface pressure anticipated while sidetracking out of 1 E-07 is -2050 psi, assuming a gas gradient to surface. This maximum potential surface pressure is calculated using the expected reservoir pressure of 2680 psi based on recent pressures within the area and assuming a gas gradient of 0.1 psi/ft. - The annular preventer will be tested to 250 psi and 2500 psi. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottomhole pressure by using 9.2 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. The well will be loaded with overbalanced fluid prior to running completions. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. Page 3 of 3 INI 5/6/2011 l.,) j t L 0 � s� 0 4 a Q o a r o 0 0 uJ 0 LU:'--2-7:::1, l O W u.l I- r -r i I I I (V p 1 1 11 I I I 0°&I C I I 11 _ II N GO _E I I 1 1 II _ I t 11 I1 II p tb I I f 1 OD It O `� 11 11 d-01 O � � p 11 Cr) v ih � � O ao � � 1 1 - � � II ao o 2-6-0c o I I ii N N II N — N N N 00 I I 11 )-2- v 00 v �' Vv �1 1 I • C m ih ppp m � m p �� V It ii U Z.7311- - � E � E ).-::11 � io ii I' z - __ OO U &) O W c::;:;:,,,, 1 1 I I Q - m ' o o`oopto m a too0 ,7: I: ii - LI.I 1:DE-cc °O �� ):-2C C7N C7 �� _aiiiid N �� V0) (nIIIICC• womm _� m m C mvoa0o ZNO co . omda� m do o ooO ``\\ii �`\ iiE 4t cnri`I Y m E �` i i \` ii c ca c`? c6 H F- m U m c6 m [0 H N O L I I 11 U rn U � � ivao � 'vO O ch = C7 ' = U oU U —_rn co rn dtcorn _ _ U o _ — o. N N Nc`') V' co MOn ! N YY Y fl NDN N2tt N cf) c0 -U N `— cR `— N 9 \\ M A M M A m m m U7 m C) U M moo M m o \\\ \\ I \ \ a m n m I ii �i": „ ,, , ,..,,--,, N i iI_-1111 ;III . I ■ 1 II1I1 '"��[ Aj!t � . Ii -�. ��_ Wit.: • ,_ � ,. ���,, � �_ o la. I co " p p oN N 2 2 o 0 i N -O � C O O O Qrn rn in ::%-41 2 p ;� O O O m c_-_ 0 m C a 0 W � � M N °)cl- 6 Lo � M E � w EYE � imoo CC Y � /�� M O 00 N Co To _ W N �_ M a0 CO V co f- N d' N Q rn O) !".N N Mco co C`') a) co 1` rn ORIGINAL Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing Lubricator Riser nnular/ Blind/Shear 2" Pipe I Slip(CT) Pump into Lubricator .�\ /J L�`/� above BHA rams �� r r Choke 1 2-3/8" Pipe/Slip(BHA) Choke Equalize Manifold 2-3/8" Pipe/Slip(BHA) A L Kill ►> >\// Jr Blind/Shear 2" Pipe/Slip(CT) Choke 2 Swab Valves Wing Valves ��4102ie Tree Flow Cross gi Surface Safety Valve BOPE: 7-1/16", 5M psi, TOT Choke Line: 2-1/16", 5M psi Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, C062 Union RIGINAL ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1E Pad 1E-07 1E-07A Plan: 1 E-07A wp06 Standard Planning Report 02 May, 2011 BAKER HUGHES ORIGINAL iv- ConocoPhillips FS- ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-07 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-07 @ 105.50ft(1E-07) Site: Kuparuk 1E Pad North Reference: True Well: 1 E-07 Survey Calculation Method: Minimum Curvature Wellbore: 1E-07A Design: 1 E-07A_wp06 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1E Pad Site Position: Northing: 5,959,760.24ft Latitude: 70°18'3.022 N From: Map Easting: 549,889.51 ft Longitude: 149°35'45.358 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.38° Well 1E-07 Well Position +N/-S 0.00 ft Northing: 5,960,480.37ft Latitude: 70° 18'10.104 N +E/-W 0.00 ft Easting: 549,889.49 ft Longitude: 149°35'45.219 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore 1 E-07A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 6/1/2011 16.79 79.86 57,357 Design 1E-07A_wp06 I 11 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,800.00 l Vertical Section: Depth From(ND) +N/-S +EI-W Direction 1 (ft) (ft) (ft) (°) 0.00 0.00 0.00 145.00 Plan Sections Measured ND Below Dogleg Build Turn Depth Inclination Azimuth System +NI-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°1100ft) (°) Target 8,800.00 38.00 62.28 6,234.81 3,250.95 4,607.91 0.00 0.00 0.00 0.00 8,892.00 40.99 62.76 6,305.80 3,277.94 4,659.82 3.27 3.25 0.52 6.02 8,912.00 48.99 62.76 6,319.93 3,284.41 4,672.38 40.00 40.00 0.00 0.00 8,957.00 69.24 62.76 6,342.91 3,301.99 4,706.54 45.00 45.00 0.00 0.00 8,997.00 85.02 71.68 6,351.81 3,316.94 4,742.38 45.00 39.44 22.31 30.00 9,082.50 104.00 105.42 6,344.92 3,319.39 4,825.96 45.00 22.20 39.45 60.00 9,182.50 104.05 151.88 6,319.36 3,260.66 4,899.41 45.00 0.05 46.46 84.00 9,282.50 104.15 164.25 6,294.91 3,170.89 4,935.56 12.00 0.10 12.37 88.00 9,482.50 104.12 189.01 6,245.33 2,978.97 4,946.85 12.00 -0.01 12.38 87.00 9,582.50 101.15 200.93 6,223.38 2,884.92 4,921.64 12.00 -2.98 11.92 103.00 9,982.50 97.43 152.39 6,154.78 2,503.33 4,944.83 12.00 -0.93 -12.14 270.00 10,257.50 89.99 184.63 6,136.50 2,238.09 4,998.41 12.00 -2.70 11.72 101.60 10,657.50 81.84 137.16 6,166.68 1,871.90 5,124.33 12.00 -2.04 -11.87 259.00 10,900.00 77.78 166.45 6,210.49 1,664.21 5,236.11 12.00 -1.68 12.08 100.50 5/2/2011 2:35:56PM Page 2 COMPASS 2003.16 Build 69 ORIGINAL ✓ ConocoPhillips id' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-07 Company: ConocoPhillips(Alaska)Inc. ND Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-07 @ 105.50ft(1E-07) Site: Kuparuk 1E Pad North Reference: True Well: 1 E-07 Survey Calculation Method: Minimum Curvature Wellbore: 1E-07A Design: 1 E-07A_wp06 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) r/100ft) (°) (ft) (ft) 8,800.00 38.00 62.28 6,234.81 3,250.95 4,607.91 -20.03 0.00 0.00 5,963,761.53 554,475.27 TIP 8,892.00 40.99 62.76 6,305.80 3,277.94 4,659.82 -12.37 3.27 6.02 5,963,788.86 554,526.99 KOP 8,900.00 44.19 62.76 6,311.69 3,280.42 4,664.63 -11.64 40.00 0.00 5,963,791.37 554,531.79 8,912.00 48.99 62.76 6,319.93 3,284.41 4,672.38 -10.46 40.00 0.00 5,963,795.41 554,539.51 End of 40DLS 8,957.00 69.24 62.76 6,342.91 3,301.99 4,706.54 -5.27 45.00 0.00 5,963,813.22 554,573.54 4 8,997.00 85.02 71.68 6,351.81 3,316.94 4,742.38 3.04 45.00 30.00 5,963,828.40 554,609.28 5 9,000.00 85.69 72.85 6,352.06 3,317.85 4,745.22 3.93 45.00 60.00 5,963,829.33 554,612.12 9,082.50 104.00 105.42 6,344.92 3,319.39 4,825.96 48.98 45.00 59.91 5,963,831.40 554,692.84 6 9,100.00 104.69 113.51 6,340.58 3,313.75 4,841.93 62.76 45.00 84.00 5,963,825.87 554,708.84 9,182.50 104.05 151.88 6,319.36 3,260.66 4,899.41 139.21 45.00 86.01 5,963,773.17 554,766.67 End of 45DLS 9,200.00 104.11 154.04 6,315.10 3,245.55 4,907.12 156.01 12.00 88.00 5,963,758.11 554,774.48 9,282.50 104.15 164.25 6,294.91 3,170.89 4,935.56 233.48 12.00 88.53 5,963,683.66 554,803.41 8 9,300.00 104.25 166.42 6,290.61 3,154.49 4,939.86 249.38 12.00 87.00 5,963,667.28 554,807.81 9,400.00 104.45 178.80 6,265.74 3,058.62 4,952.30 335.04 12.00 87.53 5,963,571.51 554,820.89 9,482.50 104.12 189.01 6,245.33 2,978.97 4,946.85 397.16 12.00 90.61 5,963,491.83 554,815.97 9 9,500.00 103.64 191.12 6,241.13 2,962.25 4,943.88 409.16 12.00 103.00 5,963,475.09 554,813.11 9,582.50 101.15 200.93 6,223.38 2,884.92 4,921.64 459.75 12.00 103.51 5,963,397.62 554,791.38 10 9,600.00 101.14 198.79 6,220.00 2,868.78 4,915.80 469.63 12.00 -90.00 5,963,381.44 554,785.66 9,700.00 100.81 186.57 6,200.89 2,773.19 4,894.30 535.59 12.00 -90.41 5,963,285.73 554,764.80 9,800.00 100.00 174.40 6,182.77 2,675.04 4,893.49 615.53 12.00 -92.75 5,963,187.58 554,764.63 9,900.00 98.75 162.30 6,166.42 2,578.60 4,913.39 705.94 12.00 -94.95 5,963,091.29 554,785.18 9,982.50 97.43 152.39 6,154.78 2,503.33 4,944.83 785.63 12.00 -96.93 5,963,016.23 554,817.11 11 10,000.00 97.01 154.46 6,152.58 2,487.80 4,952.59 802.80 12.00 101.60 5,963,000.76 554,824.97 10,100.00 94.41 166.24 6,142.60 2,394.26 4,985.97 898.57 12.00 101.86 5,962,907.45 554,858.97 10,200.00 91.63 177.93 6,137.32 2,295.53 4,999.69 987.31 12.00 103.04 5,962,808.83 554,873.34 10,257.50 89.99 184.63 6,136.50 2,238.09 4,998.41 1,033.64 12.00 103.65 5,962,751.38 554,872.44 12 10,300.00 89.02 179.62 6,136.86 2,195.63 4,996.83 1,067.51 12.00 -101.00 5,962,708.92 554,871.15 10,400.00 86.78 167.83 6,140.54 2,096.48 5,007.72 1,154.98 12.00 -100.96 5,962,609.85 554,882.70 10,500.00 84.67 155.98 6,148.02 2,001.86 5,038.63 1,250.21 12.00 -100.52 5,962,515.45 554,914.23 10,600.00 82.79 144.06 6,158.98 1,915.92 5,088.19 1,349.04 12.00 -99.64 5,962,429.84 554,964.35 10,657.50 81.84 137.16 6,166.68 1,871.90 5,124.33 1,405.82 12.00 -98.33 5,962,386.07 555,000.78 13 10,700.00 80.95 142.24 6,173.04 1,839.87 5,151.50 1,447.65 12.00 100.50 5,962,354.22 555,028.16 10,800.00 79.13 154.28 6,190.40 1,756.29 5,203.24 1,545.79 12.00 99.74 5,962,271.00 555,080.45 . 10,900.00 77.78 166.45 6,210.49 . 1,664.21 5,236.11 1,640.07 12.00 97.65 5,962,179.15 555,113.93 TD 5/2/2011 2:35:56PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips IPS ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-07 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-07@ 105.50ft(1E=07) Site: Kuparuk 1E Pad North Reference: True Well: 1E-07 Survey Calculation Method: Minimum Curvature Wellbore: 1E-07A Design: 1E-07A wp06 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting -Shape (0) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 1E-07A T2 0.00 0.00 6,259.00 3,033.99 4,952.24 5,963,546.88 554,820.99 70°18'39.928 N 149°33'20.768 W -plan hits target center -Point 1E-07AT4 0.00 0.00 6,210.00 1,664.97 5,222.46 5,962,179.82 555,100.28 70°18'26.462 N 149°33'12.914 W -plan misses target center by 13.14ft at 10894.69ft MD(6209.37 TVD,1669.25 N,5234.87 E) -Point 1E-07AT3 0.00 0.00 6,135.00 2,237.68 4,998.44 5,962,750.97 554,872.47 70°18'32.096 N 149°33'19.436 W -plan misses target center by 1.50ft at 10257.90ft MD(6136.50 TVD,2237.69 N,4998.38 E) -Point 1E-07A,AL1 Polygon 0.00 0.00 0.00 3,150.31 4,549.15 5,963,660.51 554,417.18 70°18'41.074 N 149°33'32.524 W -plan misses target center by 6201.29ft at 10000.00ft MD(6152.58 TVD,2487.80 N,4952.59 E) -Polygon Point 1 0.00 3,150.31 4,549.15 5,963,660.51 554,417.18 Point 2 0.00 3,180.07 4,737.37 5,963,691.51 554,605.18 Point 3 0.00 3,090.49 4,824.79 5,963,602.52 554,693.18 Point 4 0.00 2,908.68 4,792.59 5,963,420.52 554,662.19 Point 5 0.00 2,636.80 4,769.79 5,963,148.52 554,641.20 Point 6 0.00 2,396.16 4,862.22 5,962,908.52 554,735.22 Point 7 0.00 1,983.58 4,942.51 5,962,496.53 554,818.24 Point 8 0.00 1,633.66 5,076.22 5,962,147.54 554,954.26 Point 9 0.00 1,278.77 5,052.88 5,961,792.53 554,933.27 Point 10 0.00 1,287.33 5,271.96 5,961,802.55 555,152.27 Point 11 0.00 1,710.25 5,290.75 5,962,225.54 555,168.25 Point 12 0.00 1,877.40 5,270.85 5,962,392.54 555,147.24 Point 13 0.00 2,322.23 5,153.77 5,962,836.54 555,027.22 Point 14 0.00 2,812.81 5,073.99 5,963,326.53 554,944.20 Point 15 0.00 3,319.02 5,051.32 5,963,832.53 554,918.17 Point 16 0.00 3,393.20 4,873.79 5,963,905.52 554,740.17 Point 17 0.00 3,373.67 4,649.63 5,963,884.51 554,516.16 Point 18 0.00 3,233.87 4,465.69 5,963,743.50 554,333.17 Point 19 0.00 3,150.31 4,549.15 5,963,660.51 554,417.18 1 E-07A T1 0.00 0.00 6,353.00 3,322.01 4,764.77 5,963,833.62 554,631.64 70°18'42.761 N 149°33'26.231 W -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (••) 10,900.00 6,210.49 2-3/8" 2-3/8 3 51.212011 2:35:56PM Page 4 COMPASS 2003.16 Build 69 ORIGINAL • Iv- ConocoPhillips 'r' CortocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-07 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-07 @ 105.50ft(1E-07) Site: Kuparuk 1E Pad North Reference: True Well: 1 E-07 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-07A Design: 1 E-07A_wp06 Plan Annotations i Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 8,800.00 6,234.81 3,250.95 4,607.91 TIP 8,892.00 6,305.80 3,277.94 4,659.82 KOP 8,912.00 6,319.93 3,284.41 4,672.38 End of 40DLS 8,957.00 6,342.91 3,301.99 4,706.54 4 8,997.00 6,351.81 3,316.94 4,742.38 5 9,082.50 6,344.92 3,319.39 4,825.96 6 9,182.50 6,319.36 3,260.66 4,899.41 End of 45DLS 9,282.50 6,294.91 3,170.89 4,935.56 8 9,482.50 6,245.33 2,978.97 4,946.85 9 9,582.50 6,223.38 2,884.92 4,921.64 10 9,982.50 6,154.78 2,503.33 4,944.83 11 10,257.50 6,136.50 2,238.09 4,998.41 12 10,657.50 6,166.68 1,871.90 5,124.33 13 10,900.00 6,210.49 1,664.21 5,236.11 TD 5/2/2011 2:35:56PM Page 5 COMPASS 2003.16 Build 69 ` . , w U' Magi00 I00 44ilitgmi i 51.1111. i s o, o o o 8 o O 1 i O r w ,� N o .41 ate+ { . o Q i11 V G O \. 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O © C 0 O di IS) ConocoPhillips r ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1E-07 Project: Kuparuk River Unit TVD Reference: 1E-07 @ 105.50ft(1E-07) Reference Site: Kuparuk 1E Pad MD Reference: 1E-07 @ 105.50ft(1E-07) Site Error: 0.00ft North Reference: True Reference Well: 1E-07 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 1E-07A Database: EDM Alaska Prod v16 Reference Design: 1E-07A_wp06 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) *Kuparuk 1E Pad 1 E-102-B-Lateral-B-Lat Actual Out of range 1 E-102-D-Lateral-D-Lat Actual Out of range 1 E-104-Wellbore#1-Actual Surveys Out of range 1E-121-B Lateral-B-Lat Survey Out of range 1E-121-D Lateral-D-Lat Survey Out of range Kuparuk 1E Pad 1 E-05-1 E-05-1E-05 Out of range 1 E-05-1 E-05A-1E-05A(wp03) Out of range 1 E-06-1E-06-1E-06 Out of range 1E-07-1 E-07-1E-07 8,875.00 8,875.00 0.00 1.00 -1.00 FAIL-Minor 1/10 1E-07-1 E-07AL1-1 E-07AL1_wp06 9,474.97 9,475.00 0.91 0.83 0.14 Pass-Minor 1/10 1E-07-1 E-07AL2-1 E-07AL2_wp04 8,875.00 8,875.00 0.00 0.74 -0.74 FAIL-Minor 1/10 1E-07-1 E-07AL2-01-1E-07/101_wpO4 8,875.00 8,875.00 0.00 0.74 -0.74 FAIL-Minor 1/10 1 E-08-1 E-08-1 E-08 Out of range 1 E-08-1 E-08A-1E-08A Out of range 1 E-08-1 E-08AL1-1 E-08AL1 Out of range 1 E-08-1 E-08AL1-01-1 E-08AL1-01 Out of range 1 E-08-1 E-08AL1-02-1 E-08AL1-02 Out of range 1 E-08-1 E-08AL1-03-1 E-08AL1-03 Out of range 1 E-08-1 E-08AL2-1 E-08AL2 Out of range 1 E-08-1 E-08AL2-01-1 E-08AL2-01 Out of range 1E-10-1E-10-1E-10 Out of range 1E-102-1E-102-1E-102 Out of range 1E-102-1E-102L1 -1E-102L1 Out of range 1E-102-1 E-102L1 PB1-1 E-102L1 PB1 Out of range 1E-102-1 E-102PB1-1 E-102PB1 Out of range 1 E-102-1 E-102PB1 -Plan 1E-102 B lat(wp5.0) Out of range 1 E-102-1 E-102PB2-1 E-102PB2 Out of range 1E-11 -1E-11-1E-11 Out of range 1E-12-IE-12-1E-12 Out of range 1E-12-1E-12L1 -1E-12L1 Out of range 1E-12-1E-12L1-01 -1E-12L1-01 Out of range 1 E-12-1 E-12L1 PB1-1 E-12L1 PB1 Out of range 1E-12-1E-12L2-1E-12L2 Out of range 1 E-12-1 E-12L2-01-1E-12L2-01 Out of range 1 E-12-IE-12L2-01 PB1-1 E-12L2-01 PB1 Out of range 1 E-12-1 E-1212PB1-1 E-12L2PB1 Out of range 1E-121-1E-121-1E-121 Out of range 1E-121-1E-121-Plan:1E-121 B Lat(wp06) Out of range 1E-121-1E-121L1-1E-121L1 Out of range 1E-121-1E-121L1-Plan 1E-121 D Lat(wp06) Out of range 1E-123-1E-123-1 E-123 Out of range 1E-123-1E-123L1-1E-123L1 Out of range 1E-123-1 E-123PB1-1E-123PB1 Out of range 1E-126-1E-126-1E-126 Out of range 1E-126-1E-126L1-1E-126L1 Out of range 1E-126-1E-126L2-1E-126L2 Out of range 1E-20-1E-20-1 E-20 Out of range 1 E-36-1E-36-1E-36 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/4/2011 9:27:58AM Page 3 of 11 COMPASS 2003.16 Build 69 CIR ! GINAL OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME /<i2 L'� / '7 PTD# 2—// C ' ( "Development Service Exploratory Stratigraphic Test Non-Conventional Well Le,��G� tc L t<1 t-e-c POOL: jl��:� 1/t�c L i(��it �� 7 FIELD. � Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 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