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207-028
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: RPPG MBE Trtmnt 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 11571'feet None feet true vertical 3661'feet None feet Effective Depth measured 11565'feet 7288', 7465, 7820'feet true vertical 3660'feet 3636', 3661', 3719'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)4-1/2" L-80 7324' MD 3642' TVD Packers and SSSV (type, measured and true vertical depth) Packer Packer Packer SSSV ZXP Liner Top Packer ZXP Liner Top Packer HRD ZXP Liner Top Packer None 7288' MD 7465' MD 7820' MD N/A 3636' TVD 3661' TVD 3719' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name: Contact Name: Authorized Title:Sr. Wells Engineer Contact Email: Contact Phone: Senior Engineer:Senior Res. Engineer: Authorized Signature with date: WINJ WAG John Peirce 8155-8522', 8722-9818', 9540-9545', 9925-9930', 10075-10592', 10849-11521' feet 3699-3676', 3672-3659', 3670-3660', 3659-3659', 3665-3656', 3654-3659' feet 108' Burst Collapse 11565' TVD 108' 2254' 3820' 3660' Length 78' 3356' Size 4-1/2" Representative Daily Average Production or Injection Data n/an/an/a Structural 20" 10-3/4" 7-5/8" 3. Address: Casing Pressure Tubing Pressure measured true vertical Kuparuk River Field/ West Sak Oil Pool Conductor Surface Production KRU 1J-105L1 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-019 n/a Slotted Liner Packer 3725' 7680' N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Shut-In Gas-Mcf measuredPlugs Junk measured N/A ConocoPhillips Alaska, Inc. ADL 25661, ADL 25662 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 207-028 50-029-23346-60-00 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: MD 3387' n/a Shut-In Treatment descriptions including volumes used and final pressure: n/a Casing John Peirce John.W.Peirce@conocophillips.com (907) 265-6471 P.O. Box 100360 Anchorage, AK 99510 n/a 7707' n/a Oil-Bbl Water-Bbl t Frac Ot y 6. API Nu y G L GING 070, 25. Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:52 am, Nov 24, 2020 John W Peirce Digitally signed by John W Peirce Date: 2020.11.19 15:33:50 -09'00' RBDMS HEW 11/25/2020 DSR-11/24/2020 SFD 11/24/2020VTL 02/18/2021 !"# $$%&'! ()'!*) !+)",- $*.,+/) %,+/0,)1 2 %%$- "#&$$&0!"%567%%$-3402 89&# (: *;/.&+.!+)'*),&+8 /" ',+/)'!*) !+),- $*.!" )'!*) !+)0 %%$-34*+"7",!-!$ < 2 )& < = !)'!*) !+) *'5&# !'*),&+- Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1J-105L1 triplwj Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: MBE TREATMENT - SEE NOTES 5/22/2017 1J-105L1 pproven Casing Strings Casing Description B-Sand Slotted Liner OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 7,840.5 Set Depth (ftKB) 11,565.0 Set Depth (TVD) … 3,660.4 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,840.5 3,709.0 89.94 SLEEVE L1 B-SAND HR Liner Setting Sleeve w/ 10' TBR 5.5" ( ID 5.0" ) 5.000 7,860.6 3,708.9 90.49 SBE L1 B-SAND Receptacle Jt 5.5" 15.5# L80 5.5" Hdy b X p ( ID 4.89") 4.890 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,155.0 8,522.0 3,698.7 3,676.3 WS B, 1J-105L1 4/12/2007 32.0 SLOTS Alternating solid/slotted pipe 2.5" long x .125" wide 8,722.0 9,818.0 3,672.3 3,659.2 WS B, WS C, 1J -105L1 4/12/2007 32.0 SLOTS Alternating solid/slotted pipe 2.5" long x .125" wide 9,540.0 9,545.0 3,659.7 3,659.6 WS B, 1J-105 9/24/2012 6.0 APERF Big Hole guns, 6 spf, 2090# Crystal Seal pumped 9,925.0 9,930.0 3,659.1 3,659.1 WS B, 1J-105L1 11/28/2019 6.0 APERF HSD GUNS, 6 SPF, 60 DEGREE PHASING 10,075.0 10,592.0 3,665.5 3,656.2 WS B, 1J-105L1 4/12/2007 32.0 SLOTS Alternating solid/slotted pipe 2.5" long x .125" wide 10,849.0 11,521.0 3,654.3 3,659.5 WS B, 1J-105L1 4/12/2007 32.0 SLOTS Alternating solid/slotted pipe 2.5" long x .125" wide Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 9,540.0 9,545.0 3,659.7 3,659.6 GEL SQUEEEZE PROFILE MODIFICATION - PUMPED 2090 LBS (4MM) CRYSTAL SEAL INTO "B" MBE. 9/24/2012 9,540.0 9,545.0 3,659.7 3,659.6 GEL SQUEEZE PROFILE MODIFICATION - PUMPED 3100 LBS (4MM) CRYSTAL SEAL INTO "B" MBE 8/10/2013 Notes: General & Safety End Date Annotation 4/30/2017 NOTE: Coil Tubing RPPG Treatment 3308 Lbs to B MBE in 1J-105L1 8/10/2013 NOTE: PROFILE MODIFICATION - PUMPED 3100 LBS (4MM) CRYSTAL SEAL INTO "B" MBE@9550 9/24/2012 NOTE: PROFILE MODIFICATION - PUMPED 2090 LBS (4MM) CRYSTAL SEAL INTO "B" MBE@9550 4/29/2007 NOTE: MULTI-LAT WELL - 1J-105 (A-SAND), 1J-105L1 (B-SAND), 1J-105L2 (D-SAND) 1J-105L1, 11/18/2020 1:44:53 PM Vertical schematic (actual) B-Sand Slotted Liner; 7,840.6- 11,565.0 SLOTS; 10,849.0-11,521.0 SLOTS; 10,075.0-10,592.0 APERF; 9,925.0-9,930.0 APERF; 9,540.0-9,545.0 GEL SQUEEEZE; 9,540.0 ftKB GEL SQUEEZE; 9,540.0 ftKB SLOTS; 8,722.0-9,818.0 SLOTS; 8,155.0-8,522.0 PRODUCTION; 27.4-8,838.4 WINDOW B; 7,707.0-7,722.0 B-Sand Liner HH; 7,703.3- 7,893.8 B-Sand Liner LEM; 7,464.8- 7,862.5 D-Sand Liner HH; 7,343.3- 7,611.8 D-Sand Liner LEM; 7,288.4- 7,494.8 WINDOW D; 7,348.0-7,363.0 SEAL ASSY; 7,296.6 LOCATOR; 7,295.5 SLEEVE-C; 6,691.3 GAS LIFT; 6,393.7 SURFACE; 30.5-3,386.8 GAS LIFT; 2,267.8 NIPPLE; 498.3 CONDUCTOR; 30.0-108.0 HANGER; 23.0 KUP INJ KB-Grd (ft) 32.29 Rig Release Date 4/29/2007 1J-105L1 ... TD Act Btm (ftKB) 11,571.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292334660 Wellbore Status INJ Max Angle & MD Incl (°) 96.16 MD (ftKB) 8,305.45 WELLNAME WELLBORE1J-105 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1J-105 triplwj Last Rev Reason Annotation End Date Wellbore Last Mod By REV REASON: ADD PERFS 1J-105 mcanej Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 30.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 94.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 30.5 Set Depth (ftKB) 3,386.8 Set Depth (TVD) … 2,254.4 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description WINDOW D OD (in) 8 ID (in) 7.00 Top (ftKB) 7,348.0 Set Depth (ftKB) 7,363.0 Set Depth (TVD) … 3,647.1 Wt/Len (l…Grade Top Thread Casing Description WINDOW B OD (in) 8 ID (in) 7.00 Top (ftKB) 7,707.0 Set Depth (ftKB) 7,722.0 Set Depth (TVD) … 3,703.3 Wt/Len (l…Grade Top Thread Casing Description PRODUCTION OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 27.4 Set Depth (ftKB) 8,838.4 Set Depth (TVD) … 3,820.3 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description D-Sand Liner LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,288.4 Set Depth (ftKB) 7,494.8 Set Depth (TVD) … 3,666.2 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,288.4 3,635.9 79.45 PACKER L2 D-SAND LEM ZXP 5-1/2" x 7-5/8" Liner Top Packer TOP 4.940 7,307.5 3,639.2 80.46 CSR L2 D-SAND LEM Casing SBR 109-47 C 6.26" OD x 4.75" ID 4.750 7,327.1 3,642.3 81.50 BUSHING L2 D-SAND LEM Reducing XO Bushing 5-1/2" Hydril 563 x 4-1/2" IBT 3.930 7,332.3 3,643.0 81.77 HANGER L2 D-SAND LEM Above Hook Hanger 3.960 7,343.3 3,644.5 82.35 HANGER L2 D-SAND LEM Inside Hook Hanger 3.688 7,491.5 3,665.6 80.39 SEAL ASSY L2 D-SAND LEM Baker Seal Assembly 4-1/2" STL Box up 3.860 Casing Description D-Sand Liner HH OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 7,343.3 Set Depth (ftKB) 7,611.8 Set Depth (TVD) … 3,686.7 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,343.3 3,644.5 82.35 HANGER L2 D-SAND HOOK ASSY Baker Model B-1 Hook Hanger 7 5/8" x 4 1/2" (Inside csg) 5.600 7,360.0 3,646.7 82.39 HANGER L2 D-SAND HOOK ASSY Baker Model B-1 Hook Hanger 7 5/8" x 4 1/2" (Outside csg) 4.000 7,505.3 3,668.0 79.94 ECP L2 D-SAND HOOK ASSY Baker Payzone External Casing Packer 3.960 Casing Description B-Sand Liner LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,464.8 Set Depth (ftKB) 7,862.5 Set Depth (TVD) … 3,725.4 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,464.8 3,661.4 81.28 PACKER L1 B-SAND LEM ZXP 5-1/2" x 7-5/8" Liner Top Packer TOP 4.767 7,483.8 3,664.3 80.65 CSR L1 B-SAND LEM 109-47 Casing SBR 6.26" OD x 4.75 4.750 7,503.5 3,667.6 80.00 BUSHING L1 B-SAND LEM XO Bushing 5-1/2" Hydril 563 x 4- 1/2" IBT 3.958 7,696.5 3,699.3 81.21 HANGER L1 B-SAND LEM LEM Above Hook Hanger 3.688 7,703.3 3,700.4 81.18 HANGER L1 B-SAND LEM LEM Inside Hook Hanger 3.688 7,809.3 3,717.1 80.72 NIPPLE L1 B-SAND LEM Camco "DB-6" Nipple, I.D. 3.562", IBT 3.562 7,859.2 3,724.9 81.40 SEAL ASSY L1 B-SAND LEM Baker Seal Assembly 4-1/2" STL Box up 3.860 Casing Description B-Sand Liner HH OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 7,703.3 Set Depth (ftKB) 7,893.8 Set Depth (TVD) … 3,730.0 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,703.3 3,700.4 81.18 HANGER L1 B-SAND Baker Model B-1 Hook Hanger 7 5/8" x 4 1/2" (Inside) 5.640 7,720.0 3,703.0 81.08 HANGER L1 B-SAND Baker Model B-1 Hook Hanger 7 5/8" x 4 1/2" (Outside) 5.640 Casing Description A-Sand Slotted Liner OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 7,820.0 Set Depth (ftKB) 11,725.0 Set Depth (TVD) … 3,822.7 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC w/ TR Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,820.0 3,718.8 80.68 PACKER A-SAND 5.5"x 7.63" Baker "HRD" ZXP Liner Top Pkr 5.500 7,839.0 3,721.8 81.03 SEAL NIPPLE A-SAND "RS" Packoff Seal Nipple, 6.07" OD/ 4.87" ID 4.870 7,841.8 3,722.3 81.08 HANGER A-SAND 5.5" X 7.63" "Flex-Lock" Liner Hgr, 6.59" OD/ 4.85" ID 4.850 7,851.6 3,723.8 81.26 SBE A-SAND 190-47 Seal Bore Ext, 6.29" OD / 4.75" ID 4.750 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.99 Top (ftKB) 23.0 Set Depth (ft… 7,323.9 Set Depth (TVD) (… 3,641.8 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.0 23.0 0.00 HANGER TUBING HANGER w/ PUP 3.992 498.3 497.7 7.11 NIPPLE CAMCO DB NIPPLE 3.875 6,691.3 3,494.6 69.09 SLEEVE-C CMU SLIDING SLEEVE (CLOSED ON 6/29/2007) 3.812 7,295.5 3,637.2 79.82 LOCATOR LOCATOR 3.880 7,296.6 3,637.3 79.88 SEAL ASSY GBH-22 LOCATING SEAL ASSEMBLY 3.880 1J-105, 11/18/2020 1:44:54 PM Vertical schematic (actual) A-Sand Slotted Liner; 7,820.0- 11,725.0 SLOTS; 10,068.0-11,682.0 SLOTS; 8,863.0-9,769.0 PRODUCTION; 27.4-8,838.4 B-Sand Liner HH; 7,703.3- 7,893.8 B-Sand Liner LEM; 7,464.8- 7,862.5 PLUG & PRONG; 7,809.0 WINDOW B; 7,707.0-7,722.0 D-Sand Liner HH; 7,343.3- 7,611.8 D-Sand Liner LEM; 7,288.4- 7,494.8 WINDOW D; 7,348.0-7,363.0 SEAL ASSY; 7,296.6 LOCATOR; 7,295.5 SLEEVE-C; 6,691.3 GAS LIFT; 6,393.7 SURFACE; 30.5-3,386.8 GAS LIFT; 2,267.8 NIPPLE; 498.3 CONDUCTOR; 30.0-108.0 HANGER; 23.0 KUP INJ KB-Grd (ft) 32.29 Rig Release Date 4/29/2007 1J-105 ... TD Act Btm (ftKB) 11,735.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292334600 Wellbore Status INJ Max Angle & MD Incl (°) 92.96 MD (ftKB) 9,846.46 WELLNAME WELLBORE1J-105 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,809.0 3,717.0 80.72 PLUG & PRONG DB-6 PLUG - PRONG 10/29/2019 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,863.0 9,769.0 3,821.1 3,813.0 WS A2, 1J-105 4/26/2007 32.0 SLOTS Alternating solid/slotted pipe 2.5" long x .125" wide 10,068.0 11,682.0 3,810.0 3,822.4 WS A2, 1J-105 4/26/2007 32.0 SLOTS Alternating solid/slotted pipe 2.5" long x .125" wide Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,267.8 1,853.7 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 6/28/2007 2 6,393.7 3,387.0 CAMCO KBMG 1 GAS LIFT DMY BEK-5 0.000 0.0 4/28/2007 Notes: General & Safety End Date Annotation 8/10/2013 NOTE: PROFILE MODIFICATION - PUMPED 3100 LBS (4MM) CRYSTAL SEAL INTO "B" MBE@9550 9/24/2012 NOTE: PROFILE MODIFICATION - PUMPED 2090 LBS (4MM) CRYSTAL SEAL INTO "B" MBE@9550 4/29/2007 NOTE: MULTI-LAT WELL - 1J-105 (A-SAND), 1J-105L1 (B-SAND), 1J-105L2 (D-SAND) 1J-105, 11/18/2020 1:44:55 PM Vertical schematic (actual) A-Sand Slotted Liner; 7,820.0- 11,725.0 SLOTS; 10,068.0-11,682.0 SLOTS; 8,863.0-9,769.0 PRODUCTION; 27.4-8,838.4 B-Sand Liner HH; 7,703.3- 7,893.8 B-Sand Liner LEM; 7,464.8- 7,862.5 PLUG & PRONG; 7,809.0 WINDOW B; 7,707.0-7,722.0 D-Sand Liner HH; 7,343.3- 7,611.8 D-Sand Liner LEM; 7,288.4- 7,494.8 WINDOW D; 7,348.0-7,363.0 SEAL ASSY; 7,296.6 LOCATOR; 7,295.5 SLEEVE-C; 6,691.3 GAS LIFT; 6,393.7 SURFACE; 30.5-3,386.8 GAS LIFT; 2,267.8 NIPPLE; 498.3 CONDUCTOR; 30.0-108.0 HANGER; 23.0 KUP INJ 1J-105 ... WELLNAME WELLBORE1J-105 pTp ao_�--02`X' Proposal for 1J -105L7 to 1J-107 RPPG B MBE Retreatment 1J-105 Tri-Lat injector was drilled & completed in 2007 with West Sak A, B, & D Sd laterals. 1J-1051-1 B Lat has 4.5", L-80 slotted liner. A first B MBE occurred 4/5/12 from 1J -105L1 to 1J-1031-1 producer. A 5/26/12 IPROF found B MBE at —9550' RKB taking all PWI. On 9/24/12, a Crystal Seal job sealed the MBE —3 months, then 3/24/13 (PROF verified B MBE at 9550' reopened. An 8/10/13 Crystal Seal retreat was pumped and lasted —3 years until an MBE occurred 3/9/16. 1J-1051_1 5/25/16 IPROF found new MBE at —9750' RKB. On 4/30/17, an RPPG treatment sealed MBE at 9750' RKB which lasted until —10/20/19, then the first MBE occurred from 1J -105L1 to 1J-107. An 11/8/19 IPROF in 1J -105L1 found a B MBE at 9930' RKB to 1J-107. A fullbore RPPG job on 12/5/19 treated the B MBE with 5940 lbs of RPPG, but post -job SWI response showed 1J-1051-1 not achieving any positive WHIP after 30 days at 500 - 1000 BWPD. A 2/17/20 [PROF verified that the MBE treatment failed, and that the B MBE at —9930' RKB was still open. 1J-1051-1 is currently configured for B MBE treatment. The `A' Lat is isolated by a Plug set at 7809' RKB on 10/29/19. A 'B' Diverter was set 11/7/19 at 7696' RKB, and a `D' ]so-Slv was set 11/7/19 at 7332' RKB to isolate D Lat. A perf interval was shot 11 /28/19 at 9925 - 9930' RKB near the B MBE at 6 spf, 60 deg ph, using 'big hole' charges for the 12/5/19 treatment. The treating pressure during RPPG treatment was quite higher than expected during the job indicating that some additional perforations might have been beneficial to enable placing a larger treatment volume at lower WHIP's. This procedure proposes an MBE retreatment. Some additional perforations will be shot to help enable better RPPG placement to the MBE, then an RPPG (Reformed Polymer Particle Gel) slurry treatment will be pumped with fibers added to the tail slurry to seal off the B MBE at —9930' RKB. Following the RPPG treatment, 1J-1051_1 will return to SWI service to evaluate the treatment results. Procedure Coil Tubing: 1) RIH with perf gun, then pump a ball down CT to perforate a 5' OAL add perf interval at 9920 - 9925' RKB (target) in 4.5" slotted liner, at 6 spf, 60 deg ph. POOH with perf gun. Verify all shots fired. Pumping: 2) At —12 hours before the RPPG job, put 1J-1051-1 on SWI at —1000 BPD to displace Diesel FP and gas head from tubing to open B MBE to 1J-107. RU pumping equipment at 1J-105 the next morning. SI 1J-107 and 1J-1051-1, and then immediately fullbore pump the following into 1J-1051-1: a) 151 bbls (= volume to MBE) of 2% KCL Brine at a steady rate between 1.5 to 4.0 bpm TBD based on the rate needed to let the pump keep up with vacuum rate acting on well, followed by b) XX bbls RPPG slurry mixed at 0.5 - 0.75 lbs/gal RPPG in 2% KCL Brine on -the -fly. Pump this slurry at steady rate until WHIP reaches —150 psi, then swap to pumping c) Optional: Up to —50 bbls of Tail stage with fibers added at light concentration yet TBD (depends on vendor product option selected and blending recommendations) in 0.5 - 0.75 ppg RPPG slurry, then d) Call Flush and pump 108 bbls of 2% KCL Brine displacement, followed by e) 41 bbls Diesel FP to 2000' TVD (2684' RKB), followed by f) Shutdown & trap WHIP on well with RPPG treatment —1 bbl underdisplaced to B MBE. RD. Wait 48 hrs for RPPG to cure in MBE to crosslinked non -flowing RPPG before returning 1J-1051_1 to injection or 1J-107 to production. Return 1J-1051_1 to SWI. Evaluate results of RPPG MBE treatment. Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Monday, March 9, 2020 4:45 PM To: Peirce, John W Subject: Re: [EXTERNAL]KRU 1J-1051-1 (PTD 207-028, Sundry 320-019). KRU 1J-107(PTD 207-107, Sundry 320-018) RPPG Retreatment Sundry changes Follow Up Flag: Follow up Flag Status: Flagged John, The changes outlined below and in the updated procedure are approved. Please include a copy of this approval with the approved sundries and have them available on site should the AOGCC inspector request to see the approval. Thanx, Victoria Loepp Sent from my iPhone On Mar 9, 2020, at 8:40 AM, Peirce, John W <John.W.Peirce@conocophillips.com> wrote: Hi Victoria, Did you get a chance to look at this yet? Just checking. Thanks, John Peirce From: Peirce, John W Sent: Wednesday, March 4, 2020 3:26 PM To: Loepp, Victoria T (CED) <victoria. foe pp@alaska.gov> Subject: RE: [EXTERNAL]KRU 11-1051-1 (PTD 207-028, Sundry 320-019). KRU 1J-107(PTD 207-107, Sundry 320-018) RPPG Retreatment Sundry changes Victoria, Attached is a revised procedure as you requested. There were no deletions to be made in the procedure work steps, so no text needed striking out. I put some text in red for work steps to shoot more perforations in the liner and to possibly add some Tail slurry with fibers. I labeled the tail slurry with fibers as an 'Optional' step, because we may or may not perform on this step during the job. If opportunity to pump the job comes up before we have our final fiber recipe determined and approved by the MBE team, that we would prefer to pump the RPPG job without fibers rather than delay the pumping the job. I also added some information to the proposal above the procedural steps to include discussion of the new IPROF that we performed 2/17/20 that verified the MBE at —9930' is still open. All the other information remains the same. I request approval of the attached updated procedural plan. Thanks, John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office From: Loepp, Victoria T (CED) <victoria.loepp@alaska.eov> Sent: Wednesday, March 4, 2020 8:25 AM To: Peirce, John W <1ohn.W.Peirce@conocophillips.com> Subject: [EXTERNAL]KRU 1J-1051_1 (PTD 207-028, Sundry 320-019). KRU 11-107(PTD 207-107, Sundry 320-018) RPPG Retreatment Sundry changes John, Please make changes to the existing procedure by striking through deletions and making additions in red. Email the revised procedure for review and approval. We will handle these changes via email. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(cilalaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793- 1247 or victoria Loeoo@alaska gov From: Peirce, John W <John.W.Peirce@conocophillips.com> Sent: Wednesday, March 4, 2020 8:07 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.eov> Subject: Re: 11-1051-1 RPPG Retreatment Procedures 10-403 Approval Victoria, We are still planning to get 1J-1051-1 RPPG Treatment Procedure pumped per the Sundry approvals attached. Timing for pumping the job is being worked, but we expect to pump it sometime this Spring. Our MBE team has been reviewing the planned treatment. We believe based on how the well treated during the last RPPG treatment on 12/5/19, that we should probably add an additional 5' of large hole perforations at 9920 — 9925' RKB in the liner near the MBE. We have an existing perf interval at 9925 — 9930' RKB in the slotted liner, but adding some more perfs before the retreatment should help to get more RPPG slurry through the liner to the MBE before pressuring out. On the last treatment, we didn't quite get as much slurry away as we would have liked before pressuring out, and maximum treating pressure during the job was higher than we expected at 1930 psi, so it may help to add an extra five feet of perfs. The 10-403 approval attached below did not request approval for additional perfs, so I believe I'll need to send an updated 10-403 to AOGCC for approval to supersede the 10-403 approval below. Is this correct? One other minor change to the procedure that we would like to propose is to add a very small volume of fibers to our Tail RPPG slurry just before we call Flush. We don't know for sure how many barrels of Tail slurry we would pump with fibers because it depends on pressure response we'll be seeing during the job. I would guess the total volume of slurry with fibers would likely be less than 50 barrels. The fibers are to add some shear strength to cured RPPG slurry displaced into the MBE in the near wellbore region. This may give us a more resilient treatment. Adding fibers to RPPG slurry was not mentioned in the 10-403 (below) because this is a brand new treatment modification that we want to field test. If approved, this would be the first RPPG job with fibers added to the slurry. This should result in some new learnings. Beyond the request for approval to add an additional 5' of new perfs and a small amount of fibers to the tail slurry, no other changes are requested. Should I send over new amended 10-403's? Thanks, John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office <1J -105L1 RPPG B MBE Re-Trtmt Proposal-3-4-2020.doc> Loepp, Victoria T (CED) From: Peirce, John W <John.W.Peirce@conocophillips.com> Sent: Monday, March 9, 2020 4:59 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]KRU 1J-1051-1 (PTD 207-028, Sundry 320-019). KRU 1J-107(PTD 207-107, Sundry 320-018) RPPG Retreatment Sundry changes Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thanks for approval and I will follow your instructions. John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, March 9, 2020 4:45 PM To: Peirce, John W <John.W.Peirce@conocophillips.com> Subject: Re: [EXTERNAL]KRU 11-105L1 (PTD 207-028, Sundry 320-019). KRU 11-107(PTD 207-107, Sundry 320-018) RPPG Retreatment Sundry changes John, The changes outlined below and in the updated procedure are approved. Please include a copy of this approval with the approved sundries and have them available on site should the AOGCC inspector request to see the approval. Tha nx, Victoria Loepp Sent from my iPhone On Mar 9, 2020, at 8:40 AM, Peirce, John W <John.W.Peirce(@conocophillips.com> wrote: Hi Victoria, Did you get a chance to look at this yet? Just checking. Thanks, John Peirce From: Peirce, John W Sent: Wednesday, March 4, 2020 3:26 PM To: Loepp, Victoria T (CED) <victoria.loepp(Ja alask�> To: Peirce, John W <John.W.Peirce@conocophillips.com> Subject: (EXTERNAL)KRU 1J -105L1 (PTD 207-028, Sundry 320-019). KRU 1J-107(PTD 207-107, Sundry 320-018) RPPG Retreatment Sundry changes John, Please make changes to the existing procedure by striking through deletions and making additions in red. Email the revised procedure for review and approval. We will handle these changes via email. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria Loepp(aalaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistakein sending it to you, contact Victoria Loepp at (907)793-1247 or Victorio.Loepo@alaska.aov From: Peirce, John W <John.W.Peirce @conocophiIli ps.com> Sent: Wednesday, March 4, 2020 8:07 AM To: Loepp, Victoria T (CED) <victcria.loepp@alaska.eov> Subject: Re: 1J-10SL1 RPPG Retreatment Procedures 10-403 Approval Victoria, We are still planning to get 11-105L1 RPPG Treatment Procedure pumped per the Sundry approvals attached. Timing for pumping the job is being worked, but we expect to pump it sometime this Spring. Our MBE team has been reviewing the planned treatment. We believe based on how the well treated during the last RPPG treatment on 12/5/19, that we should probably add an additional 5' of large hole perforations at 9920 — 9925' RKB in the liner near the MBE. We have an existing pert interval at 9925 —9930' RKB in the slotted liner, but adding some more perfs before the retreatment should help to get more RPPG slurry through the liner to the MBE before pressuring out. On the last treatment, we didn't quite get as much slurry away as we would have liked before pressuring out, and maximum treating pressure during the job was higher than we expected at 1930 psi, so it may help to add an extra five feet of perfs. The 10-403 approval attached below did not request approval for additional perfs, so I believe I'll need to send an updated 10-403 to AOGCC for approval to supersede the 10-403 approval below. Is this correct? One other minor change to the procedure that we would like to propose is to add a very small volume of fibers to our Tail RPPG slurry just before we call Flush. We don't know for sure how many barrels of Tail slurry we would pump with fibers because it depends on pressure response we'll be seeing during the job. I would guess the total volume of slurry with fibers would likely be less than 50 barrels. The fibers are to add some shear strength to cured RPPG slurry displaced into the MBE in the near wellbore region. This may give us a more resilient treatment. Adding fibers to RPPG slurry was not mentioned in the 10-403 (below) because this is a brand new treatment modification that we want to field test. If approved, this would be the first RPPG job with fibers added to the slurry. This should result in some new learnings. Beyond the request for approval to add an additional 5' of new perfs and a small amount of fibers to the tail slurry, no other changes are requested. Should I send over new amended 10-403's? Thanks, John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office Loepp, Victoria T (CED) From: Peirce, John W <John.W.Peirce@conocophillips.com> Sent: Wednesday, March 4, 2020 3:26 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]KRU 1J-1051-1 (PTD 207-028, Sundry 320-019). KRU 11-107(PTD 207-107, Sundry 320-018) RPPG Retreatment Sundry changes Attachments: 11-1051-1 RPPG B MBE Re-Trtmt Proposal_3-4-2020.doc Follow Up Flag: Follow up Flag Status: Flagged Victoria, Attached is a revised procedure as you requested. There were no deletions to be made in the procedure work steps, so no text needed striking out. I put some text in red for work steps to shoot more perforations in the liner and to possibly add some Tail slurry with fibers. I labeled the tail slurry with fibers as an 'Optional' step, because we may or may not perform on this step during the job. If opportunity to pump the job comes up before we have our final fiber recipe determined and approved by the MBE team, that we would prefer to pump the RPPG job without fibers rather than delay the pumping the job. I also added some information to the proposal above the procedural steps to include discussion of the new (PROF that we performed 2/17/20 that verified the MBE at —9930' is still open. All the other information remains the same. I request approval of the attached updated procedural plan. Thanks, John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, March 4, 2020 8:25 AM To: Peirce, John W <John.W.Peirce@conocophillips.com> Subject: [EXTERNAL]KRU 1J-1051.1 (PTD 207-028, Sundry 320-019). KRU 11-107(PTD 207-107, Sundry 320-018) RPPG Retreatment Sundry changes John, Please make changes to the existing procedure by striking through deletions and making additions in red. Email the revised procedure for review and approval. We will handle these changes via email. Tha nx, Victoria Victoria Loepp 10 Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeppa,alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal low. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepo@alaska.aov From: Peirce, John W <John.W.Peirce(a@conocophillips.com> Sent: Wednesday, March 4, 2020 8:07 AM To: Loepp, Victoria T (CED) <victoria.loeppc@alaska.gov> Subject: Re: 11-105L1 RPPG Retreatment Procedures 10-403 Approval Victoria, We are still planning to get 1J-1051-1 RPPG Treatment Procedure pumped per the Sundry approvals attached. Timing for pumping the job is being worked, but we expect to pump it sometime this Spring. Our MBE team has been reviewing the planned treatment. We believe based on how the well treated during the last RPPG treatment on 12/5/19, that we should probably add an additional 5' of large hole perforations at 9920 — 9925' RKB in the liner near the MBE. We have an existing pert interval at 9925 —9930' RKB in the slotted liner, but adding some more perfs before the retreatment should help to get more RPPG slurry through the liner to the MBE before pressuring out. On the last treatment, we didn't quite get as much slurry away as we would have liked before pressuring out, and maximum treating pressure during the job was higher than we expected at 1930 psi, so it may help to add an extra five feet of perfs. The 10-403 approval attached below did not request approval for additional perfs, so I believe I'll need to send an updated 10-403 to AOGCC for approval to supersede the 10-403 approval below. Is this correct? One other minor change to the procedure that we would like to propose is to add a very small volume of fibers to our Tail RPPG slurry just before we call Flush. We don't know for sure how many barrels of Tail slurry we would pump with fibers because it depends on pressure response we'll be seeing during the job. I would guess the total volume of slurry with fibers would likely be less than 50 barrels. The fibers are to add some shear strength to cured RPPG slurry displaced into the MBE in the near wellbore region. This may give us a more resilient treatment. Adding fibers to RPPG slurry was not mentioned in the 10-403 (below) because this is a brand new treatment modification that we want to field test. If approved, this would be the first RPPG job with fibers added to the slurry. This should result in some new learnings. Beyond the request for approval to add an additional 5' of new perfs and a small amount of fibers to the tail slurry, no other changes are requested. Should I send over new amended 10-403's? Thanks, John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office 11 Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Wednesday, March 4, 2020 8:25 AM To: Peirce, John W Subject: KRU 1J-1051_1 (PTD 207-028, Sundry 320-019). KRU 1J-107(PTD 207-107, Sundry 320-018) RPPG Retreatment Sundry changes Follow Up Flag: Follow up Flag Status: Flagged John, Please make changes to the existing procedure by striking through deletions and making additions in red. Email the revised procedure for review and approval. We will handle these changes via email. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793.1247 Victoria. Loepp(a.alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeop@aloska.gov From: Peirce, John W <John.W.Peirce@conocophillips.com> Sent: Wednesday, March 4, 2020 8:07 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: Re: 1J-1051-1 RPPG Retreatment Procedures 10-403 Approval Victoria, We are still planning to get 1J-10SL1 RPPG Treatment Procedure pumped per the Sundry approvals attached. Timing for pumping the job is being worked, but we expect to pump it sometime this Spring. Our MBE team has been reviewing the planned treatment. We believe based on how the well treated during the last RPPG treatment on 12/5/19, that we should probably add an additional 5' of large hole perforations at 9920 — 9925' RKB in the liner near the MBE. We have an existing pert interval at 9925 —9930' RKB in the slotted liner, but adding some more perfs before the retreatment should help to get more RPPG slurry through the liner to the MBE before pressuring out. On the last treatment, we didn't quite get as much slurry away as we would have liked before pressuring out, and maximum treating pressure during the job was higher than we expected at 1930 psi, so it may help to add an extra five feet of perfs. 12 The 10-403 approval attached below did not request approval for additional perfs, so I believe I'll need to send an updated 10-403 to AOGCC for approval to supersede the 10-403 approval below. Is this correct? One other minor change to the procedure that we would like to propose is to add a very small volume of fibers to our Tail RPPG slurry just before we call Flush. We don't know for sure how many barrels of Tail slurry we would pump with fibers because it depends on pressure response we'll be seeing during the job. I would guess the total volume of slurry with fibers would likely be less than 50 barrels. The fibers are to add some shear strength to cured RPPG slurry displaced into the MBE in the near wellbore region. This may give us a more resilient treatment. Adding fibers to RPPG slurry was not mentioned in the 10-403 (below) because this is a brand new treatment modification that we want to field test. If approved, this would be the first RPPG job with fibers added to the slurry. This should result in some new learnings. Beyond the request for approval to add an additional 5' of new perfs and a small amount of fibers to the tail slurry, no other changes are requested. Should I send over new amended 10-403's? Thanks, John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office 13 Loepp, Victoria T (CED) From: Peirce, John W <John.W.Peirce@conocophillips.com> Sent: Wednesday, March 4, 2020 8:07 AM To: Loepp, Victoria T (CED) Subject: Re: 1J-1051-1 RPPG Retreatment Procedures 10-403 Approval Attachments: 11-1051-1 APPROVED 01-28-20_10-403 RPPG M BE TRTMT Sundry Application.pdf, 1J-107 APPROVED 01-28-20_10-403 RPPG MBE TRTMT Sundry Application.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, We are still planning to get 1J-1051-1 RPPG Treatment Procedure pumped per the Sundry approvals attached. Timing for pumping the job is being worked, but we expect to pump it sometime this Spring. Our MBE team has been reviewing the planned treatment. We believe based on how the well treated during the last RPPG treatment on 12/5/19, that we should probably add an additional 5' of large hole perforations at 9920— 9925' RKB in the liner near the MBE. We have an existing pert interval at 9925 —9930' RKB in the slotted liner, but adding some more perfs before the retreatment should help to get more RPPG slurry through the liner to the MBE before pressuring out. On the last treatment, we didn't quite get as much slurry away as we would have liked before pressuring out, and maximum treating pressure during the job was higher than we expected at 1930 psi, so it may help to add an extra five feet of perfs. The 10-403 approval attached below did not request approval for additional perfs, so I believe I'll need to send an updated 10-403 to AOGCC for approval to supersede the 30-403 approval below. Is this correct? One other minor change to the procedure that we would like to propose is to add a very small volume of fibers to our Tail RPPG slurry just before we call Flush. We don't know for sure how many barrels of Tail slurry we would pump with fibers because it depends on pressure response we'll be seeing during the job. I would guess the total volume of slurry with fibers would likely be less than 50 barrels. The fibers are to add some shear strength to cured RPPG slurry displaced into the MBE in the near wellbore region. This may give us a more resilient treatment. Adding fibers to RPPG slurry was not mentioned in the 10-403 (below) because this is a brand new treatment modification that we want to field test. If approved, this would be the first RPPG job with fibers added to the slurry. This should result in some new learnings. Beyond the request for approval to add an additional 5' of new perfs and a small amount of fibers to the tail slurry, no other changes are requested. Should I send over new amended 10-403's? Thanks, John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office 14 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS pEC A,V' U 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate Q Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: RPPG MBE TRTMT 0 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number. Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ Stratigraphic❑ Service 0 207-028 3. Address: P. 0. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-23346-60 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 1J-1050 ADL 25661, ADL 25662 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NIA Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11,571 feet Plugs measured None feet true vertical 3,661 feet Junk measured None feet Effective Depth measured 11,565 feet Packer measured 0 feet true vertical 3,660 feet true vertical 0 feet Casing Length size MD ND Burst Collapse CONDUCTOR 78 feet 20 108' MD 108' TVD SURFACE 3,356 feet 10 3/4 " 3,387' MD 2254' TVD PRODUCTION 7,680 feet 7 5/8 " 7,707' MD 7707' TVD LOTTED LINER 3,725 feet 4 1/2 " 11,565' MD 3660' TVD Perforation depth: Measured depth: 8155 -8522,8722-9818,9540-9545,9925-9930,10075-10592,10849-11521 feet True Vertical depth: 3699-3676. 3672-3659, 3659-3659, 3660-3660, 3665-3656 3654-3659 feet Tubing (size, grade, measured and true vertical depth) 4.5" L-80 7,324' MD 3,642' TVD Packers and SSSV (type, measured and true vertical depth) PACKER = ZXP LINER TOP PACKER 7288 MD 3,636' TVD PACKER = ZXP LINER TOP PACKER 7,465' MD 3,661' TVD PACKER = HRD ZXP LINER TOP PKR 7,820' MD 3,719' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): WA 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 Priorto well operation: - - SHUT-IN - - Subsequent to operation: - - 557 - e 14. Attachments (required per 20 A C 25.070, 25.071, 8 25.283) 15. Well Class after work: Daily Report of Well Operations O Exploratory ❑ Development ❑ Service O Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 71 WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-521 Contact Name: John Peirce Authorized Name: John Peirce Contact Email: John.W.Peirce@cop.com Authorized Title: Sr. Wells Engineer Contact Phone: (907) 265-6471 Authorized Signature: � _ Date: 112-12-0 - Form 10-404 Revised 4/201 VTL -3/+/.7 a RBDMS JAN 0 3 2020 Submit Original Only /A ?A#jv W, KUP INJ ConocoPhillip5weg Attributea Alaska. Im IQ FIeH Nemo NIPPLE WELLNAME 1J-105 WELLBORE 1J -105L1 IJ1GE11, 1]/f120192i1 i5 PM Last Tag Vedslxlw®Eclarnull AnneUlwn peptn Me) aw Dah Wellnore LasIMM By .......... ............._ .___....._...._. Last 189 1J-1051-1idpiwj HANGER', Ya.O Las( RBV RBaSpn Annohlbn EnG Oace wL11I By Rev Reason:MBE TREATMENTSEENOTES SI2Z20D iJ-1051-1 pproven oven Casing Strings CCxoJCTOR,X04 aeo NIPPLE; caan9 on:cuglon oo(Inl B-Sandslottetl Liner 4112 IO Bn) TuPIMLeI semenln(nRe) set oelNn (11101_. wvLen O... Gmtle ronrnreae 348 7,840.5 11,5650 36604 11.60 L80 BTC Liner Details GAS IlEi: 2A]e Toppled) Top"IdInKlig ToPma19 Ihm p.a Co. xominallo 9n) ],8405 3.)08.0 0994 SLEEVE L1 B- AND Liner Hing IdAv, w110'TBR i000 5.6 (ID5.0") ],860.6 37099 00.49 BE L1 Decepiatle JI SS' 155r L . " tly p 4.890 6URFACE:3p53,088a� I k p ( ID 4.89'1 Perforations S, Slots Gss uEr; 9999.] snot 6LEEVEC:8.8413 rap155,0 Bimsvp ropoKlo 3166) eem mpl LmMJ-105 IMb Oen (enatsm I rrce com 8,155.0 8, 0 3,6983 3min,67 3,676. WS B, 1J-1051-1 4/12200) 32.D SLOT terna9ng solitllsiotietl LOCATOR; 7265 pipe 25" Ion9 x.125" wide SEALASSY', 7M6 87ZL0 9.8180 3.872.3 359.2 B,W ,1J 41102007 32.0 SLOTS A9emating SoliNslone -10511 pipe 2.5' long x.125" wide 9,540.0 9,5450 3,659.7 359.6 WS B,1J-105 9242012 6.0 APERF gHolegun66sp, Clyslal Seat pumped 9,925. 9,930.0 3659.1 36591 WS B, 1J-10% 11882019 6.0 APERF H DUN WlNoow o, 7,W7M0 DEGREE PHASING 10,075. 10.592.0 3,665.5 3,656.2 WE iJ-1D5L1 7—M—M 32.0 SLOTS Ailemaling 9o0d1slovetl DIP. 25" long x 127" de 10,649.0 11,5210 3,654.3 3"9.5 WS B, 1J -105L1 4/12800> 32.0 SLOTS Alternating solidlslo6etl pipe 2.5" long x.125" wide DIrewd! wIJ:µ T]84.a Cement Squeezes T'w—Bfilm jNp) I 7W 11 roP3i1B1 elm y66 l 1 38e)) Sire) peF skirt no. com 9,5400 9.5450 3,8597 3.659.6 L 91242012 SQUEEEZE 9,54001 9545.0 3,bbU / 3,659.6 GEL SQUEEZE IWIUIZUIJ Dsem Lm HN: 7,6ap.6 Notes: General 8 Safety 78118 BSeM lbq' LEM; TJ6r.6 End (Ane An.. 7MQ 6�-111,M 4 01] NOTE: Coil Tubing RPPGTreatmeni UBLb510BMBEin1J-105L1 TI 013 114.1E. PROF III MODIFICATION -PUMPED 3100 LBS(4MM) CRYSTAL SEAL INTO' B' MBE 550 IMMB 6:7.70107,TYtO PR0DVCTI0N,s7 ,Nd4 W24/2)12 NOTE: PROFILE MODIFICATION -PUMPED 2090 LES(4MM) CRYSTAL SEAL IWO B"MBE41ISSO smrs: e.lxoasz0 61LTa', a>E.08,6100 GELSOUEIM,9.5 0. GEL6pUEEM;9.5 oIos APERF: 9,SW O-SWO .11F;9,015.90da— 6Lor6', Io.m501958x.o SWTS:10,849611,5110 66eM SYNM Imr; r. 8106_ 115850 KUP INJ ConocoPhillips Alaska, Inc. WELLNAME 1J-105 WELLBORE 1J-105 fa-1os.1v31rm1aznee vM Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Va0.'+IWe^nR4eke, Toon )), TOP mcI roP(nx8) ttuLB1 f) Des com Run Oan IO VnI ........... .,......... ........... _.... HANGER: no ],8090 3.]1].0 80.72 8 pB-6 PLUG-pRON 10/29/201 0.000 PRONG I 9 Perforations & Slots snM wn. CONDOGTOR', VO -1060 xlPPlf.e%.3 Twill BLm InKB) TOME) ILMLBI BIW (TVD) ImcBl LlnYeazore Om IeM1WSIR 1 type Cmm 8,8630 91769.0 3.821.1 3,8130 WS A2, 13-105 4l2&200] 320 SLOTS Altercating solialsloned GAS UFr; Zms pipe 2.5 -long x.125" wide 10,068.0 11,882.0 3,810.0 3,822.4 WSA2,1J-105 426200] 320 SLOTS ABemanng solid/Sloned 1 pipe 251009 x .125' wide 6uREn 12.3s.,3868— ,3868— Mandrel Inserts s, an GASUFT;EM7 an N TOP M.)View TOPnMBI Me) MeW MWH LatcM1 PwdEoE GD IM) saw Type Type lid TRORun load Run DM* I com sLFEVEC: e.m1.3 1 2.26].8 1,853.] G1MC0 KBMG 1 A LIFT DMY B15 0.000 0.0 628200] 11 6.393.] 1 3, 87.0 IGAMCO Ird.0 I i GA5UFT IDMY SEK -t I 0.000 1 0() 42&200 l0WTOR; Taws Notes: General S Safety sF LAS6r:7,aase End Dale AnnomWe 811012013 NOTE: PROFILE MODIFICATION- PUMPED 310 LBS (414M) RYSTAL SEAL INTO "B"MBE@9550 9242012 NOTE: PROFILE MODIFICATION -PUMPED 2090 LBS(4MM) CRYSTAL SEAL INTO "5-MBE@9550 &2/2011 NOTE'. View Schema&: Mol Alaska Sctlemanc .0 WINDOWD.7S P7.389.0 0.5aM D—LEM: 7.280{ 7,aW 3 D-awd D- HH. 7,3U.s 7,611 a WINrPw B;T 07G-7Md PLUG& PRONG; 7AM0 B Seq LYIx IEM: 7,.a 7..25 6se. WS HH:]]ry, Oses.. PRODUCTION: n ",8314 3LUTs:6.BA..neo— SLOT6:IO,L�611.892.0� AAM ebRy LM:7.83J.A. 11,]}50 1J -105L1 RPPG MBE TREATMENT DTTM JOBTYP SUMMARYOPS START 11/28/19 MISC. CAPACITY RIH WITH 2.0" OD HSD GUNS, 6 SPF, 60 DEGREE PHASE, SHOOT SUSTAINMENT HOLES IN B LATERAL LINER FROM 9925' TO 9930' CTMD, F/P TBG TO 3000', VERIFIED ALL SHOTS FIRED, READY FOR FULLBORE RPPG, JOB IN PROGRESS. RDMO CT UNIT. 12/5/19 MISC. CAPACITY PUMPED FULLBORE RPPG TREATMENT TO OPEN B LAT MBE AT SUSTAINMENT -9930' RKB. FRESH 5' PERF INTERVAL SHOT OVER MBE AT 9925-9930' RKB (SEE WSR 11/28/19). PUMPED 496 -BBL TREATMENT INCLUDING 100 -BBL 2% KCL PRE -FLUSH, FOLLOWED BY 241 -BBL SLURRY CONTAINING 2% KCL PLUS 5940# RPPG PRODUCT. DISPLACED SLURRY TO MBE WITH 21 -BBL 2% KCL AND 134 -BBL DIESEL FP (155 - BBL TOTAL DISPLACEMENT, SWAPPED TO DIESEL EARLY DUE TO WHP PRESSURE INCREASE). GAINED APPROXIMATELY 1930 -PSI NET PRESSURE DURING TREATMENT PUMPING 2.0-3.6 BPM. SHUT IN SUPPORTED PRODUCER 1J-107 SIMULTANEOUSLY AT START OF PUMPING AND REQUESTED IT BE FREEZE PROTECTED SLOWLY AND BOL ONLY AFTER 48 -HOURS. 12/9/19 PUMPING PUMPED 141 BBLS DIESEL DOWN TBG TO ESTABLISH INJECTIVITY TRACKING ONLY JOB COMPLETE Well To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 14QLED Transmittal RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Injection Profile 2) Signed : Print Name: 20'i02g 32109 RECEIVED READ Cased Hole, Inc. MAR 0 2 2020 Attn: Diane Williams 4141 B Street AOGCC Suite 308 Anchorage, AK 99503 Diane. Williams(dreadcased hole.com 18 -Feb -20 1J -105L1 CD 50-029-23346-60 Date: READ CASED HOLE, INC, 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL: READ-ANCHORAGEO-READCASEDHOLECOM WEBSITE: WWW.READCASEI)HOLE.COM https://readcasedhole-my. sharepointcom/personal/dime_v 11iams readcasedhole wmMocumentvD Dri,dAchivevMeste.platePilesrl'emplaw&MistdbutiontTransmittalSheets/ConocoPhillips_Trn it docx THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J -105L1 Permit to Drill Number: 207-028 Sundry Number: 320-019 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. oogcc.o loska.go v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Je . Price Chair DATED this day of January, 2020. A8nMS1 JAN 312020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AA(;)5 ?An RECEIVED DAN 142020 zA A6GC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforatex*1 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG MBE RE-TRTMNI2l 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COnocoPhllli s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service p 207-028 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50-029-23346-60-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No KRU 1 J -105L1 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25661, ADL 25662 Kuparuk River Field / West Salk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,571' 3,661' 11565 3660 1500psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 108' 108' Surface 3,356' 103/4 3,387' 2,254' Production 7,680' 7518 7,707' 3,820' Slotted Liner 3,725' 41/2 11,565' 3,660' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grace: Tubing MD (ft): 8155-8522, 8722-9818, 9540- 3699-3676, 3672-3659, 3660- 13654-3659 4.500" L-80 7,324' 9545, 9926-9930,10075-10592, 3660, 3659.3659, 3665.3656, 10849-11521 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER = ZXP LINER TOP PACKER 7288 MD and 3636 TVD PACKER = ZXP LINER TOP PACKER 7465 MD and 3661 TVD PACKER = HRD ZXP LINER TOP PACKER 7820 MD and 3719 TVD 12. Attachments: Proposal Summary 0 Wellbore schematic ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ Service O 14. Estimated Date for 1/27/2020 r 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ p WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce John Peirce Contact Name: Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce(a)cop.cam Authorized Signature:Date: Contact Phone: (907) 265-6471 1 f � 20 1 20 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: i/o J ✓hL// Plug Integrity [IBOP Test ElMechanical Integrity Test LJLocation Clearance ❑ Other: FtBDMS 14(�'L)J1AN 312020 Post Initial Injection MIT Req'd? Yes ElNo Spacing Exception Required? Yes No M," Subsequent Form Required: /J - % r APPROVEDy • OVEDBYI Ili IV Approved by: COMMISSIONER t THE COMMISSION Date: THEVV M ,/Z-+ z0 Submit Form and rm io-a a sed 4 17 Approved application is valid for 12 months from the date of appro a . N/ A �ahmeoss �" ouplicare 1�L KUP INJ WELLNAME 1J-105 WELLBORE 1J-105 ConocoPhlllips Well Attributes Max Angie & MD TD IFIeW Name IWeIIMreAPWWI — (Wellbore 9tatuz Icy°) MO IXNB) Pct Bhn (XKe) Ala9148, Ito. WFCT CGK GnnJmpinwinn _IN.I J9fi 9AEfi Efi ++>i4n NIPPLE + IRS.+n1AA3'.ID'.YPM Last Tag VertwlxM1m age, (ideal Annoation I Depth ants) I End Ons,Wintore leaf Red By ................................................... Last Tag: ii -105 triPiwj HANGER:2ap Last Rev Reason Aanadtlan End Data wellmre teat Mae av REV REASON: ADD PERES L-105 mcanej Casing Strings CONDUCTOR; mutm.o NIPPLE, 9493 Gas I". 2257.a Casing Descrip4on CONDUCTOR 00 (in) 20 10 (in) Tap (.as) 19.12 30.0 Jack Depth (nKB) Set Depth D)... Wai D... Grave 108.0 1 (N 06.0 94.00 H40 is TM1reae WELDED Coln D.Obtnn DID (m) to (in) Tap axle) SM Depth axle) SO"Sn"(ND)... Use (L. Green SURFACE 103 14 9 95 30.5 3,386.8 2,254.4 45.50 L40 Top TM1reae BTC Casing Description OD (in) IDIS ToptMLa) Set Dep@(XKD) Set Depth IT" .. Lee (I GRtle Top TM1reae WINDOW D 8 7.00 7,348.0 7,363.0 3,647.1 Casing Disniption DD (1n) In de) Top (nK8) Set Depth (EKE) Set Depth (ND)... glvLen (1... Gratle Top TM1re9e SURFACE;Wtr3.ses.e_ WINDOW 8 7.00 7,707.0 ],]22.0 3,703.3 Casing Description DD (In) ID (In) Top d Kid Set Depth (ME) Set Depth Dratin . WIILen d... Gmtla Tap TMestl PRODUCTION 7W 8.87 27.4 8,8384 3,8203 2970 L-80 BTCM GAS LIR: a.S%i] Casing Description DSantl Liner LEM Do (In) 4112 to (in) Tape (added 3.96 7,2884 Set Depth dtKB) SO Depth RVDR. Wtlten(I... Gratle 7,4948 3,666.2 12.60 LA0 Top Thre9tl (BTM SLEEVE -C: 5.013 Liber Details LOwTORI>,ER5 SEALASSY(Ezaae Top MEl3) TaP(NDGPXTu alp1-11') Item Des Cum Nominal (in) 7,2884 3,8359 7945 PACKER 0D-71,11)LEMZXP 5-112"x]bui Liner Top Packer TOP 4.940 7,307S 3,639.2 80.46 CSR L2 D D LEM Cast., SBR 10947 C x 4.750 435" ID 7,327.1 3,1342.3 81.50 BUSHING U D -AND LEM Reducing XO Bushing 1'Hydrd 3.930 WINOONbD; 7..0r7.sm.o 563 x 4-112" IBT 7,332.3 3.643.0 8177 HANGER L2DSANDLEM Above Hook Hanger 3.960 7,343.3 3,6445 82.35 HANGER aDSAND LEM Inside Hook Hanger 3.588 7,4915 3,665.6 80.39 SEALASSY L, D- AND LEM Baker Seal ssembly4-17TL 3.860 Be- I! DSantl mer LEM', 7,269.4 Casing D6scommon D -Sand Liner HH ODain) 4112 ID (Ind Top (flNB) 3.48 ],3433 Set DepfM1 anted S¢I DepIM1aND)... WIILen 11... GRtl¢ 7,611.8 3686.7 11.60 L-80 iop TMeaa RTC 7,989.5 Liner Details Top Khru Top (TVD)dt¢9) Tup lna (') Item De. Co. Nominal to (m) CSana Una HIN Ese.a EaH a 7,3433 3,644.5 82.35 HANGER LPD-SANDHOOK A Y Baker Model 8-i Hoak Hanger 7 SIE' x 4117' (Inside Cad) 5.600 7,360.0 3,6467 82.39 HANGER L2D-ANDHOOK ABBY Baker Motle11 Hoo 4.000 Hanger 7 SIB" x 412' (Om31de Csg) wwDOw e; 7.70na7,722o ],505.3 3,668.0 79 94 ECP L2D-SAND HOOK ASSY Baker ayzone Exmmal Casing Packer 3.960 Ca¢mg D¢sunptun i Sand Liner LEM o0(in) 412 . 396 ],4648 ,tDeptleaftelu . ,725.4 T..Lan..G 78625 3m1260LT op Thleao IBT Liner Details PLDG6PRONG:1,W40 Top build rap(TVIRM N Topinull°) Item Des Co. Nominal ID on) 74648 3,661) 8128 PACKER LI BSAND LEM ZXP 5-12'x7-5113" Liner Top 4.767 Packer TOP 7,483.8 3,664.3 80.65 CSR _1 B -SAND LEM 10947 Casing SBR26" OD x 4.750 4.75 a sem Dna LEM:i m 8- 7,503.5 3,667.6 —80 GD BUSHING —8121 LiB-AND LEM XO Bushing 8112"Hytlril53x- 112" IBT 3.958 asene mer HH; Elms 11 7,6985 3,699.3 RANGER L1 BSAND LEM LEM Above Hook Hanger 3.688 Eam.e 7,703.3 3,7004 81.18 HANGER L1 B -SAND LEM LEM Inside Hook Hanger 3.688 7,809.3 3,]1].1 80.72 IN L B -SAND LEM Camco"OB-6r'Nlpple,ID. 5 ". 3.562 IBT vaooucnoN;nae,msa 7,859.2 3,724.9 81.40 SEALASSY L1B-SAND LEM Bakei Assembly 4-12"77 3.860 Box up Casing Description B -Sand Liner HH OD (,n) 4 IDdn) Toper'.) 348 7,7033 Setmparatel) Sa,IR.RM(N ] 37300 TOprhmmh BTC Liner Details Take We) Top(ND)RUNS) Top met P) INS Dee Co. Nominal to (in) SLOTS;e,maR97600� 7,703.3 3,700.4 81.18 HANGER Ll B AND Baker Model B-1 Hook anger751"x 5.640 12" (inside) 7,720.0 3,7030 plus HANGER L18 -AND Baker Model U-1 HOOK anger) "x4 5640 12" (Otn.9ide) Casing Description 00 (in) ID,a,iop (XKe) SN Oepm aMKEd Set Earth(ND)... WIIUse 11... GRtle Top Threae A -Sand Slotted Liner 4112 3.48 ],8200 11,725.0 3822.7 11.60 L-80 BTC./TR Liner Details Top ante) TopINO)anted Topmdl9 nem Des Com Nominal ID (In) 7,8200 3,718.8 W68 PACKER A -SAND BY. TAY Baker 'HHD ZXP Liner Top Par 5.500 7,839.0 3,721.8 81,03 MAL -NIPPLE A AND"RS'PeckoRSeal Nippe,6. D1.T' 4.870 ID 7,841.8 3722.3 81,08 HANGER A- AND 5.5"X7.63' 659' 4.850 OD/4.85 " ID 7,851.6 3,]23.0 81.26 SBE A -SAND 19047 Seal Bore Ext, 629"00/475"ID 4.756 s1UTs', +a,om.wtm2a— Tubing Strings Tubing Description slang TUBING 4112 Ma._mdn) rop (tile) 3.99 23.0 SM De Pm lx.s¢t Depth ND)(._we(NOR IntendsTop Connection 7,323.9 3,641.8 12.60 L-80 IBT Completion Details rop [7)D) Top (tile) (xtD) TOPmal (°) IMm D¢¢ Cnm Nominal ID hi 23.0 230 606 HANGER TUBING HANGER wI PUP 3.992 498.3 497.7 7.11 NIPPLE CAMCO DB NIPPLE RAPS Q691.3 3,494.6 69.09 SLEEVE -C JCNUI SLIDING SLEEVE (CLOSED ON 6292007) 3.812 7295.5 3 637.2 79.82 LOCATOR JILOCATOR 3.880 A9aM slm.a m.,; za'm.a 7296.6 3,63]3 ]9.88 SEALASSY GBH -22 LOCATING SEAL ASSEMBLY 3.880 n,72so ConomVPhillips KUP [NJ WELLNAME U-105 WELLBORE 1J-105 Alaska.lnc. 1-1 11 ISS. ln3nmo3.X3e PM Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) YxEwl uhei NFNa9 ToplrvO) Tp XKB Top Incl Lcom Run Dale IO (in) ................................................. HANGER. 000 1,8090 3,1110 80.12 PLUGB D8-fi PLUG -PRONG PRONG OY29I201 9 OA00 Perforations 8, Slots Sat Den CONDUCTOR; 30.0.1 Pb0 `d`PUi Top(SHE) BI 11(1.) Me) Me DVD) (I Linked Lane pate (eho6M ) Type LOm 8,863.0 9,769.0 3,821.1 3,813.0 WS A2, 1J-105 4/2612007 32.0 SLOTS Alternating solidlslOned GAS LIFT: ZW,S 1 pipe 25" long x.125 - wide 10,068.0 11,6820 3,810.0 3,8224 WS A2, 1J-105 426/2007 320 SLOTS Alternating soldlsloned I pipe 25" long x.125" wide SURFACE', X.S3,3ESE� Mandrel Inserts st ali GAS LIFTI a SO on Top(NO)Valve N Top (XNB) Me) Make Model 00 (in) Sew type Latch Port51u Type (In) TRO Run Me Run. I ..in .LEEYE-D, 0e81. 3 1 ?267.8 1 1,853.7 ICAMCO KBMG 1 GAS LIFT DMY BK -5 0.0( 0.0 6rz8I200J 21 6,3037 I 3,Jd/U JUAMUU IKBMU 1 1 JOAN LIFT IDMY BEK-5 I QU001 OD 14U812007 LOCATOR: 7.X5.5 Notes: General & Safety. _ _ - SEN.AMY; 7,2.8 End Late Annotation 8/1012013 NOTE. PROFILE MODIFICATION - PUMPED 3100 LUIS(4MM) CRYSTAL SEAL INTO "S"MSE@9550 9124/2012 NOTE:PROFILEMLdLd1OATION-PUMPED 2090 LBS(4MM) CRYSTAL SEAL INTO "B"M6E@9550 322011 NOTE'. View SCM1ematic w/Alaska Schematic9.0 WINDOW D, 7,31067,303.0 DSendWe, LEN 7Ged4- I.. DSaeE tmx HK', 7,M4 76116 WINDOW B. 7 RpS7,Y120 PLUG a PRONG: 7.0]3,0 B.Sne Lne,LEM:7,d61.& 78515 &Smtl Urer HH: ],.n1 CEIG 8 PRODUCPON: Z7.4�09a.4 SLOTS', 9,SWi SLOTS:1Q53B611,BBZ0� ASeM &bbE Wer 7.BID0. 11,77.,.0 KUP ]NJ WELLNAME 1J-105 WELLBORE 1J -105L1 Role,COriocomillip5 Well Attributes Max Angle 8 MD TD a..vr tiWr"X FIeIEName WellboreA n We11Wre51a1us 1611,61 MO05,46 117M71 lxKB1 NesILe.InD. 6.ifi 8,30545 11.5]1.0 1J-1fiL1, 1/13FNID333'.%GM Last Tag Vendeet. SDUR¢Ij Annceii Depth MKS) pon Oafe wNIINore 1 Use MW By ......................... ........................ ...................................... ... Last Tag: I 1J-IUDL1 luipAS HANGER, M Last Rev Reason Annodeon Ena Dane w6111wre Usem6tl ay 77R TREATMENT -SEE NOTES I 522201] IUI litmov., Causing Strings Caamg Dasanpxon oD Onl m(nl rop lxKBl "N")se Depth TWO)... MLen p...Gmaa TOP Theld B -Sand Slotted Liner 412 Joe 346 ],840.5 11,565.0 3,660.4 11.60 L-80 BTC cououcroa Poa10e.0 Nlpvte, 49e3 Liner Details NoremauD AAs upr, zzs/.e roPlnKB),64 mPPVD) (xrce) Top 4 Ikre Dea Co. pn) ],840.5 3,]09.0 89.9OUSnd 4 SLEEVE L1B-SAND HR Liner Seeing Sleeve wl l0'TBR 5.000 5.5" (105.0") 1 ],860.6 3,]08.9 90.4956E LIBSANORecepfapleJt 5,5'155#LBU55"ROyb 4.890 SURFace, 3p.5.3.39i1 X P ( ID 4.89") Perforations & Slots GASUFT.Eta i Shot Dens Top(Tod) pareVvD) (.he.. SLEEVEL: B,W13 Top (ME) Me MB) IM(B) IM e) Linke42one Dale I Type Coln 8,1550 8,522.0 3,698.7 3,676.3 WS B, U-1051_1 4/12/2007 32.0 SLOTS Alternating solidl70aed pipe 2.5" long x 125'wide LOCATOR. i, M.5 SEALASSY 7zi 8,7220 9,818.0 3,672.3 3,6592 W WT=J -1051_1 41122007 32.0 SLOTSIternalin0solid/slotted pipe 25"long x 125"wide 9,540.0 9,5450 3,6597 3,6596 WS B, 1J-105 9242012 6.0 APERF Big Hole guns, sp, Crystal Seal pumped 9,925.0 9,930.0 3,659.1 3,659.1 WSB,1J-105L1 1112&2019 6.0 APERF HSD GUN PF, WINOOW D 7SNa.O7,3atl0 DEGREE PHASING 10,075.0 10,592.0 3,6655 3,656.2 WSB,1J-105L1 41121200] 32.0 LOTS Altemiong solidlslpned pipe 2.5" long x.125" Wide 10,849.0 11,521.0 3,6543 3,6595 WS8,1J-1OSLt 41121200] 32.0 SLOTS ARemaBng sonsisloned I I I pipe 2.5" long x.125" Woe one,O-anc .r LEMl TailCerneri45queezea ].spas ToplrvDl To, (MET Bi lMca) Ixrcal acre TVm (xKBI oea dart Dam Co. 9,5411.0 9,545.0 3,659) 3,659.6 GEL 9124/2012 SOUEEEZE 9,54001 9,5450 31m9/1 3,659.6 I GEL SQUEEZE 8110/2013 Dsam urer HHnsa3s Notes: General B Safety sad xe Beard Uder LEM: i"Sa" i,eazs Eng Date annotation OPPG 4/30/201] NTE Coil Tubing Rm Treatment 3308 LbsBMBE in 1J-1051_1 B.ea,tl llrerHX: i,ina3 >,se3e &102013 NOTE PROFILE MODIFICATION -PUMPED 3100 LBS (4MM)CRVBTAL SEAL INTO "e"MBE@9550 WINPRODUCTION IN, 2T..'al2p p800wnoN;nae,maa 9242012 NOTE: PROFILE MODIFICATION-PUMPE02090 LBS 4MM CRYSTALSEAL INTO"B"MBE 9550 ( ) � stars; a 1..o-esazo� 7 SLOTS; t MD OL9em0 GEL SOUIDUE, 9 SAO E USE GEL SOUEEEZE, 95 W.ONC _ APENU 95 CO APERF;eM5.0L%aai SLOTS:Ipom5 10,SP1.0 SLOTS; 10,9aB 611 $]t0 Some. MODrer, ],GO.P 11,5630 Proposal for 1J -105L1 to 1J-107 RPPG B MBE Retreatment 1J-105 Tri-Lat injector was drilled & completed in 2007 with West Sak A, B, & D Sd laterals. 1J-10511 B Lat has a 4.5", L-80 slotted liner. The first B MBE occurred 4/5/12 from 1J-1051-1 to 1J-1031-1 producer. A 5/26/12 IPROF found B MBE at 9550' RKB taking all PWI. On 9/24/12, a Crystal Seal job sealed the MBE for -3 months, then 3/24/13 ]PROF verified the B MBE at -9550' had reopened. An 8/10/13 Crystal Seal retreatment was pumped, and treatment -3 years until the next MBE occurred 3/9/16. A 5/25/16 IPROF in 1J-1051-1 found new MBE at -9750' RKB. On 4/30/17, an RPPG treatment sealed MBE at 9750' RKB and the treatment lasted until 10/20/19 when a new MBE occurred from 1J-1051-1 to U-107. This is the first MBE from 1J-1051-1 to 1J-107. An 11/8/19 IPROF in 1J-1051-1 found the new B MBE at -9900' RKB to 1J-107 B Lat. A fullbore RPPG job on 12/5/19 treated the MBE with 5940 lbs of RPPG, but post -job SWI response shows 1J-1051-1 not regaining positive WHIP yet with over -30 days at 500 - 1000 BWPD. It's assumed the MBE treatment may have failed, but it's also possible the MBE is sealed, and low BHP matrix is taking SWI with WHIP on vacuum. Thus, CT F&S and IPROF will be performed (per separate procedure). If new IPROF shows B MBE at -9900' RKB is still open, this procedure will be ready to fullbore pump an RPPG retreatment to the MBE ASAP. Post-RPPG retreatment, 1J-1051-1 will be returned to SWI to evaluate retreatment results before restoring SWI to all 3 laterals. 1 J-1051-1 is currently configured for B MBE treatment. The 'A' Lat was isolated by a Plug set at 7809' RKB on 10/29/19. A 'B' Diverter was set 11/7/19 at 7696' RKB, and a 'D' Iso-Slv was set 11/7/19 at 7332' RKB to isolate D Lat. A pert interval was shot 11/28/19 at 9925 - 9930' RKB near B MBE at 6 spf, 60 deg ph, using 'big hole' charges. ASF. No additional perforating is needed. It is proposed that the B MBE at 9900' RKB be retreated with RPPG (Reformed Polymer Particle Gel) to return 1J-1051-1 to SWI service. Procedure: Pumping: Verify that a post-RPPG job IPROF (of early 2020) on 1J -105L1 was performed and evaluated as indicating that an open B MBE still exists at +/- 9900' RKB before proceeding to step 1. 1) At -12 hours before the RPPG job, put 1J-1051-1 on SWI at 1000 BPD to displace Diesel FP and gas head from tubing to open B MBE to 1J-107. RU pumping equipment at 1J-105 the next morning. SI 1J-107 and 1J-1051-1, then immediately fullbore pump into 1J-1051-1 with 151 bbls (volume to MBE) of 2% KCL Brine at some steady rate between 1.5 to 4.0 bpm (rate TBD based on rate needed to let pump keep up with vac rate acting on well), followed by XX bbls of RPPG slurry mixed with 2% KCL Brine while adding 0.5 - 0.75 lbs/gal RPPG on -the -fly. Continue pumping 0.5 - 0.75 ppg slurry at steady rate until WHIP reaches 200 psi, then determine when to Flush by swap to 108 bbls of 2% KCL Brine displacement, followed by 41 bbls Diesel FP to 2000' TVD (2684' RKB), followed by Shutdown to trap WHP leaving RPPG treatment -1 bbl underdisplaced to B MBE. RD equipment. Wait 48 hrs for RPPG to cure in MBE to crosslinked non -flowing RPPG before returning 1J-1051-1 to injection or 1J-107 to production. Return 1J-1051-1 to SWI. Evaluate results of RPPG MBE treatment. Well Lo To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 a • Transmittal RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Injection Profile 2) Signed Print Name: 207020 3 146 6 DECEIVED READ Cased Hole, Inc. NOV 1 9 2019 Attn: Diane Williams 4B street Suite n ®GCC Anchorage, AK 99503 / 1 Diane.WilliamsC(Dreadcasedhole com 07 -Nov -19 U-1051-1 CD 50-029-23346-60 Date : I I /Z00 1� READ CASED HOLE, INC, 41418 STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-6951 E-MAIL: READ-ANCHORAGE((aREADCASEDHOLECOM WEBSITE: WWW.READCASEDHOLE.COM https:!readcasedhole-my.sharepoint.com/pemnalidiane williams_readcasedhole comlDocumenWD Dm'e'Achivev:NasterTempla[eFilestl'emplatea/DisMbud mTraasmitt Sheets/Conocophillips Transmitdocx THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J -105L1 Permit to Drill Number: 207-028 Sundry Number: 319-521 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .a0gcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 'U Jerem M Price Chair DATED this`s day of November, 2019. RBDMS±�NOV 18 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED NOV 13 2019 A®GCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ i� For ID -403 p Q � ��Lth Suspend ❑ Perforate O • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG MBE TRTMTA 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service ❑ • 207-028 3. Address: 6. API Number:$10-0s1_ , -(0 P. 0. Box 100360, Anchorage, Alaska 99510 5002923-4AW0 • 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1J -105L1 Will planned pertorations require a spacing exception? Yes ❑ No ❑' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25661, ADL 25662 Kuparuk River Field / West Sak Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,571' 3,661' 11,565 3,660 1500psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 108' 108' Surface 3,356' 103/4 3,387' 2,254' Production 7,680' 75/8 7,707' 3,820' Slotted Liner 3,725' 41/2 11,565' 3,660' Perforation Depth MD fft) IPerforation Depth TVD fft) ITubing Size: Tubing Grade: Tubing MD (ft): 8155-8522, 8722-9818, 9540- 3699-3676, 3672-3659, 3660- 1 4.500" L-80 7,324' 9545, 10075-10592, 10849- 3660, 3665-3656, 3654-3659 11521 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER = ZXP LINER TOP PACKER 7288 MD and 3636 TVD PACKER = ZXP LINER TOP PACKER 7465 MD and 3661 TVD PACKER = HRD ZXP LINER TOP PACKER 7820 MD and 3719 TVD 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service E ' 14. Estimated Date for 12/4/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ p WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com ee Contact Phone: (907) 265-6471 Authorized Signature: tNr 1J-11Z.I1- E Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 5� ! Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 18 2019 Post Initial Injection MIT Req'tl? Yes ElNo ElBBDMS�NOV Spacing Exception Required?Yest�/ Ei No Subsequent Form Required: / -- 1, 01 APPROVED BY �)✓II Approved by: • `"-' COMMISSIONER THE COMMISSION Date: 1 V. a a/ Approved plicat fRAthe date of approval. 'ori Submit F//orm an Attachments in Duplicate Proposal for 1J -105L1 to 1J-107 RPPG B MBE Treatment 1J-105 Tri -lateral injector was drilled & completed in 2007 with laterals in West Sak A, B, & D sands. 1J -105L1 B Lat has a 4.5", L-80 slotted liner. Multiple B MBE's have occurred in 1J-1051-1 The first B MBE occurred 4/5/12 from 1J-1051-1 to 1J -103L1 producer. A 5/26/12 IPROF found a B MBE at 9550' RKB taking all PWI. On 9/24/12, a 1J-1051-1 Crystal Seal job sealed the MBE for -3 months. A 3/24/13 IPROF verified the B MBE at 9550' had reopened, then an 8/10/13 Crystal Seal retreatment was pumped. This retreatment lasted -3 years until another MBE occurred on 3/9/16. A 5/25/16 IPROF in 1J-1051-1 found a new MBE at 9750' RKB. On 4/30/17, an RPPG treatment sealed the MBE at 9750' RKB and this treatment lasted until 10/20/19 when a new MBE occurred from 1J-1051-1 to 1J-107. This is the first MBE from 1J -105L1 to 1J-107. 11/8/19 IPROF in 1J -105L1 found the new B MBE exists at 9900' RKB to 1J-107 B Lat. 1J-1051-1 is currently configured for a B MBE treatment. The 'A' lateral was isolated by a Plug set at 7809' RKB on 10/29/19. A 'B' Diverter was set at 7696' RKB on 11/7/19 (for B Lat IPROF of 11/8/19), Kand a'D' Iso-Slv was set 11/7/19 at 7332' RKB to isolate the D Lat. It is proposed that the new B MBE at 9900' RKB be sealed with RPPG (Reformed Polymer Particle Gel) to return 1J-1051-1 to SWI service. Procedure: Coil Tubing: 1) RIH with pert gun & shoot FOAL large hole perfs in 4.5" OD blank liner at +/- 9895' RKB in D Lat near the 'B' MBE. POOH with gU Verify all shots fired. RD CTU. Pumping: 2) At -12 hours before planned RPPG job, put 1J-1051-1 on SWI at 1000 BPD to displace Diesel FP and gas head from tubing to open B MBE to 1J-107. RU pumping equipment at 1J-105 next morning. SI 1J-107 and 1J-1051-1, and then immediately fullbore pump into 1J-1051-1 with 150 bbls (= tubing + liner volume to MBE) of 2% KCL Brine at steady rate between 1.5 to 4.0 bpm (pump rate will depend on what raWis needed to let the pump keep up with the vacuum rate seen acting on the well), followed by XX bbls of RPPG slurry mixed with 2% KCL Brine while adding 0.5 - 0.75 lbs/gal RPPG on -the -fly. � Ccgtinue pumping 0.5-0.75 ppg slurry at a steady rate until WHIP reaches 500 to 800 psi, then swap td108 bbls of 2% KCL Brine displacement, followed by 41 bbls Diesel FP to 2000' TVD (2684' RKB), followed by shutdown to leave the RPPG treatment -1 bbl underdisplaced to B MBE. RD pumping equipment. Wait 48 hrs for RPPG to cure in MBE to crosslinked non -flowing RPPG before returning 1J -105L1 to injection or 1J-107 to production. Return 1J -105L1 to SWI to evaluate results of the RPPG B MBE treatment. After sufficient evaluation time to verify that B MBE is sealed, 1J-105 will be reconfigured to restore SWI to all three laterals. KUP INJ WELLNAME 1J-105 WELLBORE 11-105 ConocC P fillipsAM ell Attributes MAlaslw,Inc.IW, ,.-,,,n JLVQ API.WI IWe11b...ifve �t}511°1 �MG(mcB) ncL e+m fnxal wr Tc K GPS LIFT; SURFACE; GPS D-Ornr Leer LEM1; D o-sana LAN KRa.: T PLUG S PRONG, 7j f3 B aentl LmrLEM; ]4 ],1 9 S -d War KK; ]T SLOTS; 8663.0-6.]fi8.0— A aLOlaaO.GH.n11,SB20� PSNH &bXM INec'BID0. vno x up IBT L1 B -S. Box up hm am 7 Sal" x4 PNDH001 7518"x4 PNDH001 Packer Com Tap (7,B ToptNGt tnKBl Top Incl t°) -1m all Ccm NomincllO (in) ],620 3,]18.8 PACKER 8068 PACKER A -SAND BS'x].6r BakeC HRD' Z PLiner Top Pkr 5.500 7,839.0 3,]21.8 61.03 SEALNIPPLE A-SAND"R'Peckp eal Nipple,T'0D14.8 ID 4.870 7,841.8 3,]22.3 81.08 HANGER ASA D5.5'•X 7.63" Flax -Lock' Liner Hgr, 6,59' OD/ 4.65" ID 4850 7,851.6 3,]23.6 8126 SBE A -SAND 19047 Seal Bore Ext, 6.29"OD 14.75"ID 4750 I T P)BKB) I INKB) I r) i Item P. i Gom i I ConacKUP INJ WELLNAME 1J-105 WELLBORE 1J-105 oPhillips �'�^' NdsKaE lnc. 1110511nvm1es:GMS, PM Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) vxenl«n.rmoo l«n.p Tnplrvol n,(II B) (nKel Tnp ma 1°I Ges cnm Run Oam 101in) ._........._................_.__.........._....................__................,. HANGER,96 ],8)9.0 3,]1 ].B 80.]2 PLUG$ DB- 6 PLUG -PRONG 10/29 1 0.000 PRONG g .Perforations & Slots skne CONDOCTNRP a]0.1MG PLE W9S Top RUNS) Ben Ut GO Tnp(rvol (flKa) elm (TVD)Gena lnl(BI UnMOZ^ne Oeb (sholsttt I T YM Cam 8,863.0 9,]69.0 3,8211 3,813.0 MS 1J-105 026200] 32.0 SLOTS Alternating SOHNSloned GA6 uFT; 2w].e pipe 2.5" long x.125" wide 10,068.0 11,6820 3,810.D 3,822.4 WS A2,1J-105 412612007 32.0 SLOTS ARernating 6OINGlofted pipe 2.5" long x.125" wi0e SURFACE:30.58.RP,S� Mandrel lnserte 6t Ni OAS LIFi:flSd3.T SLEEVE-c',e661a o^ Topedid N Tap (IMB) (M{B) Make Motlal 00(In) Valor tnkM1 POrt Spo TRORun sery MM Tyce (In) (Pat) Run Deb Com 1 2,2fi].8 1,853.] CAMCO KBMG 1 GAB LIFT DMY BK -6 0.000 "GIN, 200] 2 6,393.] 3,38].0 CAMCO KBMG 1 GAS LIFT DMV BEK-5 0.000 0.0 ] LOGaroavm ,5s Notes: General & Safety. sFALAssr',]]W.9 End Seb Annodtian 4I29I2007 NOTE:MULTI-LAT WELL-1J-105(-SAND),1J-105L1 (BSAND), 1J -105L2 (D$AND) 32/2011 NOTE: View Schematic w/ Alaska Bchematic90 wwOow D: T,Sae.o gxa.O 9242012 NOTE: PRO FI LE M001FICATION-PUMPED 2090 LBB (4MM)CRVSTAL $EqL INTO "B'MBE@9550 81102013 NTE: PROFILE MDDIFICATION- PUMPED 3100 LBS (41AM)111STAL BEAL INTO "B"MBE@9550 66eM Llnar LEM', ],266,4 ]4846 D-Wd liner HH', 7,3113 ].111.1 .tiIN00W B', 770747,7YL.O PLUG & PRONG: 7.DSGO MnNi LMm LEM: ],464.6 1W31- W356'Sane 8 SaneLiner HH', T.1 7MG PRODUCTION', n 4-,639.4 SLOTS; 10068,0-11,102.0� AS -d Gbo Unn .Txo ComxoPhillips Alaskn,lnc. ImII KUP INJ WELLNAME U-105 WELLBORE 1J -105L1 Casing Strings Pp�oven n.tra TOR', adS,ne NIPPLE; 46 Casing Description 0a(in) In (in) Top third) Set Depth marl bel Di(Im... phi ll... Gratle Tap TMeatl BSantl Slotted Liner 41/2 348 7,840.5 11,5650 3,660.4 1150 L-80 AT Liner Details GAS LIR:$351.6 In (Mea Top on, -)a KaI Top Incl I') Ihm Oea bom Nominal l0 (in) 3,709.0 89.94 SLEEVE L16SANDRR Lmer SeNnB leeve w/10'TBR 5.5- i5" (ID 5.0") 5.000 SURFACE: 30.53,..- 7,860.63,7089 904959E LIB AND Receptacle Jt 5.5" 15.5#1 5.5" tlyb X p ( ID 4,89") 4890 Perforations & Slots GAS LIR; EMT Shot SLEEVE -G, 6,W1.3 Top (flNB) aM Me) To MNa) (11K.) Stm( (flKEd B) LIn kM Zane pole ens (ahoryll 1 Type Co. 8,155.0 8,522.0 3,698,7 3,676.3 WS B, 1J-10511 4112/2007 .0 SLOTS Alternating 50didltlaii LOCATOR; 7,365,5 SEAL Assn, T,.I pipe 2.5" long x.125" wide 8722,0 9,8180 3,6723 3,859,2 WS B,W ,1J -105L1 4/12200] 32.0 SLOTS Alternating soli Slotted pipe 2.5" long x.125" wide 9,540.0 9,545.0 3,659.7 3,85.6 WS B, 1J-105 WQ2012 6.0 APERF Big oleguns, sp,2090# Crystal Seal pumped 10,075.0 10,592.0 3,865.5 3,656.2 WE B, IJ -105L1 4/1WO07 320 SLOTS Alternating soliWalpned WINDOW o: 7348 0,7,3810 pipe 2.5" long x.125" witle 18849.0 11,521.0 3,854.3 3,6595 WS B, iJ-10511 41122007 32.0 SLOTS Alternating soliutsloned pipe 2.5" long x.125" wide Cement Squeezes DSend Lear LEM; 7,2pd- Top "m BM frondTop g9bg Bhn I than) IYdi pes Sw"Eme Com 9,540.0 9,545.0 3,659.7 3,8595 GEL 9242012 [4e6.e SOUSEEZE 9,540.0 9,5450 3,659] 3,659.6 GEL SQUEEZE 81102013 Notes: General & Safety End pate Annob ion 42912007 NOTE. MULTI- LAT WELL -IJ -105(A -SAND), 1J-105L11B-BAND), U -1051-t! (D -SAND) GS. me.NN: Laws 7.6118 32/2011 NOTE: View Scbematoe/Alaska Schema ic9,0 PRODUCLON; 2]." M4 asem Liw LEM: 1.4Ws X25 8242012 NOTE PROFILE MODIFICATION -PUMPED 2090 LBS (4MM) CRYSTALSEAL INTO -13- 8/102013 NOTE. PROFILEMODIFICATION-PUMPED 3100 LBS(4MM)CRYSTgL SEAL INTO"6"MBE�ID9550 e s.ne Dn.r HR Tri 7awa 41301201] NOTE: Coil Tubing RPPG Treaunen13308 Lbs toB MBE in 1J-10511 SLOTS; 0,155" Good �AA3� 610]6; B,YQ,09,81a0 APERF; 9,SSpe 5150 et QLT GGEL SQUEEZE: 9,5100 Sam LA C s 7Xb U SLOTS', 10,0]5.013583.0 SLOTS: 10G80.11.R1,0 8-timl peopi Leen T,91a6 11,Sfi50 STATE OF ALASKA " ALAS IL AND GAS CONSERVATION COMMISSIONO REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: MBE GEL JOB El 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory❑ 207-028 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service D 6.API Number: 99510 50-029-23346-60 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1 J-1 05L1 ADL 25661,ADL 25662 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 11,571 feet Plugs measured None feet true vertical 3,661 feet Junk measured None feet Effective Depth measured 11,565 feet Packer measured 7288,7465, 7820 feet true vertical 3,660 feet true vertical 3636,3661, 3719 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 20 " 108'MD 108 SURFACE 3,356 feet 10 3/4" 3,387'MD 2254 PRODUCTION 7,680 feet 7 5/8" 7,707'MD 3820 ��E`'�� SLOTTED LINER 3,725 feet 4 1/2" 11,565'MD 3660 RUTAY19207 Perforation Depth Measured depth 8155-8522,8722-9818, 9540-9545, 10075-10592, 10849-11521 feet A�JGCC True Vertical depth 3699-3676, 3672-3659,3660-3660, 3665-3656,3654-3659 feet AOGCC V Tubing(size,grade,measured and true vertical depth) 4.5" L-80 7,324'MD 3,642'TVD Packers and SSSV(type,measured and true vertical depth) PACKER=ZXP Liner Top Packer 7,288'MD 3,636'TVD PACKER=ZXP Liter Top Packer 7,465'MD 3,661'TVD PACKER=HRD ZXP Liter Top Packer 7,820'MD 3,719'TVD SSSV: NIPPLE 498'MD 498'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED t �j f y 1N 1 e a�CU 7. 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: SHUT-IN - - - - Subsequent to operation: - - 401 - 33 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development❑ Servi4I Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-082 Contact Name:John Peirce Authorized Name: John Peirce Contact Email: John.W.Peirce@conocophillips.com Authorized Title: Sr.Wells Engineer /("4. d 7 Contact Phone: (907)265-6471 Authorized Signature: / .tr"" Date:�j1 / / Form 10-404 Revised 4/2017 + ` 4/q 11RBDMS 1,v MAY 1 9 2017 Submit Original Only • • 1J- 105L1 DTTMS.JOBTYP SUMMARYOPS 4/26/17 NRWO PERFORM PASSING MIT-IA, PULL TYPE 1 ISOLATION SLEEVE AT 7707' RKB, SET DB-6 PLUG AT 7809' RKB, SET PRONG IN DB-6 PLUG AT 7809' RKB, JOB IN PROGRESS. 4/27/17 NRWO SET TYPE 1 DIVERTER IN B LEM AT 7707' RKB, SET NEW STYLE ISOLATION SLEEVE (2.75" ID)ACROSS D LEM AT 7348' RKB, FLAG PIPE FOR DEPTH CORRELATION, JOB IN PROGRESS. 4/28/17 NRWO RIH TO FLAG AND CORRECT DEPTH TO RKB, CONTINUE TO RIH TO FIRE 2.0" OD POWERFLOW PERF GUNS (6 SPF/60 DEG PHASE), TOP SHOT AT 9745' RKB, BOTTOM SHOT AT 9750' RKB, READY FOR RPPG PUMPING, JOB IN PROGRESS. 4/30/17 NRWO RUN #1, UNABLE TO PASS B SAND DIVERTER AT 7707' RKB, RUN#2 TAG AGAIN AT 7707' RKB, PUMP 3308 LBS OF REFORMED PARTICLE POLYMER GEL (RPPG)AT AN AVERAGE .75 PPG CONCENTRATION WITH 70 DEGREE SEAWATER, PUMP 275 LBS POLYSWELL GEL AT .20 PPG, FLUSH WITH 15 BBLS SEAWATER AND PUMP DIESEL DISPLACEMENT WHILE POOH, WAIT 48 HOURS BEFORE FCO, JOB IN PROGRESS. 5/1/17 PUMPING PUMPED 43 BBLS DSL DOWN TBG FOR FREEZE PROTECT( JOB TRACKING COMPLETE) ONLY PUMPED 4 BBLS NEAT METH DOWN F/L FOR FREEZE PROTECT(JOB COMPLETE) 5/3/17 NRWO RIH WITH DJN, CLEAN OUT DOWN TO 10913' CTMD GETTING BACK 97% RETURNS, GOT BACK LESS THEN A BBL OF RPPG AND SLIGHT CONCENTRATIONS OF POLLY SWELL. TURN OVER TO DSO ( JOB COMPLETE) KUP 1J-105L1 c.onocoP11 lips04Well Attribu Max Angk D TD Alaska Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) COrtiti5p, 500292334660 WEST SAK INJ 96.16 8,305.45 11,571.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1J-105Li,5/17/20178:02.35 AM SSSV:NIPPLE Last WO: 3229 4/29/2007 Vertical achemalK(actual). Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:PULL ISO SLEEVE 8 DIVERTER hipshkf 2/13/2014 HANGER;23.0 RIZ a. Casing Stiings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread - . .Rn*n it 1 :!,1/11!1 9-Sand Slotted Liner 4 1/2 3.476 7,840.5 11,565.0 3,660.4 11.60 L-80 BTC Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) CONDUCTOR;30.0.108.0' ila `" :41 1.1 15.000 NIPPLE;498.3 MEE GAS LIFT;2,267.8 :•13,708.9 •I L804.890 1 SURFACE;30.5-3,386.8 I Top/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone ate ft) Type Com GAS LIFT;8,393.7 �1.: i II Perforations&Slots ::::::: 1Ili SLOTS Alternating solid/slotted 1J-105L1 pipe 2.5"long x.125" wide SEAL ASSY;7,298.8 ...r 9,540.0 9,545.0 15 9/24/2012 •1 APERF Big •. 00 pumped tL 10,075.0 10,592.0 3,665.5 3,6562 WS B,1J- 4/12/2007 32.0 SLOTS Alternating solid/slotted 105L1 pipe 2.5"long x.125" Whipotock D;7,347.0 wide I WINDOW D;7,348.0-7,363.0 10,849.0 11,521.0 3,654.3 3,659.5 WS B,1J- 4/12/2007 32.0 SLOTS Alternating solid/slotted 105L1 pipe 2.5"long x.125" wide Cement Squeezes Top(TVD) Btm(TOD) II. Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com .,-„.. 9,540.0 9,545.0 3,659.7 3,659.6 GEL 9/24/2012 D-Sand Liner LEM;7,288.4- SQUEEEZE 7,494.8 9,540.0 9,545.0 3,659.7 3,659.6 GEL SQUEEZE 8/10/2013 Notes:General&Safety End Date Annotation D-Send Liner HH;7,343.3- 4/29/2007 NOTE: MULTI-LAT WELL-1J-105(A-SAND),1J-105L1(B-SAND),1J-105L2(D-SAND) 7,8381 B-Sand Utter HH;7,703.8-1 3/2/2011 NOTE:View Schematic w/Alaska Schematic9.0 7,893.8 WINDOW B;7,707.0-7,722.0 9/24/2012 NOTE:PROFILE MODIFICATION-PUMPED 2090 LBS(4MM)CRYSTAL SEAL INTO"B"MBE@9550 ISO SLEEVE;7,707.0 y PRODUCTION;27.4-8,838.4 'i 8/10/2013 NOTE: PROFILE MODIFICATION-PUMPED 3100 LBS(4MM)CRYSTAL SEAL INTO"B"MBE@9550 BSend Liner LEM;7,464.6- 7,862.5 I- 1c SLOTS;8,155.0-8,522.0 SLOTS;8,722.09,818.0 GEL SQUEEEZE;9,540.0 ftKB _ _ APERF;9,540.0-9,545.0 GEL SQUEEZE;9,540.0 ftKB`` _ I 1 SLOTS;10,075.0-10,592.0 /....._. 1--i SLOTS;10,849.0-11.521.0—i_1 B-Band DEnted Liner;7,840.6- 11,565 ON ,840.6- 11,5650\ • • Carlisle, Samantha J (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday, May 17, 2017 7:23 AM To: Carlisle, Samantha J (DOA) Subject: Fwd:Approved Sundry for Withdrawal (Sundry#316-460) 8 Please handle 2 SCANNED from my iPhone .1UN 2 22017 Z lJ Begin forwarded message: From: "Haggerty-Sherrod,Ann (Northland Staffing Services)" <Ann.Haggerty- Sherrod@contractor.conocophillips.com> Date: May 17,2017 at 6:32:20 AM AKDT To: "Carlisle,Samantha J (DOA)" <samantha.carlisle@alaska.gov>, "Loepp,Victoria T(DOA)" <victoria.loepp@alaska.gov> Subject:Approved Sundry for Withdrawal(Sundry#316-460) Good morning, This email is to officially request withdrawal of approved Sundry#316-460. We are withdrawing this application due to the fact that, according to the requesting engineer, "Sundry number 316-460 (1J-10511)with an approval date of 9/11/16 was a 'Canceled' MARCIT Gel job. We could not pump it as planned due to inability to flow 1J-103 offset producer as planned. John Peirce" Thanks so much for your help in this matter, let me know if there is something else needed. Thanks, Ann 1 RBDMS LL- JUN 1 6 2017 • OF Tit 4i0. 11/7, • THE STATE Alaska Oil and Gas 9� Of AL Conservation Commission - -�- � oA s } 2 s 333 West Seventh Avenue • GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFA ;'S�� Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineer AP t 2017 ConocoPhillips Alaska, Inc. swot � � P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-105L1 Permit to Drill Number: 207-028 Sundry Number: 317-082 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this Z3 day of February, 2017. RBDMS \,/FE3 t 7 2017 • IVB • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB Y 5 2017 APPLICATION FOR SUNDRY APPROVALS , GC 20 AAC 25.280 1.Type of Request: Abandon Plug Perforations Fracture Stimulate 1 Repair Well E Operations Shutdown 1- Suspend Suspend Perforate Other Stimulate 1Pull Tubing Change Approved Program E Plug for Red rill Perforate New Pool Re-enter Susp Well Alter Casing fl Other: MBE GEL JOB F' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory r— Development 207-028 , 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service . 50-029-23346-60 . 7.If perforating: 18.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes No F I KRU 1J-105L1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25661,ADL 25662 Kuparuk River Field/West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,571' ' 3,661' • 11565 • , 3660 1500 NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 108' 108' Surface 3,356' 10 3/4 3,387' 2,254' Production 7,680' 7 5/8 7,707' 3,820' Liner 3,725' 4 1/2 11,565' 3,660' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8155-8522,8722-9819,10075-10592 3699-3676,3672-3660,3665-3656 4.500" L-80 7,324' 10849-11521 • 3654-3660 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER=N/A N/A SSSV: =NONE N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 1=I 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory E Stratigraphic I- Development Service F 14.Estimated Date for 3/14/2017 15.Well Status after proposed work: Commencing Operations: OIL WINJ F . WDSPL E Suspended E 16.Verbal Approval: Date: GAS WAG E GSTOR SPLUG E Commission Representative: GINJ E Op Shutdown 1- Abandoned E 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact John W.Peirce @ 265-6471 Email John.W.Peirce@conocophillips.com Printed Name John Peirce Title Sr.Wells Engineer /L4 tr ' r-. 2/L4/17 Signature _.. Phone 265-6471 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3k—z - 002. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ t-' 1-1-13 I t-A Other: Post Initial Injection MIT Req'd? Yes ❑ No L15 yin 7 Spacing Exception Required? Yes ❑ No ®! Subsequent Form Required: ! ° - 4-. ° 1/ RBDIVIS �� FEB r�iJ 2 LU 1/ Approved by: iV/-..''.47 MMISSIONER THE COMMISSION Date: 2-12;5/ 17 Fo m 10- 3 Re / 11 24/#.13/917 APPROVED BY e1Submit Form and j qp`� v�'� p r alid for 12 months from the date of approval. Attachments in Duplicate Feu ` KUP 11J-105L1 •ConocoPhillips ; Well Attribut Max Angle I D TD Alaska:Inc. 'I Wellbore API/UWI Field Name Wellbore Status ncl('') MD(ftKB) Act Btm(ftKB) gp, 500292334660 WEST SAK INJ 96.16 8,305.45 11,571.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 11-1050,2/13/2017 105505 AM SSSV:NIPPLE Last WO: 32.29 4/29/2007 Vertical achsnla4c:{echw,p. Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:PULL ISO SLEEVE 8 DIVERTER hipshkf 2/13/2014 HANGER 230 412. 11 Casing Strings s� Caning Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ,_.,�.,_....,:._...., I B-Sand Slotted Liner 4 1/2 3.476 7,840.5 11,565.0 3,660.4 11.60 L-80 BTC Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl I°) Item Des Com (in) -A.ti CONDUCTOR,30.0.106.0 7,840.5 3,709.0 89.94 SLEEVE L1 B-SAND HR Liner Setting Sleeve w/10'TBR 5.000 NIPPLE;498.3 ;�'i" 5.5"(ID 5.0") GAS LIFT;2,267.8 7,860.6 3,708.9 90.49'SBE L1 B-SAND Receptacle Jt 5.5"15.5#L80 5.5"Hdy b 4.890 lig 1 X p(ID 4.89") • L Perforations&Slots \ SURFACE;30.5-3,386.8-e Shot Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com GAS LIFT;8,393.7 8,155.0 8,522.0 3,698.7 3,676.3 WS B,1J- 4/12/2007 32.0 SLOTS Alternating solid/slotted 105L1 pipe 2.5"long x.125" wide SLEEVE-C;0691.3 8,722.0 9,818.0 3,672.3 3,659.2 WS B,WS C, 4/12/2007 32.0 SLOTS Alternating solid/slotted 1J-105L1 pipe 2.5"long x.125" 1.1 11 wide LOCATOR;7,295.5 SEAL ASSY;7,296.8 9,540.0 9,545.0 3,659.7 3,659.6 WS B,1J-105 9/24/2012 6.0 APERF Big Hole guns,6 spf, 2090#Crystal Seal pumped 111 11 10,075.0 10,592.0 3,665.5 3,656.2 WS B,1J- 4/12/2007 32.0 SLOTS Alternating solid/slotted 105L1 pipe 2.5"long x.125" Whipstock D;7,347.0 wide WINDOW 0;7,349.0-7,363.0 it 10,849.0 11,521.0 3,654.3 3,659.5 WS B,1J- 4/12/2007 32.0 SLOTS Alternating solid/slotted il 105L1 pipe 2.5"long x.125" wide Cement Squeezes Top(TVD) Btm(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com ,-. 9,540.0 9,545.0 3,659.7 3,659.6 GEL 9/24/2012 D-Send Liner LEM;7,288.4 SQUEEEZE 7,494e 9,540.0 9,545.0 3,659.7 3,659.6 GEL SQUEEZE 8/10/2013 Notes:General&Safety End Date Annotation ' D-Sand Liner HH;7,343.3 4/29/2007 NOTE: MULTI-LAT WELL-1J-105(A-SAND),1 J-105L1(B-SAND),1J-105L2(D-SAND) 7,811.8 B-Sand Liner HH;7,703.3_1 3/2/2011 'NOTE:View Schematic w/Alaska Schematic9.0 7,893.8 WINDOW 8;7,707.0-7,722.01 9/24/2012 NOTE:PROFILE MODIFICATION-PUMPED 2090 LBS(4MM)CRYSTAL SEAL INTO"B"MBE@9550 ISO SLEEVE;7,707.D, PRODUCTION;27.4-8,838.4, a1 8/10/2013 NOTE: PROFILE MODIFICATION-PUMPED 3100 LBS(4MM)CRYSTAL SEAL INTO"B"MBE@9550 B-Sand Liner LEM;7,464.8- 7,862.5 I- • _r- SLOTS;8,155.08,522.0 -/ - I I_ SLOTS;8,722.0-9,818.0 I GEL SQUEEEZE;9,540.0 ftKB APERF;9,540.0-9,545 0 GEL SQUEEZE;9,5400 ftKB - SLOTS;10075.0-10582.0 _' SLOTS;10,849.011,521.0 6-sand Slotted Liner;7,840.6 11,56601 ,l i w Proposal for 1J-105L1 to 1J-103L1 B Sand MBE Treatment with RPPG 1J-105 tri-lateral injector was drilled & completed in 2007 with laterals in West Sak A, B, & D sands. 1J-105L1 B lateral has 4.5", L-80 slotted liner. Multiple MBE events have occurred in 1J-105L1. The first happened 4/5/12 from 1J-105L1 to 1J-103L1 producer. A 5/26/12 IPROF found a B MBE in at 9550' RKB taking all PWI. On 9/24/12, a 1J-105L1 Crystal Seal job sealed this MBE for -3 months. A 3/24/13 IPROF verified that the treated MBE at -9550' had reopened. On 8/10/13, a Crystal Seal retreatment was pumped, and this treatment lasted for -3 years until it failed on 3/9/16. An IPROF on 5/25/16 in 1J-105L1 showed a new MBE at 9750' RKB. Currently 1J-105 is configured for 'A and D only' lateral injection. The B lateral is currently isolated with a B Iso-Sly. 1J-105 is currently on injection to the A and D sands. The following procedure is proposed to seal off the new B MBE at 9750' RKB with RPPG (aka: Reformed Polymer Particle Gel) to return 1J-105L1 to PWI service. RPPG is a newly developed synthetic dehydrated crystalline particle polymer gel product that hydrates and swells in water. RPPG is like Crystal Seal in appearance and swellability. However, unlike Crystal Seal, RPPG has a delayed crosslinking feature that tightly bonds individual swollen particle polymer grains together into an amalgamated mass of gel after placement to the MBE. This crosslinking feature should give RPPG MBE treatments much better resilience to disaggregation and breakdown vs. Crystal Seal when the treatment in the MBE is being subjected to drawdown pressure from flowing the producer. Unlike previous Crystal Seal MBE treatments that we have performed to date in West Sak MBE's, we propose that we inject the initial 37 to 50 bbls of gel slurry at maximum concentration from CT to the MBE while drawdown is being applied on the MBE by flowing the 1J-103 offset producer. Coil Tubing Procedure: 1) RIH to pull the Iso-Sly set across the B LEM at 7707' RKB. 2) RIH to set an A Sand Isolation Plug in the 3.562" DB Nipple at 7809' RKB. 3) RIH to set a Type 1 B Diverter across in the B LEM at 7707' RKB. 4) RIH to set a Type 2 D Iso-Sly with verified 2.75" min ID across in the B LEM at 7348' RKB. 5) RIH to shoot 5' of 'big hole' perforations at 9750 - 9755' RKB across the new B MBE located at 9750' RKB, per 5/25/16 IPROF. 6) Put both 1E-103 producer and 1J-105 injector BOL 12 - 24 hrs before CTU RU on 1J-105. Have 1J-103 flowing to 1J test separator. This will reestablish flow through the B MBE between the wells. RU CTU with 2" CT on 1J-105. RIH with a down port nozzle on CT. Park nozzle at 9740' RKB just above the open MBE in 1J-105L1. Blend Seawater from transports with 1 - 4 mm mesh RPPG at 0.30 - 0.35 ppg slurry concentration `on-the-fly' in a mixing van and then pump it down CT at a steady established rate of 1.7 - 2.2 bpm while producing 1J-103 and injecting 1000 BPD PWI down CT x Tbg to keep CT back side flushed of any RPPG slurry. Pump the first 37 to 50 bbls of slurry out of the nozzle parked at MBE at -9740. After -37 bbls of slurry exits the nozzle, shut-in 1J-103 (to avoid any significant placement of RPPG to the producer), while continuing slurry pumping to 1J-105L1 and starting POOH at 50 fpm. Continue pumping steady rate and slurry concentration until nozzle is POOH and parked at `safety' above all liner slots at 8140' • • RKB. POOH to safety mitigates development of very heavy PU weight that often develops while pumping heavy gel concentrations into slotted liners with crossflow. Continue pumping slurry at steady rate and 0.30 - 035 ppg concentration until WHIP reaches -800 psi, then SI all 1J-105 injection to CT x Tbg annulus, and swap from RPPG slurry to pumping to 5 bbls of Seawater spacer down CT, followed by -62 bbls Diesel FP followed by 1 CT volume of CT Diesel FP. When Diesel starts going down CT, start POOH from safety while maintaining steady rate down CT. RD CTU. Wait 2 days for RPPG particles fully crosslink in MBE before returning 1J-105L1 to PWI. If step 6 is executed as planned, 1J-103 producer will be allowed to flow back to the plant with low odds that it would create a plant upset due to gel production. 7) RIH with jet swirl nozzle and tag top of RPPG in well, then jet down through RPPG to as deep as possible to shear & mechanically break RPPG remaining in the liner. POOH w/CT. PU & RIH with 2.5" OD CT Tractor with nozzle to jet down through RPPG to as deep as possible to shear & mechanically break RPPG remaining in the liner at deeper depths to open more lateral to PWI. POOH w/CT Tractor. Place 1 J-105L1 on PWI to evaluate the results of the MBE treatment. 8) RIH with IPROF BHA. Memory log down & up passes to verify all the MBE's are sealed off. Wait 2 hours and then log a cool back pass. POOH with CT. RD CTU. Return 1J-105L1 to PWI service. Leave 1J-105L1 on `B sand only' injection long enough to evaluate that the B MBE's remain sealed. When deemed appropriate, proceed to steps 9 -11 to normal up well. 9) RIH to pull the Iso-Sly across the D LEM at 7348' RKB to open the D lateral to injection. 10) RIH to pull the Diverter in the B LEM at 7707' RKB and leave B lateral open to injection. 11) RIH to pull the Plug from the DB Nipple at 7809' RKB to open the a lateral to injection. Return 1J-105 to PWI service to all 3 laterals. • • yOF T� I , � THE STATE Alaska Oil and Gas f Conservation Commission :.- ___= o ALAS�:A lir#x 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 r Main: 907.279.1433 ALAS fi Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce SCANNED FEB 1 6 HIT Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, West Sok Oil Pool, KRU 1J-105L1 Permit to Drill Number: 207-028 Sundry Number: 316-460 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ".;k4-41`1*--- Cathy . Foerster Chair DATED this 16ay of September, 2016. RBDMS Li" -' 1 6 2016 • • • STATE OF ALASKA • E ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 0 8 2016 APPLICATION FOR SUNDRY APPROVALS D 9 S9/(3///_ 20 AAC 25.280 OG CC 1.Type of Request: Abandon r Plug Perforations E Fracture Stimulate E Repair Well E Operations Shutdown E Suspend E Perforate E Other Stimulate r Pull Tubing E Change Approved Program Plug for Redrill 1 Perforate New Pool E Re-enter Susp Well E Alter Casing E Other: MBE Marcit Gel Trtmnt F ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. • Exploratory 1- Development 207-028 ' 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23346-60 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? none Will planned perforations require a spacing exception? Yes r No Fo- / KRU 1J-105L1 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25661,25662 • Kuparuk River Field/West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,571' • 3,661' + 11565 i . 3660 1500 psi none none Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 108' 108' Surface 3,356' 10 3/4 3,387' 2,254' Production 7,680' 7 5/8 8,838' 3,820' B Sand Slotted Liner 3,725' 4 1/2 11,565' 3,660' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8155-8523,8722-9818, 3699-3676,3672-3659, 4.500" L-80 7,324' 9540-9545,10075-10592, 3660-3660,3665-3656 10849-11521 ' 3654-3659 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): no packer N/A no SSSV N/A 12.Attachments: Proposal Summary j Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory E Stratigraphic fl Development E--- Service 14.Estimated Date for 10/3/2016 15.Well Status after proposed work: Commencing Operations: OIL WINJ F- WDSPL E Suspended 16.Verbal Approval: Date: GAS WAG E GSTOR E SPLUG Commission Representative: GINJ E Op Shutdown fa Abandoned 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact John Peirce @ 265-6471 Email John.W.Peircecop.com Printed Name John Peirce Title Sr.Wells Engineer Signature 414. . one 265-6471 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: It.Q – Li , V Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test 0 Location Clearance ❑ Other: Ii3 IlL Post Initial Injection MIT Req'd? Yes ❑ No / Spacing Exception Required? Yes ❑ No d Subsequent Form Required: `n—4,04, RBDMS 1,v ¶''' 1 6 2016 APPROVED BY Approved by: CY€ P COMMISSIONER THE COMMISSION Date:9 / �/] l ee 4 D I Submit Form and Form SO-03 Revised % 01'S�" ' R r d I,'(��1, is valid for 12 months from the date of approval. ,attacbments init Form nd Ilia //9//S- Vz/a • • 1J-105L1 to 1J-103L1 B MBE Treatment with MARCIT Gel Proposal West Sak 1J-105 Tri-lateral injector was completed in 2007 with 4.5" horizontal slotted liners in the WS A, B, and D sands. A 1J-105 to 1J-103 Matrix Bypass Event (MBE) first occurred 4/5/12. On 5/26/12, a B lateral (PROF found a large MBE at -9,550' RKB taking almost all PWI. On 9/24/12 the B lateral liner was CTC perfed with large holes at 9540 - 9545' RKB, and then CT pumped 2,090 lbs of 4 mm mesh Crystal Seal to the B MBE. After this treatment, 1J-105 was returned to `B lateral only' PWI with no sign of an open MBE to 1J-103. PWI lasted for -3 months before 1J-103 water cut spiked up on 1/1/13, which caused 1J-105 being SI due to a suspected reopening of the B MBE to 1J-103. A 3/24/13 IPROF in 1J-105L1 verified that the original B MBE treated at -9,550' RKB had re-opened and was again taking all PWI. On 8/10/13, a CT Crystal Seal retreatment pumped 3,100 lbs of Crystal Seal to the B MBE at 9,550' RKB. This treatment lasted 3 years before it eventually failed on 3/9/16. On 4/20/16, CT isolated the A lateral by setting a Plug in the mainbore in the Nipple at 7,809' RKB. On 4/21/16, CT Installed a B Diverter at 7,707' RKB, and a D Iso-Sleeve at 7,348' RKB. On 5/25/16, a CT IPROF was run in the B Lat which verified an MBE is now present at -9,750' RKB. The previous B MBE had been detected 3/24/13 at-9,550' RKB. Since two Crystal Seal jobs have been pumped and a B MBE still remains open, it is proposed that a full-bore MARCIT Gel job be pumped to attemp sea e B a - 5 RKB. 1J-105L1 is currently configured for the proposed B MBE treatment. Proposed Procedure: Fullbore MARCIT Pumping: 1) MIRU Gel Pumping Unit equipment to perform a fullbore MARCIT Gel job. Fullbore pump MARCIT Gel down 4.5" Tubing to theBE at 0.5 bpm (target) while monitoring treating pressure response. Inject up to 500 bbls (max target) of accelerated viscosity MARCIT, followed by 12 hrs SI time to build Gel viscosity in the B MBE at 9750' RKB, then resume pumping up to 1000 bbls (max target) of regular MARCIT to complete the MBE treatment. Displace Gel to MBE with Seawater and Diesel FP. Leave well SI for at least 5 days, then return 1J-105L1 to PWI and monitor offset producer 1J-103 performance. Coil Tubing: 2) RIH with Jet Swirl Nozzle to jet through excess MARCIT Gel left in the B lateral liner to as deep as possible jetting Seawater. POOH & FP with Diesel. RD. 3) Run post-MARCIT IPROF in the B lateral to verify if the B MBE is sealed. 4) RIH & pull D Iso-Sleeve at 7348' RKB (set 4/21/16) to restore PWI to the D lateral. 5) RIH & pull B Diverter at 7707' RKB (set 4/21/16) to leave B lateral open. 6) RIH & pull the A lateral Isolation Plug from the Nipple at 7809' RKB (set 4/20/16) to open the A lateral. Return 1J-105 to PWI service to West Sak A, B, and D sands. JWP 9/8/2016 KUP 1J-105L1 ConOCOPhiiil l5 s Well Attribut Max Angle TO • Alaska 17',,, Wellbore API/0W' Field Name Wellbore Status ncl(°) MD(kKB) Act Otto(kKB) CorwcaNliiiips 500292334660 _WEST SAK INJ 96.16 8,305.45 11,571.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1J-105L1,91820167:26.40 AM SSSV:NIPPLE Last WO: 32.29 4/29/2007 _ VeNW.schematic(actual) Annotation Depth(kKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:PULL ISO SLEEVE 8 DIVERTER hipshkf 2/13/2014 HANGER;23.0 7;""-'•t a1. Casing Sings ..- Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread air -a..- B Sand Slotted Liner 4 1/2 3.476 7,840.5 11,565.0 3,660.4 11.60 L-80 BTC Liner Details Nominal ID Top(ftKB) Top(TVD)(kKB) Top Incl(°) Item Des Com (in) .nom CONDUCTOR;30.o-toe o- it -^- 7,840.5 3,709.0 89.94 SLEEVE L1 B-SAND HR Liner Setting Sleeve w/10'TBR 5.000 NIPPLE;498.3 `■ 5.5"(ID 5.0") GAS LIFT;2,2678 'r 7,860.6 3,708.9 90.49 SBE L1 B-SAND Receptacle Jt 5.5"15.54/L80 5.5"Hdy b 4.890 Xp(ID4.89") G Perforations&Slots 8 SURFACE;30.5-3,386. L Shot Dens Top(ND) Ban(ND) (shots/ Top(ftKB) Btm(kKB) (ftKB) (ftKB) Zone Date ft) Type Com GAS LIFT;6,393.7 ,, 8,155.0 8,522.0 3,698.7 3,676.3 WS 8,1J- 4/12/2007 32.0 SLOTS Alternating solid/slotted 105L1 pipe 2.5"long x.125" wide SLEEVE-C;8,691.3 LiTti 8,722.0 9,818.0 3,672.3 3,659.2 WS B,WS C, 4/12/2007 32.0 SLOTS Alternating solid/slotted lail 1J-105L1 pipe 2.5"long x.125" LOCATOR;7,295.5 wide SEAL ASSY;7,296.6 9,540.0 9,545.0 3,659.7 3,659.6 WS B,1J-105 9/24/2012 6.0 APERF Big Hole guns,6 spf, 20908 Crystal Seal C�= pumped lU �l 10,075.0 10,592.0 3,665.5 3,656.2 WS B,1J- 4/12/2007 32.0 SLOTS Alternating solid/slotted ISO SLEEVE;7,348.0 iii ff 105L1 pipe 2.5"long x.125" Whipstock D;7,347.0 !Flied= wide WINDOW D;7,348.0-7,363.0 I:• 10,849.0 11,521.0 3,654.3 3,659.5 WS B,1J- 4/12/2007 32.0 SLOTS Alternating solid/slotted I 105L1 pipe 2.5"long x.125" wide Cement Squeezes Top(TVD) Btm(ND) Top(ftKB) Btm(kKB) (ftKB) (kKB) Des Start Date Com D-SandtaxLEM;7,288.4- 5.-. 9,540.0 9,545.0 3,659.7 3,659.6 GEL -9/24/2012 IF 1 SQUEEEZE 7,4s4a C __..' 9,540.0 9,545.0 3,659.7 3,659.6 GEL SQUEEZE 8/10/2013 Notes:General&Safety End Date Annotation D-Sand Liner HH;7,343.3- 4/29/2007 NOTE:MULTI-LAT WELL-13-105 A-SAND,1J-105L1 B-SAND,1J-105L2 D-SAND 7,611.8 ( ) ( ) ( ) B-Sand Liner HH;7,703.3- 3/2/2011 NOTE:View Schematic w/Alaska Schematic9.0 7,893.8 WINDOW B;7,707.0-7,722.0 9/24/2012 NOTE:PROFILE MODIFICATION-PUMPED 2090 LBS(4MM)CRYSTAL SEAL INTO"B"MBE@9550 DIVERTER;7,707.0 PRODUCTION;27.4-8,838.4 }' 8/10/2013 NOTE: PROFILE MODIFICATION-PUMPED 3100 LBS(4MM)CRYSTAL SEAL INTO"B"MBE@9550 B-Sand LIMN LEM;7,464.8- 7,882.5 4 SLOTS;8,155.0-8,522.0 SLOTS;8,722.0-9,818.0 jj 1 APERF;9,540.0-9,545.0 GEL SQUEEEZE;9,540.0 kKB GEL SQUEEZE;9,5400 ftKB ', _ 1-1 SLOTS;10,075.010,592.0 SLOTS,10,849.011,521.0 B-Sand Slotted Liner,7840 6- 11,5650\ • • W E - __ . 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R w V U C � co - Image ject Well History File Cc~r Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~- ~~ ~ Well History File Identifier Organizing (done) RE AN Color Items: ^ Greyscale Items: o,,~a uiNiuiuiiuui DIGI L DATA Diskettes, No. I ^ Other, No/Type: o ae.~a.~,~~ muiumiiiim OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: j (.~' ~s~ Pro "ect Proofing II I II'I II I I III I I III ~ ~~ QY: Maria ~ Date: ~ S ~~ ~s~ Scanning Preparation <~. x 30 = BY: Maria Date:. Production Scanning + ~_ =TOTAL PAGES (Count does not incude cover sheet) ,~/~, lsl ~ Y Stage 1 Page Count from Scanned File: (Count does include cov r sheet) hes Number in Scannin Pr aration: YES NO Page Count Matc 9 P f/~/~ BY: Maria Date: ~ ~ ~~ ~ ~s~ r ~' Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~s~ Scannin is complete at this point unless rescanning is required. II I II I) II I II II I I III 9 ReScanned BY: Maria Comments about this file: Date: Quality Checked iuiiuuuiuii 10/6/2005 Well History File Cover Page.doc -------- 4 ,-,_., w \ \ I % % _ THE STATE Alaska Oil and Gas ,,...._„.3.4-,:-:- "' o fALASK . 1 Conservation Commission rh: GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF ALAS� P Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 NEB A � 1 ZD'i John Peirce r•�" Wells Engineer ConocoPhillips Alaska, Inc. fi �2'" P.O. Box 100360 �U Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J -105L1 Sundry Number: 313 -228 Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. PP PP Y PP g Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster 4.--' �,/ Chair DATED this / y of May, 2013. Encl. • . ' STATE OF ALASKA • � o . E , •KA OIL AND GAS CONSERVATION COMMISSION 4" J2 7; / APPLICATION FOR SUNDRY APPROVALS ' \ } " 1 0 ' 20 3 20 AAC 25.280 �� ,,,.� � A9 1. Type of Request: Abandon E Rug for Redrill f� Perforate New Pool (r"- Repair w ell fw Gha r ram V Suspend f a Rug Perforations r Perforate j ' Pull Tubing r Time Extension ("` Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing (-- Other:MBE Treatment ` 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development f` Exploratory f`°' 207 - 0280 3. Address: Stratigraphic I Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 23346 - 60 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes E No I✓ 1J -105L1 6 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25661, 25662 ' Kuparuk River Field / West Sak Oil Pool.. 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11571. 3661 • 11565'• 3660' * none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 108' 108' SURFACE 3356 10.75 3387' 2254' PRODUCTION 8811 7.625 8838' 3820' B -SAND SLOTTED LINER 3724 5.5 x 4.5 11565' 3660' Perforation Depth MD (ft): , Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8155 -8522, 8722 -9819, 10075 - 10592, 10849 -11521 3699 -3676, 3672 -3660, 3665 -3656, 3654 -3660 4.5 L - 80 7324 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) no packer no SSSV 12. Attachments: Description Surrmary of Proposal fN • 13. Well Class after proposed work: Detailed Operations Program E BOP Sketch (— Exploratory r Stratigraphic (` Development f Service We m 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/1/2013 Oil f°" Gas [ WDSPL E Suspended r 16. Verbal Approval: Date: WINJ hi - GINJ r WAG I Abandoned E Commission Representative: GSTOR f S PLUG I 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 - 6471 Email: John.W.Peirce @cop.com Printed Name John Peirce Title: Wells Engineer Signature W K�-.. Phone: 265 -6471 Date S1 3 Commission Use Only ��� - �� --1111 Sundry Number: 313 ..... 224 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity f BOP Test E Mechanical Integrity Test r Location Clearance r RBDMS MAY 1 0 101 Other: Spacing Exception Required? Yes ❑ No [� Subsequent Form Required: It — 4 c L f j / / APPROVED BY Approved by: 4.:; - - _ w I • N ' T • _0 • k Date: /0 /3 Form 10 -403 (Revised 10/2012) (/ /iF Submit Form and Attachments in Duplicate r� ORIGINAL • 1J -105L1 to 1J -103L1 `B' MBE Crystal Seal Retreatment A Matrix Bypass Event (MBE) occurred on 4 -5 -12 in 1J -105L1 in the B sand lateral. A 5 -26 -12 IPROF saw the B MBE at 9550' RKB behind the 4.5" slotted liner. Almost all PWI was exiting the slotted liner at this MBE. A 9 -25 -12 Crystal Seal treatment sealed the B MBE, but the treatment broke down within a few months that resulted in shut -in of PWI to 1J -105. A 3 -24 -13 IPROF in 1J -105L1 confirmed the B MBE at —9550' RKB Crystal Sealed 9 -25 -12 was once again open taking all PWI. The 1J-105L2 D lateral was isolated with an !so-Sly on 5 -23 -12 (for 9 -25 -12 B MBE Crystal Seal treatment), and the D Iso- Sleeve remains set. 1J -105 is configured to perform a 1J -105L1 B MBE Crystal Seal retreatment. The B Diverter remains set. It is proposed that 1J -105L1 B MBE will be resealed with Crystal Seal pumped down coil tubing. No well work needs to be done to prepare for 1J -105L1 for a retreatment. Large hole perforations already exist in 1J -105L1 across the B MBE, which were shot prior to pumping the initial B MBE treatment. A post - Crystal Seal IPROF will likely be run in 1J -105L1 to verify success of the job. Coil Tubing Procedure: RIH with either a large down port or side port nozzle on 2 "coil tubing. Park nozzle across the large hole perforation interval at 9540 - 9545' RKB in the 4.5" slotted liner just above the MBE at 9550' RKB. Pump a Crystal Seal retreatment as follows: a) Seawater down coil. Determine a steady treatment rate (likely between 1.5 - 2 bpm) to be held constant during the treatment through Flush (step f) to monitor MBE response to treatment and to note a CrystalSeal screenout during slurry pumping. Swap from Seawater to 2% KCI, b) 2% KCI Water with 0.05 ppg Crystal Seal (we will use 4 mm mesh for all stages b through e) down coil. Each stage volume is TBD during pumping based on the treating pressure response seen during stage. When called, continue pumping, c) 2% KCI Water w/0.10 ppg Crystal Seal down CT, or go to Flush (step f) if we see screen out. d) 2% KCI Water w/0.15 ppg Crystal Seal down CT, or go to Flush if we see screen out develop. e) 2% KCI Water w /0.20 - 0.25 ppg Crystal Seal down CT, or go to Flush if we see screen out. f) If screen out is seen, open CT x Tbg annulus to return tank, and pump 1 CT volume Seawater Flush to displace Crystal Seal slurry from coil to well while POOH. If screen out has not been seen prior to Flush, leave CT x Tbg annulus SI and pump 1 full CT volume of Seawater Flush to displace remaining Crystal Seal Slurry from coil to liner while POOH to D LEM, then swap to pumping Diesel FP down coil, followed by 1 CT volume of Diesel to FP CT & displace Diesel FP to tubing, followed by SD. RD CTU. Wait at least 6 hours to let Crystal Seal become fully swollen and seal off the MBE before returning 1J -105L1 to PWI for treatment evaluation. Coil tubing will be used to perform a post - CrystalSeal treatment tag, a possible Crystal Seal cleanout, and a memory IPROF depending on post job PWI and offset producer responses. e KUP • 1J -105L1 • ConocoPhillips �a Well Attributes Max Angle & MD TD Alaska, loc. Wel!bore APUUWI Field Name Well Status Ind ( ") MD (MB) Act Btm (ftKB) y 500292334660 WEST SAK INJ 96.16 8,305.45 11,571.0 "'" Comment H2S (ppm) Date Annotation End Date KB .Grd (ft) Rig Release Date "- SSSV: NIPPLE Last WO: 32.29 4/29/2007 Well Co n64'. - 1J-105L1, t 0126/201210 AM schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: CORRECT PERF DATA osborl 10/26/2012 HANGER, 23 -- ^ Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd B -Sand Slotted Liner 4 1/2 3.476 7,840.6 11,565.0 3,660.4 11.60 L -80 BTC I 11 Liner Details Top Depth (TVD) Top Inc! Nomi... CONDUCTOR, _._ Top(ftKB) (ftKB) (1 Item Description Comment ID(in) IMP 30 -108 7,840.6 3,709.0 89.94 SLEEVE L1 B -SAND HR Liner Setting Sleeve w/ 10' TBR 5.5" (ID 5.0 ") 5.000 NIPPLE. aee 'r 7,860.6 3,708.1 89.13 SBE L1 B -SAND Receptacle Jt 5.5" 15.5# L80 5.5" Hdy b X p (ID 4.89 ") 4.890 MIME GAS LIFT, 2,288 t f Perforations & Slots Shot Top (TVD) Btm (TVD) Dens SURFACE, (ftKB) Btm (ftKB) (MB) (ftKB) Zone Date (08.- Type Comment 30 -3,387 8,155.0 8,522.0 3,698.8 3,676.1 WS B, 1J -105L1 4/12/2007 32.0 SLOTS Alternating solid/slotted pipe 2.5" long x .125" wide GAS LIFT, s 8,722.0 9,818.0 3,672.4 3,659.5 WS B, WS C, 4/12/2007 32.0 SLOTS Alternating solid/slotted pipe 2.5" long 6,394 1J -105L1 x.125 "wide mum SLEEVE -C, 9,540.0 9,545.0 3,659.1 3,659.2 WS B, 1J -105 9/24/2012 6.0 APERF Big Hole guns, 6 spf, 2090# Crystal 6.691 ,. Seal pumped LOCATOR, °' 10,075.0 10,592.0 3,664.9 3,656.2 WS B, 1J -105L1 4/12/2007 32.0 SLOTS Alternating solid/slotted pipe 2.5" long 7,296 >,,;; x .125 "wide SEAL ASSY, 7 10,849.0 11,521.0' 3,654.3 3,659.5 WS B, 1J -105L1 4/12/2007 32.0 SLOTS Alternating solid/slotted pipe 2.5" long x .125" wide • ISO SLEEVE, Notes: General & Safety 7,343 End Date Annotation 4/29/2007 NOTE: MULTI -LAT WELL - 1J -105 (A-SAND), 1J -105L1 (B- SAND), 1J -105L2 (D -SAND) Whipstock D. 3/2/2011 NOTE: View Schematic w/ Alaska Schematic9.0 7,347 WINDOW D, 7,348 -7,363 D -Sand Liner LEM, 7,288-7,495 0-Sand Liner Ht, 12 \ \ 7,3437,612 _...._._..; DIVERTER, I 7,703 Whipstock B. . 7.707 WINDOW B. 7,707 -7.722 B -Sand Liner LEM, 7,465 -7,862 e -Send Liner HH, 7,703-7,894 SLOTS, 8,155-8,522 PRODUCTION, 27-8,838 -_ -. SLOTS, 8,722 -9,818 APERF, 9.540 -9,545 SLOTS, 10,075 - 10.592 SLOTS, Mandrel Details 10,849- 11,521 Top Depth Top Port (TVD) Incl 00 Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) ( Make Model (in) Sere Type Type (in) (psi) Run Date Com... B -Sand Slotted 1 2,267.8 1,853.7 69.17 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 6/28/2007 Liner, ,65 5 7,841 -01 S 2 6,393.7 3,387.3 68.93 CAMCO KBMG 1 GAS LIFT DMY BEK -5 0.000 0.0 4/28/2007 TD (1J- 105L1), 11,671 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COrlOSION . • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Rug Perforations r Perforate r Other ;j` MBE Treatment Alter Casing r Rill Tubing r Stimulate - Frac r Waiver r Time Extension f Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 207 - 028 3. Address: 6. API Number: Stratigraphic r Service I r . P. O. Box 100360, Anchorage, Alaska 99510 _ " 50 - 029 - 23346 - CO 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25661, 25662 0 1 J - 105L1 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none : Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11571 feet Plugs (measured) none true vertical 3661 feet Junk (measured) none Effective Depth measured 11565 feet Packer (measured) none true vertical 3660 feet (true vertucal) none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 108 108 SURFACE 3356 10.75 3387 2254 PRODUCTION 7680 7.625 8838 3820 f r: 11. ` : :'"': "" B -SAND SLOTTE 3724 5.5 x 4.5 11565 3660 it i. it 40 ""°'° 6 a ' "` '`' Perforation depth: Measured depth: 8155 -8522, 8722 -9818, 10075- 10592, 10849 -11521 E.: t ° ' 1. a k s -, , True Vertical Depth: 3699 -3676, 3672 -3660, 3665 -3656, 3654 -3660 Tubing (size, grade, MD, and TVD) 4.5, L -80, 7324 MD, 3642 TVD SCANNED JAN 2 8 2013 Packers & SSSV (type, MD, and TVD) NO PACKER 1�.I� NO SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): see attached summary 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 shut - Subsequent to operation 717 14. Attachments 15. Well Class after work: ,. Copies of Logs and Surveys run Exploratory r Development r Service 17 Stratigraphic r 16. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND p 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: 312 -271 Contact John Peirce a 265 -6471 Email: John .W.Peirce @conocophillips.com Printed Name John Peirce Title Wells Engineer Signature �� A Phone: 265-6471 Date 2 2_/1 RR!",, OCT 2 O 2012 <o -u. iv Form 10-404 Revised 12/2012 /� Submit Original Only 1J -105L1 Well Work Summary DATE SUMMARY 9/24/12 PERFORATED FROM 9540' 70545' CTMD, OPENED CIRC SUB AND PODED A TOTAL OF 2090 POUNDS CRYSTAL SEAL. PUMPED 440 POUNDS AT .1 PPG, 770 POUNDS AT .15 PPG 405 POUNDS AT .2 PPG. AND 495 POUNDS AT .29 PPG. WELL FREEZE PROTECTED TO 2000' TVD. JOB COMPLETE. 10/8/12 DRIFTED TO 7325' SLM (AT/ NEAR D SAND ISO SLEEVE @ 7343' RKB) WITH 2.65" CENTRALIZER & 2.25" BAILER. COMPLETE. i KUP • 1J -10551 Conoc 'I Well Attributes Max Angle & MD TD Alaska Inc Wel!bore AP!/UWI Field Name Well Status Inc; ( °) MD (ftKB) Act Btm (ftKB) 500292334660 WEST SAK INJ 96.16 8,305.45 11,571.0 .... Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date Well Conrw - 1J-105L1 10/26/2012 006.02 AM SSSV: NIPPLE Last WO: 32.29 4/29/2007 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date — - . Last Tag: Rev Reason: CORRECT PERE DATA osborl 10/26/2012 HANGER, 23 _ _ _ Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (r... Set Depth (TVD) ... String Wt... String ... String Top Thrd I B -Sand Slotted Liner 4 1/2 3.476 7,840.6 11,565.0 3,660.4 11.60 L -80 BTC Liner Details Top Depth ?9al£%: (TVD) Top Incl Nomi... it CONDUCTOR, Top (ftKB) (ftKB) ( °) Item Description Comment ID (In) 3o -1oe 7,840.6 3,709.0 89.94 SLEEVE L1 B -SAND HR Liner Setting Sleeve w/ 10' TBR 5.5" (ID 5.0") 5.000 NIPPLE, 498 I I ` itt� 7,860.6 3,708.1 89.13 SBE L1 B -SAND Receptacle Jt 5.5" 15.5# L80 5.5" Hdy b X p (ID 4.89 ") 4.890 GAS LIFT, 2,268 Allo. , : Perforations & Slots Shot Top (TVD) Btm (TVD) Dens SURFACE, .■ L Top(ftKB) Btm((tKB) (ftKB) (ftKB) Zone Date (eh... Type Comment 30 -3,387 8,155.0 8,522.0 3,698.8 3,676.1 WS B, 1J -105L1 4/12/2007 32.0 SLOTS Alternating solid/slotted pipe 2.5" long x .125" wide GAS LIFT, I 8,722.0 9,818.0 3,672.4 3,659.5 WS B, WS C, 4/12/2007 32.0 SLOTS Alternating solid/slotted pipe 2.5" long 8.394 1J-105L1 x.125 "wide SLEEVE -C, _ { e y ::, " 9,540.0 9,545.0 3,659.1 3,659.2 WS B, 1J -105 9/24/2012 6.0 APERF Big Hole guns, 6 spf, 2090# Crystal 6,691 >•B, Seal pumped LOCATOR, 10,075.0 10,592.0 3,664.9 3,656.2 WS B, 1J -105L1 4/12/2007 32.0 SLOTS Altemating solid/slotted pipe 2.5" long fair 7,296 x .125 "wide SEAL ASSY, 7,297 10,849.0' 11,521.0 3,654.3 3,659.5 WS B, 1J-105L1 4/12/2007 32.0 SLOTS Altemating solid/slotted pipe 2.5" long x .125" wide i - Notes: General & Safety ISO SLEEVE, End Date Annotation 7,343 4/29/2007 NOTE: MULTI-LAT WELL - 1J-105 (A-SAND), 1J-105L1 (B-SAND), 1J-105L2 (D-SAND) whipstock D, 3/2/2011 NOTE: View Schematic w/ Alaska Schematic9.0 7,347 WINDOW D, 7,348-7,363 D -Sand Liner LEM, 7,288-7,495 D Sand 51 H \ 2 1 r DIVE TER, 7,703 1 ,,7 k 3 DIVER A 8, Whipstock B, 7,707 WINDOW B. 7.707-7,722 13-Sand 1/n 13-Sand d Line. LEM. 7.465 -7362 B -Sand Liner 8H, 7.703-7.894 OTS, SLOTS, ■ 8,155-8322 PRODUCTION. 2748,838 T 8,722 -9 S. APERF. 9,540 -9345 SLOTS. 10,075-10,592 SLOTS, Mandrel Details 10.849-11,521 Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (1 Make Model (in) Sere Type Type 06) (psi) Run Date Com... e -sand Slotted 1 2,267.8 1,853.7 69.17 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 6/28/2007 Liner. 7,841 - 17,585 5 2 6 3,387.3 68.93 CAMCO KBMG 1 GAS LIFT DMY - BEK -5 0.000 0.0 4/28/2007 _ TO (7170557), 11,571 r 7z, I ty: L 18 A " / SEAN PARNELL, GOVERNOR Li iru ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION C OMMI S SI ON / ANCHORAGE, ALASKA 99501-3539 33 PHONE (907) 279-14 FAX (907) 276-7542 John Peirce Wells Engineer ConocoPhillips Alaska, Inc. tJ ° P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-105L1 Sundry Number: 312-271 Dear Mr. Peirce: ti'atiAkiED AUG t ZO Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy PiFoerster Chair DATED this L day of July, 2012. Encl. A OIL AND G S CONSERVATION COMIIION RECEIVED JUL 2 3 2012 APPLICATION FOR SUNDRY APPROVALS r) 7/z50 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well f • a •0 OCCo r Suspend r Rug Perforations r Perforate r Pull Tubing r M dime Extension r OE Operational Shutdown r Re -enter Susp. Well f Stimulate r Alter casing r Other:GPystaI - Seal Treatm • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 207 -028 3. Address: Stratigraphic r Service 1' 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 23346 -60 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No 17 1J -105L1 , ( is LAF7 c.4AL) 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25661, 25662 • Kuparuk River Field / West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11571' 3661 • Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 108' 108' SURFACE 3356 10.75 3387' 2254' PRODUCTION 8811 7.625 8838' 3820' B - SAND SLOTTED LINER 3724 5.5 x 4.5 11565' 3660' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8155 - 8522, 8722 - 9818, 10075 - 10592, 10849 - 11521 3699 -3676, 3672 -3660, 3665 -3656, 3654 -3660 4.5 L - 7324 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) no packer no SSSV 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r7 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/17/2012 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ P' ' GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce © 265 -6471 Printed Name John Peirce Title: Wells Engineer Signature (N ( ` ,,r... Phone: 265 -6471 Date 7/ C>112 � Commission Use Only 2 Sundry Number:31 2'27 1 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Subsequent Form Required: 1 O - y ® ij 9 / 4 APPROVED BY / Approved by: at COMMISSIONER THE COMMISSION Date: l - 2-5 — / ` N 7. S J UL 2 5 201 10 -403 R vised 1/201 S t u e 0R1G1 A .- - ,',- i 7,e_ _ _ - , , • • 1J -105L1 to 1J -103L1 MBE Treatment A 1J-105 to 1J-103 producer Matrix Bypass Event (MBE) occurred 4- 05 -12. On 4- 29 -12, a main -bore IPROF showed all PWI entering 1E-105L1 B lateral with heavy cross flow from the D to B lateral. On 5- 26 -12, a CT IPROF in the B lateral to 11500' CTMD showed a large B MBE present at +/- 9550' CTMD taking almost all the PWI. It is proposed that the B MBE be sealed with Crystal Seal. This product is used for treating injectors to restore water flood efficiency by sealing highly conductive communication flow paths through formation to offset producers. Crystal Seal is a water swellable dehydrated crossiinked synthetic gel polymer that can be placed in large formation void features (ie: MBE's) by mixing and pumping it as slurry in saline aqueous solutions. Crystal Seal granules may swell to hundreds of times initial size by hydrating and absorbing water, but swollen particles are too large to enter matrix pore throats, so the product does not result in skin damage to formation. Coil Tubing Procedure 1) RIH with 2" x 7' OAL Dummy TCP Gun drift assembly on 2" CT. Drift the BHA to 7800' RKB . through the B Diverter set at 7707' RKB. POOH with drift assembly. RD CT. 2) RIH with 2" OD x 5' TCP gun (7' OAL). Park the perf gun and pump a ball down CT to fire the gun at 9540 - 9545' RKB. This location is at the middle of a 42' slotted joint across the MBE at 9550' RKB. Flag pipe to locate a nozzle later to pump Crystal Seal. The gun provides 6 spf, 60 deg ph, with modeled average perf hole diameters of 0.42" to provide enough flow area for Crystal Seal to pass through the liner to the MBE. The liner has 2.5" x 0.125" slots (32 slots / ft) in 42' slotted joints alternating with 42' blank joints. POOH with fired gun. Verify ASF. RD CT. 3) RU 2" CTU & mixing van to blend slurry `on- the -fly' in 2% KCI Water to be pumped down CT at steady 1.5 bpm during Crystal Seal job. RIH with large side port nozzle with no down ports. Note pipe flag to park nozzle on perf interval at 9540 - 9545' RKB. Pump Seawater SRIT down CT at steps ramped between 1 - 2 bpm. A final steady rate we'll decide to pump Crystal Seal slurry depends on rate that can be pumped into the well at a reasonable treating pressure. Determine if the well looks OK to treat based on the SRIT. If OK to treat, continue pumping: Seawater Pad down CT at 1.5 bpm (target) until ready to swap to slurry. Maintain steady treating rate throughout treatment through Flush to monitor treating pressure at constant rate. Swap from Seawater to 2% KCI Water. Pump 2% KCI with 0.05 ppg Crystal Seal (4 mm mesh all stages) down CT. Each stage volume TBD during pumping based on treating pressure response observed during stage. Continue pumping 2% KCI w /0.10 ppg Crystal Seal (CS) down CT, or Flush if we see screen out (SO), then 2% KCI w/0.15 ppg CS down CT, or Flush if we see SO, then 2% KCI w /0.20 ppg CS down CT, or Flush if we see SO, then 2% KCI w/0.25 ppg CS down CT, or Flush should we see SO. If screenout occurs, open CT x Tbg annulus to return tank, and pump 1 CT volume of Seawater Flush to displace all Crystal Seal slurry from CT into well while POOH. If screenout has not been seen prior to Flush, leave CT x Tbg annulus shut -in and pump 1 full CT volume of Seawater Flush to displace Crystal Seal Slurry from CT to MBE while POOH with CT to B LEM, then swap to 63 bbls of Diesel FP down CT, followed by 1 CT volume of Diesel ( -40 bbls) to FP CT and displace Diesel FP to tubing, followed by SD. RD CTU. Wait 6 hrs then return 1J-105L1 to PWI for post Crystal Seal treatment evaluation. KUP • 1J -105L1 Conoco hillips , I , Well Attributes Max Angle & MD TD AtaSlf Mc Wellbore APIIUWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (RKB) stgpt • 500292334660 WESTSAK INJ 96.16 8,305.45 11,571.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: NIPPLE Last WO: 32.29 4/29/2007 Well Confiq. - 1110511, 5/29/207 2 10'27'28 AM scnemadc- Actual Annotation (Depth (RKB) End Date Annotation (Last Mod ... lEnd Date • • _____ -- Last Tag: Rev Reason: SET DIVERTER 8 ISO ninam 5/29/2012 HANGER.23 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd B -Sand Slotted Liner 4 1/2 3.476 7,840.6 11,565.0 3,660.4 11.60 L -80 BTC Liner Details f Top Depth (TVD) Topincl Mond... Top (/IICB) (RKB) ( °) Item Description Comment ID (in) cor4ou o08 7,840.6 3,709.0 89.94 SLEEVE L1 B -SAND HR Liner Setting Sleeve w/ 10' TBR 5.5" (ID 5.0 ") 5.000 NIPPLE, 498 • ' AI 7,860.6 3,708.1 89.13 SBE L1 B -SAND Receptacle Jt 5.5" 15.5# L80 5.5" Hdy b X p (ID 4.89 ") 4.890 GAS LIFT, 2.268 ' . Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (RKB) (ftKB) Zone Date (eh... Type Comment SURFACE 30. 3.387 , 8,155 8,522 3,698.8 3,676.1 WS B, 1J-105L1 4/12/2007 32.0 SLOTS Altemating solid/slotted pipe 2.5" long x .125" wide 5 —___, GAS LIFT, t 8,722 9,818 3,672.4 3,659.5 WS B, WS C, 4/12/2007 32.0 SLOTS Alternating solid/slotted pipe 2.5" long 6,394 ti r 1J -105L1 x.125 "wide SLEEVE - c, I 1 10,075 10,592 3,664.9 3,656.2 WS B, 1J -105L1 4/12/2007 32.0 SLOTS Altemating solid/slotted pipe 2.5" long 6,691 t r ' le i x .125 "wide LOCATOR, _. 10,849 11,521 3,654.3 3,659.5 WS B, 1J -105L1 4/12/2007 32.0 SLOTS Alternating solid/slotted pipe 2.5" long 7,298 x .125" wide SEAL ASSY. r Notes: General & Safety End Date Annotation 4/29/2007 NOTE: MULTI -LAT WELL - 1J -105 (A- SAND), 1J -105L1 (B SAND), 1J -105L2 (D -SAND) II SLEEVE, 7,343 3/2/2011 NOTE: View Schematic w/ Alaska Schematic9.0 Whipstock D, 7,347 WINDOW 9, 7,348 -7,383 D -Sand Liner 14 - \ - 7,288-7,495 EM, D -Sand Liner 7 , 7.343-7,612 DIVERTER, 11111: 7,703 Whipstock B, 7,707 WINDOW B, I - 7,707 -7,722 B -Sand Liner LEM. 7,465 -7.862 B -Sand Liner HH, 7.703 -7.894 SLOTS, 8,155-8,522 • PRODUCTION. 27.8,838 TS, 8,7229 SLOTS. 10,075- 10,592 Mandrel Details Top Depth Top Pont (TVD) Inc! OD Valve Latch Size TRO Run • Stn Top (ftKB) (RKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,267.8 1,853.7 69.17 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 6/28/2007 • 2 6,393.7 3,387.3 68.93 CAMCO KBMG 1 GAS LIFT DMY BEK -5 0.000 0.0 4/28/2007 SLOTS. 10,849- 11,521 8-Sand Slotted -- Liner, 7,841 - 11,565 TD (1J- 105111, 11,571 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 1, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 1J-105L1 Run Date: 5 2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 II I 1J -105L1 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 - 23346 -60 Injection Profile Log 1 Color Log 50- 029 - 23346 -60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com n Date: '�( 1,`� � Signed: )/ 6 fivt °~ ~ ~a ~ ~~ ~~:. .°., i ~+ V "~ ,. ~~ ~ ,, tea. x 8 ry ~.t~ ~ _ ilk 5 ~ ~~ ~~ ~. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~q ~~ DATA SUBMITTAL COMPLIANCE REPORT 5/7/2009 Permit to Drill 2070280 Well Name/No. KUPARUK RIV U WSAK 1J-105L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23346-60-00 MD 11571 TVD 3661 Completion Date 4/29/2007 Completi on Status 1-OIL Current Status 1WINJ UIC Y __ -- REQUIRED INFORMATION Mud Log No Samples IVQ Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res/USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED D Asc Directional Survey G 7629 11571 Open 8/2/2007 D C Lis 15316~Gamma Ray 3351 11571 Open 8/3/2007 LIS Ven GR, ROP, FET , w/Graphics i /Rpt 15316~S Verification 3351 11571 Open 8/3/2007 LIS Veri, GR, ROP, FET ~g Induction/Resistivity 25 Col 108 11571 Case 4/23/2009 MD DGR, EWR 12-Apr- ~ 2007 ~ / !Log Induction/Resistivity 25 Col 108 3660 Case 4/23/2009 ND DGR, EWR 12-Apr- 2007 C Pds 17918 See Notes 0 0 4/23/2009 EWR logs in PDS, EMF and CGm graphics __ - _ _' Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y !~ Daily History Received? ,Q ,~,,~ Chips Received? .-X.Nd' Formation Tops w"'" Analysis ~LLN Received? DATA SUBMITTAL COMPLIANCE REPORT 5/7/2009 Permit to Drill 2070280 Well Name/No. KUPARUK RIV U WSAK 1J-105L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23346-60-00 MD 11571 TVD 3661 Completion Date 4/29/2007 Completion Status 1-OIL Current Status 1WINJ UIC Y Comments: Compliance Reviewed By: _ - __ Date: r~__w~` i ~J ~~'~L'~, L1~G T1~SM~~'T~=~L Toe State of Alaska Alaska Oil and Gas Conservation Conan. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-105+L1+L2+PB1 Apri17, 2009 AK-MW-4912996 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling , 6900 Arctic Blvd., Anchorage, AK 99518 1J-105+L1+L2+PB1 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Lo 50-029-23346-00,60,61,70 g 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Lo 50-029-23346-00,60,61,70 g Digital Log Images 1 CD Rom 5 0-029-2 3 3 46-00, 60, 61, 70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ ~~ i ~~- i ~~~ t ~~ ~~ Bryan.Burin~~hall~hll~ron.co::: v~, ~= ~, ~ 'vd ~ ~I Date: Signed: ~ ~ ,fin-=-~ Ll. 1 / A,.IV ~ LLV1V(41V ~.{ Nil i i.i ~ • w~ ~ v ~ ... ..... ~ ... . .. .., ... ~ .. .. Maunder, Thomas E (DOA From: Maunder, Thomas E (DOA) Sent: .Monday, August 27, 2007 9:52 AM To: 'NSK West Sak Prod Engr'; Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPPISSN defeated on 1E-112, 1J-102, 1J-127, 1J-164, 1J-180 - --v ... Thanks Hai, While we will file this information in the main wellbore file, it is probably appropriate to list the lateral permit numbers for completeness. Cafl or message with any questions. Tom Maunder, PE AOGCC From: NSK West Sak Prod Engr [mailto:n1638@conocophillips.com] Sent: Sunday, August 26, 2007 8:59 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPFl DS Lead Techs; CPF1 Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPPISSN defeated on 1E-112, 1J-102, iJ-127, iJ-164, 1J-180 Tom ; Jim, The LPPISSN's on all of the West Salc DS1 E and DS'I J wells are now back in service as their wellhead injection pressures have increased to above 500 psi. The folio~n,~ing wells had been defeated; permit to drill numbers are also listed. I ~niasn't sure if you wanted the permit to drill number for the mainbore only or the laterals as +~ell so I included both. WELL ID Permit to Drill No. 1 E-112 204-091 (MAINBORE}, 204-092 (L1), 204-093 (L2) 1J-102 206-110 (MAINBORE), 206-111 (L1), 206-'112 (L2) .-~1J-105 207-027 (MAINBORE), 207-028 (L1}, 207-029 (L2) 1J-'f27 206-047 (MAINBORE), 206-048 (L1), 206-049 (L2) 1J-160 207-015 (MAiNBORE), 207-016 (L1), 207-017 (L2) 1J-164 205-144 (MAINBORE), 205-145 (L1), 205-146 (L2) 1J-180 206-150 (MAINBORE), 206-151 (L1) Note: '1J-105 and 1J-'160 were defeated in early July 2007, before the CPF1 ESD, because they were new injectors (notification for these wells was sent 7/9/2007). Let me know if you have any questions. Regards, Nai Hunt Hai Hunt /Pete f~lezaticky /Eric Hollar NSK West Sai< Production Engineer ConocoPhillips Alaska, lnc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 8/27/2007 WELL LOG TRANSMITTAL To: State of Alaska July 2, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-105 Ll AK-MW-4912996 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23346-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 a~ ~ ~-_ ~ _._, Date: f ~ 2007 Signed: `3 ~ ~ -- ~`~~~; VTR ~`~-4a`?f ~ ~S3/~ • 17-Jul-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-105L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 7,629.17' MD Window /Kickoff Survey 7,707.00' MD (if applicable) Projected Survey: 11,571.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~~~~iv~D 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ .Stimulate ^ AIBS~(8 ~t~~Q( GaS ~S P~eP~~ to INJ ~u--1fT11SSlOft Alter Casing ^ Pull Tubing ^ Peroorate New Pool ^ Waiver ^ Time Exte~'~'t0~ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5: Permit to Drill Number. COnOCOPhlllips Alaska, IrtC. Development ^ Exploratory ^ 207-028 3. Address: Strati ra hic g p ^ Service / ~ ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23346-60 7. KB Elevation (ft): 9. Well Name and Number. RKB 109' 1J-105L1 ` 8. Property Designation: 10. Field/Pool(s):. ADL 25661f& 25662 f Kuparuk River Field /West Sak Oil Pool " 11. Present Well Condition Summary: Total Depth measured 11571' ~ feet true vertical 3661' feet Plugs (measured) Effective Depth measured 11565 feet Junk (measured) true vertical 3660 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 80' 80' SURFACE 3278' 10-3/4" 3387 2255' WINDOW L2 1' 7-5/8" 7349' 3645' WINDOW L1 1' 7-5/8" 7708' 3701' PRODUCTION 8729' 7-5/8" 8838' 3820' B-sand slotted liner 3366' 4-1/2" 11521' 3659' Perforation depth: Measured depth: 8155' - 11521' true vertical depth: 3699' - 3660' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7324' MD . Packers &SSSV (type & measured depth) PKR = LEM ZXP Liner top pkr PKR = 7288' SSSV =NIP SSSV = 493' 12. Stimulation or cement squeeze summary: Intervals treated (measured) ~ ~L JUL 2 3 2DD7 Treatment descriptions including volumes used and final pressure: . 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 838 328 28 932 202 Subsequent to operation 2014 1204 -3 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ Q ~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-187 contact Bob Christensen /Bob Buchholz Printed Name Robert W. Buch olz Title Production Engineering Technician h Signature ~~.G. Phone 659-7535 Date ~ //~/v /~ V t~ ~ V ~ ~ V h 1.. /2~9 r~ /~D T. /~. m~ !~' Form 10-404 Revised 04/2004 ~~~ Submit Original Only C~ ~, 1J-105L1 DESCRIPTION OF WORaC COMPLETED SUMMARY Date Event Summary 07/06/07 Commenced Water Injection ~ • ~~ OIIt ~ ~ 333 W. 7th AVENUE, SUITE 100 COI~SERQA~`IO1Q CO1~II1'IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-105L1 Sundry Number: 307-187 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of June, 2007 Encl. Sincerely, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED ~(~/JUN 0 5 2007 APPLICATION FOR SUNDRY APPROVa p~~ & Gas Cons. Commission 20 AAC 25.280 hors e 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time 6ctension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Producer to Re-enter Suspended Well ^ Injector 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^/ Exploratory ^ 207-028 ~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23346-60 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes ^ NO ^~ 1J-105L1 / 9. Property Designation: ~~~ ysG ` ~ ~D ' 09 10. KB Elevation (ft): 11. Field/Pool(s): `~ 2 Kuparuk River Unit LAG Z v'1 RKB 109' Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11571' - 3661' - 11565' 3660' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 20" 80' 80' SURFACE 3278' 10-3/4" 3387' 2255' WINDOW L2 1' 7-5/8" 7349' 3645' WINDOW L1 1' 7-5/8" 77pg' 3701' PRODUCTION 8729' 7-5/8" 8838' 3820' Alternating Slotted liner 3366' 4-1/2" 11521' 3659' Perforation Depth MD (ftj Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8155' -11521' 3699' -3660' 4-1 /2" I_-so 7324' Packers and SSSV Type: Packers and SSSV MD (ft) PKR = LEM ZXP Liner top pkr PKR = 7288' SSSV =NIP SSSV = 493' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service^ ' 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: June 25, 2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ / WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Bob Buchholz Printed Name RO ert D. Christensen Title: Production Engineering Technician ., Signature Phone 659-7535 Date r~ d'Z ~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~' Plug Integrity ^ BOP Test ^ Mechanical Integrity Test X71 Location Clearance ^ Other: ~~ E'--S ~ r\ G-CCE~c~ ~' ! t4~~ o~-\~~ S ~~ ~~ ~ ~ ~ ~~~~ Subsequent Form Required: i_tp-~y APPROVED BY /^ /~ ,D Approved by: COMMISSIONER THE COMMISSION r Date: (y ` Form 10-403 Revised 0612006 (~ ~ ~„(~ ~ ~ r `~~/^~5~~ it~~uplicate-' y • • ~E~~IVED Robert Buchholz /Robert Christensen S U N Q 5 2 0 0 7 Production Engineering Tech. Greater Kuparuk Unit , NSK-69 ~'"~ , ~ Alaska Oi! & Gas Cons. Commissiar~o Box 196105 C~r1oC~~l'1~~~~pS AnC110faQB Anchorage, AK 99519-6105 Phone: (907) 659-7535 Fax: 659-7314 .June 1, 2007 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Maunder, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk WestSak wells 1J- 105, 1J-lOSLI, and 1J-1O5L2 from Oil Production to Water Injection service. Enclosed you will find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. wells 1J-105 (PTD 207-027), 1J-lOSLl (PTD 207-028), and 1J-1O5L2 (PTD 207-029). If you have any questions regarding this matter, please contact myself or Robert Buchhloz at 659-7535. Sincerely, Robert D. Christensen Attachments • • 1J-105L1 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1J-105L1. This well has been pre-produced for 30 days in order to recover Oil based drilling fluids prior to putting the well on injection. 1J-105L1 will provide pressure support for the West Sak B sands. The 10-3/4" Surface casing (3387' and / 2254' tvd) was cemented with 600 sx AS Lite followed by 198 sx LiteCRETE. The 7-5/8" Intermediate casing (8838' and / 3820' tvd) was cemented with 480 sx DeepCRETE. The injection tubing/casing annulus is isolated via the following: Upper D sand LEM ZXP 4- 1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 7288' and / 3635' tvd, Upper B sand LEM ZXP 4-1 /2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 7465' and / 3662' tvd, and an Upper A sand HRD ZXP 4-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 7820' and / 3719' tvd. The top of West Sak D sand was found at 7348' and / 3645' tvd. D sand Lateral window top is located @ 7348' and / 3645' tvd. The top of West Sak B sand was found at 7704' and / 3700' tvd. B sand Lateral window top is located @ 7707' and / 3701' tvd. The top of West Sak A sand was found at 7894' and / 3730' tvd. • • KRU 1J-105L1 ConocoPhillips Alaska, Inc. lac u~.~~IC~_?. _~-T~G~i_- ~~ ~~T 4~~~.-~~ ~~ yLi. ~ J?-~ ~ ~ - X05 ~L°~. L.. ~- r LL J:-T=- 'I`TS : ~,~,~1~J~ ?-~ ~~~~ TVD ; = STD : ?~ SID :, a s i ^ g : '-1 ~ 6~.5 S Iz o e : ~S~s'~~ `~ ''j~S ~ ~ "I'V"D ; li V : ~1 t~. ?~ N ~ T ti~ -_-•°= - Shoe . ~ T `r:~ ; _~. '_~~ ';~ o1e S=ce ~ and ~~ ~ ~~_ ~~ ~..a?~ -~~ ` r i`~TEGRITY - ~ a~~T # ? ~nr:ui~:s dress '-'est: _~ Comments T'J~i S e ~ _ t ~~~ ~~ Perms ~~~ to ~~~~ ~./~.. w~ ~ ~'1 C`~ ``( 15 ,C"ii n S O min i '~'CH~?4ICr`_L INTEGRIT ~ - PART # Z ~~ ~o~S = ~~ ~ ~~`~ Cement Volumes :- A.mt. Liner Csg ~P~oSyc DV Cmt -col to cover aers ~SOOt ~ 30~ K S - ='eoretical TCC C 3~1Z~k5 ~ ~C. ~- J~`o~C~ Cement Bond Log (Yes or No) ~LS In AOGCC File ~~S C3L evaluation, gone aoove perTs ~~ roducti on Log : Type CONCLJS?Ct~S ?art :1: ~ ~valuati on _ ' d - . ~~ ~ fem.-~~ ConocoPhillips May 21, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Wel! Completion Reports for 1J-105, 1J-105L1, 1J-105L2 Dear Commissioner: ,~, ~ u `~ '~~~ `z ~ 20i~i .~las~~a ;ail t~ ~~sa cults. Commission A-~ct-o~ agu ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak wells 1J-105, 1J-105L1, 1J- 105L2. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling Randy Thomas Kuparuk Drilling Team Leader Dril-ing & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RT/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. I lass: itC+11Q~~~ Development Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: Aprif 29, 2007 ~ 12. Permit to Drill Number: 207-028 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: A ~ / ~~ ~~~ M , 2007 13. API Number: 50-029-23346-60 ' 4a. Location of Well (Governmental Section): Surface: 2186' FSL, 2432' FEL, Sec. 35, T11N, R10E, UM ~ 7. Date TD R ached: ~i• x'•0'7 April 12, 2007 14. Well Name and Number: 1J-105L1 - Top of Productive Horizon: 1505' FSL, 1975' FWL, Sec. 36, T11 N, R10E, UM 8. KB (ft above MSL): 109' AMSL Ground (ft MSL): 81' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 2358' FNL, 1883' FWL, Sec. 1, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 11565' MD / 3660' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): NAD 27 Surface: x- 558776 y- 5945998 Zone- 4 10. Total Depth (MD + ND): 11571' MD / 3661' TVD 16. Property Designation: 25661, 25662 TPI: x- 563188 y- 5945353 Zone- 4 Total Depth: x- 563130 > - 5941490 ° Zone- 4 11. SSSV Depth (MD + ND): nipple @ 423' 17. Land Use Permit: 471, 2177 18. Directional Survey: Yes Q No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 1514' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): T !J ~ ?7O7~~1~~ 3'7G~/ ~?VO GR/Res/USIT ~a s-~t~Q7 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE G AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTIN RECORD PULLED 20" X 34" 78.6# H-40 28' 108' 28' 108' 42" 360 sx AS 1 10.75" 45.5# L-80 28' 3387' 28' 2254' 13.5" 600 sx AS Lite, 198 sx DeepCRETE 7.625" 29.7# L-80 28' 8838' 28' 3820' 9.875" 480 sx DeepCRETE 4.5" (LEM) 12.6# L-80 7465' 7862' 3662' 3709' 6.75" blank liner 4.5" (Hook) 11.6# L-80 7703' 7894' 3700' 3709' 6.75" blank liner 5.5" x 4.5" 11.6# L-80 7840' 11565' 3707' 3660' 6.75" slotted and blank liner 23. Open to production or injection? Yes Q No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 7324' none refer to slotted liner attached 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED na 26. PRODUCTION TEST Date First Production May 11, 2007 Method of Operation (Flowing, gas lift, etc.) pre-producing injector -shares production with 1J-105 and 1J-105L2 Date of Test 5/14/2007 Hours Tested 8 hours Production for Test Period --> OIL-BBL 676 GAS-MCF 847 WATER-BBL 21 CHOKE SIZE 40 Bean GAS-OIL RATIO 1342 Flow Tubing press. 348 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 1931 GAS-MCF 2592 WATER-BBL 62 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No / Sidewall Cores Acquired? Yes ^ No ~ If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~~ Ct)~`Ai'LETiON •LA~ G7 not applicable UfR f~D Form 10-407 Revised 2!2007 CONTINUED ON REVERSE SIDE +e+ 6~~ ~U~ ~ ~ ?0~, ~j~ s'ZS.c~ f ^~1~~NAl~ ~7Of" ~ ~~~~ E~EIVED ~~Y 2 2 2007 WELL COMPLETION OR RECOMPLETION REPORTii~O~:,ns~ C ' sion 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost -Top surface surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1651' 1514' needed, and submit detailed test information per 20 AAC 25.071. T3 3387' 2255' K15 3387' 2255' Ugnu C 5426' 3020' Ugnu B 5935' 3210' Ugnu A 6142' 3290' K13 6764' 3519' West Sak D 7348' 3645' West Sak C 7557' 3677' West Sak B 7704' 3700' West Sak A4 11571' 3661' N/A West Sak A3 11571' 3661' West Sak A2 11571' 3661' Formation at total depth: Kuparuk B 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheets 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed Na R homas Title: Drillino Team Leader . ~ _ 5 ~2 % ~0' 7 Signature _.. one 2C S--G .~ j ~ Date INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 Halliburton Company Survey Report (:ompany: ConocoPhillips Alaska lnc. Date: 5/17/2007 Time: 10:A6:46 Prge: 1 Field:. Kuparuk River tJnit Co-ordinate(NE) Reference: Well: 1J-105, Tru e North Site:, Kuparuk 1J Fad Vertical;(TVD)Re ference: 1J-105L1: 109.0 Welt:. 1J-105 Section (VS)Reference: Well (O.OON,O.OOE,180.OOAzi) ~Vellpath: 1J-105L1 tiurvey Calculation Method: Minimum Curvat ___ _ ure. , Dh: Oracle _ _ - Field: Kuparuk River Unit , North Slope Alaska ~ United States Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Map Zone: Coordinate Sy Alaska, Zone 4 stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1J-105 Slot Name: WeII Position: +N/-S 79.11 ft Northing: 5945998.64 ft Latitude: 70 15 47.036 N j +E/-W -13.17 ft Easting : 558776.16 ft Longitud 149 31 29.390 W Position Uncertainty: 0.00 ft e ~Wellpath: 1 J-105L1 Drilled From: 1 J-105 II 500292334600 Tie-on Depth: 7629.17 ft Current Datum: 1J-105L1: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 3/18/2007 Declination: 23,58 deg f Field Strength: 57620 nT Mag Dip Angle: 80.82 deg Vertical Section: Depth From (TVD) ft ---- +N/-S ft +E/-W- ft Direction deg - -- ~ ~ 28.00 0.00 0.00 180.00 ~ Survey Program for Definitive Wellpath Date: 5/17/2007 Validated: No Version: 2 ~ Actual From To Survey Toolcode Tool Name i ft ft i 50.00 826.00 1J-105PB1 gyro (50. 00-826.00) CB-GYRO-SS Camera based gyro single shot 857.82 7061:58 1J-105PB1 (857.82- 7347.33) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC j 7071.00 7629.17 1J-105 (7071.00-11695.87) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7707.00 11529.13 1J-105L1 (7707.00-11529.13) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey - - MD [ucl Azim TVl> ~_ vs TVD N/S E/W DtapN MapF Tool ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945998.64 558776.16 TIE LINE 50.00 0.16 53.62 50.00 -59.00 0.02 0.02 5945998.66 558776.18 CB-GYRO-SS 100.00 0.30 141.62 100.00 -9.00 -0.04 0.16 5945998.60 558776.32 CB-GYRO-SS 171.00 0.36 41.63 171.00 62.00 -0.02 0.43 5945998.62 558776.59 CB-GYRO-SS 264.00 0.56 58.53 264.00 155.00 0.43 1.01 5945999.08 558777.16 CB-GYRO-SS 354.00 2.43 40.52 353.96 244.96 2.11 2.62 5946000.77 558778.77 CB-GYRO-SS ~I 445.00 5.63 40.67 444.72 335.72 6.97 6.79 5946005.66 558782.89 CB-GYRO-SS 537.00 8.19 47.34 536.05 427.05 14.83 14.55 5946013.58 558790.59 CB-GYRO-SS 629.00 10.54 48.84 626.82 517.82 24.81 25.70 5946023.65 558801.67 CB-GYRO-SS 656.00 11.03 48.60 653.34 544.34 28.15 29.50 5946027.01 558805.44 CB-GYRO-SS ~ 731.00 13.44 44.36 726.63 617.63 39.12 40.98 5946038.08 558816.83 CB-GYRO-SS I 826.00 17.70 47.21 818.13 709.13 56.84 59.30 5946055.93 558835.01 CB-GYRO-SS 857.82 17.28 47.55 848.48 739.48 63.31 66.34 5946062.46 558842.00 MWD+IFR-AK-CAZ-SC 954.15 20.32 51.42 939.66 830.66 83.40 89.98 5946082.74 558865.48 MWD+IFR-AK-CAZ-SC 992.72 21.50 53.16 975.69 866.69 91.82 100.87 5946091.23 558876.30 MWD+IFR-AK-CAZ-SC 1049.19 23.94 55.41 1027.77 918.77 104.53 118.59 5946104.08 558893.92 MWD+IFR-AK-CAZ-SC 1143.69 27.32 56.79 1112.97 1003.97 127.30 152.53 5946127.11 558927.67 MWD+IFR-AK-CAZ-SC 1183.40 27.88 56.24 1148.16 1039.16 137.45 167.87 5946137.38 558942.93 MWD+IFR-AK-CAZ-SC 1239.22 29.39 56.68 1197.15 1088.15 152.23 190.17 5946152.33 558965.11 MWD+IFR-AK-CAZ-SC 1282.82 30.20 56.72 1234.98 1125.98 164.12 208.27 5946164.37 558983.13 MWD+IFR-AK-CAZ-SC 1378.63 36.29 57.82 1315.08 1206.08 192.47 252.46 5946193.06 559027.08 MWD+IFR-AK-CAZ-SC 1429.96 38.83 58.54 1355.76 1246.76 208.96 279.05 5946209.75 559053.54 MWD+IFR-AK-CAZ-SC 1478.00 40.28 57.98 1392.80 1283.80 225.06 305.06 5946226.05 559079.43 MWD+IFR-AK-CAZ-SC 1525.94 40.22 57.52 1429.39 1320.39 241.59 331.26 5946242.78 559105.49 MWD+IFR-AK-CAZ-SC 1582.89 42.42 56.42 1472.16 1363.16 262.09 362.78 5946263.53 559136.84 MWD+IFR-AK-CAZ-SC 1620.06 44.49 55.67 1499.14 1390.14 276.37 383.98 5946277.97 559157.93 MWD+IFR-AK-CAZ-SC 1669.60 46.18 55.43 1533.96 1424.96 296.30 413.03 5946298.13 559186.83 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inca Date: 5/17!2007 'Time: 10:46:46 Pag_c: 2 Field: Kuparuk RiverUnit Co-ordinate(NE) Reference: WekL' 1J-105, TrueNorth Site: Kuparuk 1J Pad Vertical ('1'VD)Reference: 1J-105L1: 109.0 Well: 1J-105 Section (VS) Reference: Wetl (O.OON,O.OOE;180.OOAzi) ~1`ellpath: 1J-105L1 Survey Calculation Method: Minimum Curvature Db: Oracle ____ __ __ Survev i~1D Inc! Azim TVD Svs TVD NIS E/yV MapN ntapE Tool ft deg deg ft ft ft' ft ft ft 1715.45 48.80 55.59 1564.94 1455.94 315.44 440.89 5946317.48 559214.53 MWD+IFR-AK-CAZ-SC 1756.82 51.18 55.32 1591.54 1482.54 333.40 466.98 5946335.65 559240.48 MWD+IFR-AK-CAZ-SC 1809.45 51.26 56.92 1624.50 1515.50 356.27 501.04 5946358.78 559274.36 MWD+IFR-AK-CAZ-SC 1877.54 54.55 57.79 1665.57 1556.57 385.56 546.77 5946388.42 559319.85 MWD+IFR-AK-CAZ-SC 1904.90 56.10 57.96 1681.13 1572.13 397.52 565.83 5946400.53 559338.81 MWD+IFR-AK-CAZ-SC ~ 1955.07 55.90 57.63 1709.19 1600.19 419.69 601.02 5946422.97 559373.83 MWD+IFR-AK-CAZ-SC 2000.46 57.26 56.55 1734.19 1625.19 440.28 632.82 5946443.80 559405.47 MWD+IFR-AK-CAZ-SC 2035.72 58.97 55.94 1752.81 1643.81 456.91 657.72 5946460.63 559430.23 MWD+IFR-AK-CAZ-SC I ~ 2094.86 62.29 57.36 1781.81 1672.81 485.23 700.77 5946489.28 559473.05 MWD+IFR-AK-CAZ-SC 2160.94 64.27 57.76 1811.52 1702.52 516.89 750.58 5946521.32 559522.61 MWD+IFR-AK-CAZ-SC 2190.98 65.61 58.31 1824.25 1715.25 531.29 773.66 5946535.91 559545.58 MWD+IFR-AK-CAZ-SC ~ 2255.80 68.74 56.23 1849.39 1740.39 563.60 823.90 5946568.60 559595.56 MWD+IFR-AK-CAZ-SC 2284.90 69.79 56.29 1859.69 1750.69 578.72 846.54 5946583.89 559618.07 MWD+IFR-AK-CAZ-SC 2329.52 69.74 56.72 1875.13 1766.13 601.82 881.45 5946607.27 559652.80 MWD+IFR-AK-CAZ-SC 2379.75 69.84 56.48 1892.48 1783.48 627.77 920.80 5946633.52 559691.94 MWD+IFR-AK-CAZ-SC 2427.93 69.71 53.78 1909.14 1800.14 653.61 957.89 5946659.65 559728.83 MWD+IFR-AK-CAZ-SC i 2475.69 69.43 53.96 1925.81 1816.81 680.00 994.04 5946686.31 559764.76 MWD+IFR-AK-CAZ-SC 2573.07 69.07 55.90 1960.31 1851.31 732.32 1068.56 5946739.21 559838.87 MWD+IFR-AK-CAZ-SC 2668.62 69.00 55.97 1994.50 1885.50 782.30 1142.48 5946789.76 559912.39 MWD+IFR-AK-CAZ-SC 2761.03 69.27 56.63 2027.41 1918.41 830.21 1214.32 5946838.22 559983.84 MWD+IFR-AK-CAZ-SC 2857.69 69.10 57.13 2061.76 1952.76 879.58 1289.99 5946888.18 560059.12 MWD+IFR-AK-CAZ-SC 2951.99 70.36 58.28 2094.43 1985.43 926.84 1364.76 5946936.01 560133.51 MWD+IFR-AK-CAZ-SC 3047.78 68.99 55.48 2127.71 2018.71 975.90 1439.99 5946985.66 560208.35 MWD+IFR-AK-CAZ-SC 3141.74 67.32 56.57 2162.67 2053.67 1024.64 1512.31 5947034.95 560280.28 MWD+IFR-AK-CAZ-SC 3237.01 67.55 56.57 2199.23 2090.23 1073.11 1585.73 5947083.99 560353.31 MWD+IFR-AK-CAZ-SC 3345.45 69.14 58.63 2239.25 2130.25 1127.10 1670.82 5947138.64 560437.97 MWD+IFR-AK-CAZ-SC 3442.21 65.71 59.55 2276.39 2167.39 1172.99 1747.46 5947185.13 560514.24 MWD+IFR-AK-CAZ-SC I 3537.73 65.96 61.45 2315.49 2206.49 1215.90 1823.31 5947228.62 560589.75 MWD+IFR-AK-CAZ-SC 3596.12 65.22 64.10 2339.63 2230.63 1240.23 1870.58 5947253.31 560636.82 MWD+IFR-AK-CAZ-SC 3633.41 65.88 65.30 2355.06 2246.06 1254.74 1901.27 5947268.06 560667.40 MWD+IFR-AK-CAZ-SC 3669.03 67.11 65.93 2369.27 2260.27 1268.22 1931.02 5947281.77 560697.04 MWD+IFR-AK-CAZ-SC 3728.04 67.16 66.18 2392.20 2283.20 1290.29 1980.71 5947304.22 560746.55 MWD+IFR-AK-CAZ-SC 3777.68 67.17 68.01 2411.46 2302.46 1308.09 2022.85 5947322.36 560788.55 MWD+IFR-AK-CAZ-SC ~' 3825.12 68.49 69.59 2429.37 2320.37 1323.98 2063.81 5947338.56 560829.38 MWD+IFR-AK-CAZ-SC 3918.86 68.09 74.35 2464.06 2355.06 1350.93 2146,59 5947366.15 560911.94 MWD+IFR-AK-CAZ-SC 4014.42 67.11 75.39 2500.47 2391.47 1373.99 2239.88 5947389.88 560997.03 MWD+IFR-AK-CAZ-SC 4110.62 67.51 80.06 2537.60 2428.60 1392.85 2318.57 5947409.41 561083.57 MWD+IFR-AK-CAZ-SC ~ 4205.78 68.38 84.20 2573.35 2464.35 1404.91 2405.91 5947422.15 561170.80 MWD+IFR-AK-CAZ-SC 4300.80 67.45 87.10 2609.08 2500.08 1411.59 2493,70 5947429.52 561258.52 MWD+IFR-AK-CAZ-SC 4395.43 68.23 92.41 2644.79 2535.79 1411.96 2581.29 5947430.57 561346.11 MWD+IFR-AK-CAZ-SC 4493.63 67.18 94.70 2682.05 2573.05 1406.33 2671.97 5947425.65 561436.81 MWD+IFR-AK-CAZ-SC 4588.36 68.50 96.34 2717.78 2608.78 1397.89 2759.29 5947417.89 561524.19 MWD+IFR-AK-CAZ-SC 4683.41 67.55 95.81 2753.35 2644.35 1388.56 2846.94 5947409.24 561611.90 MWD+IFR-AK-CAZ-SC I i 4779.17 68.30 99.82 2789.35 2680.35 1376.49 2934.83 5947397.86 561699.87 MWD+IFR-AK-CAZ-SC 4872.63 69.50 104.99 2823.02 2714.02 1357.75 3019.94 5947379.79 561785.12 MWD+IFR-AK-CAZ-SC 4968.32 69.06 108.17 2856.88 2747.88 1332.22 3105.71 5947354.93 561871.08 MWD+IFR-AK-CAZ-SC 5065.43 69.07 110.92 2891.58 2782.58 1301.88 3191.17 5947325.26 561956.77 MWD+IFR-AK-CAZ-SC 5159.58 69.81 114.32 2924.66 2815.66 1267.97 3272.53 5947291.99 562038.38 MWD+iFR-AK-CAZ-SC 5255.69 69.23 114.40 2958.28 2849.28 1230.84 3354.55 5947255.50 562120.68 MWD+IFR-AK-CAZ-SC 5349.24 68.78 115.10 2991.80 2882.80 1194.27 3433.86 5947219.56 562200.27 MWD+IFR-AK-CAZ-SC 5444.91 68.27 118.24 3026.83 2917.83 1154.32 3513.41 5947180.24 562280.11 MWD+IFR-AK-CAZ-SC 5539.50 68.35 121.32 3061.80 2952.80 1110.67 3589.68 5947137.19 562356.72 MWD+IFR-AK-CAZ-SC 5634.92 68.64 124.68 3096.79 2987.79 1062.33 3664.12 5947089.43 562431.53 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips:4laska Inc. Date: 5!171200% I"ime: 10:46:46 Page: 3 Field: Kuparuk Riuer Unit Co-ordinate(NE) keference: Well: 1 J-105, True North Site: Kuparuk 1J'Pad Verticaf('I'VD)Reference: 1„-105L1: 109.0 Welt: 1J-105 Section (VS) Reference: Well (O:OON,O.OOE,180.OOAzi) Welipath; ,1J-105L1 Survey Calculation 1lethod: Minimum Curvature Un Oracle Survey MD Intl Aim TVD Svc TVD N/S E/W MapY MapE "foul ft deg deg ft ft ft ft ft ft 5729.60 67.81 128.24 3131.92 3022.92 1010.10 3734.83 5947037.76 562502.63 MWD+IFR-AK-CAZ-SC 5821.68 68.00 131.77 3166.56 3057.56 955.26 3800.16 5946983.44 562568.39 MWD+IFR-AK-CAZ-SC i 5917.84 67.17 133.65 3203.23 3094.23 894.97 3865.48 5946923.67 562634.17 MWD+IFR-AK-CAZ-SC j 6013.13 67.29 136.78 3240.12 3131.12 832.62 3927.37 5946861.81 562696.53 MWD+IFR-AK-CAZ-SC 6107.84 66.97 139.97 3276.94 3167.94 767.40 3985.33 5946797.05 562754.99 MWD+IFR-AK-CAZ-SC 6204.07 66.40 144.53 3315.04 3206.04 697.55 4039.42 5946727.63 562809.62 MWD+IFR-AK-CAZ-SC 6298.64 67.96 148.24 3351.73 3242.73 624.97 4087.65 5946655.44 562858.41 MWD+IFR-AK-CAZ-SC 6392.55 68.51 151.67 3386.56 3277.56 549.49 4131.30 5946580.30 562902.65 MWD+IFR-AK-CAZ-SC 6487.79 68.90 155.54 3421.16 3312.16 470.02 4170.74 5946501.15 562942.70 MWD+IFR-AK-CAZ-SC 6583.62 68.87 159.34 3455.69 3346.69 387.48 4205.03 5946418.90 .562977.63 MWD+IFR-AK-CAZ-SC II 6680.00 68.68 161.33 3490.59 3381.59 302.89 4235.26 5946334.55 563008.52 MWD+IFR-AK-CAZ-SC lil 6775.36 72.18 163.40 3522.53 3413.53 217.27 4262.46 5946249.15 563036.38 MWD+IFR-AK-CAZ-SC 6870.19 76.19 165.88 3548.37 3439.37 129.31 4286.60 5946161.39 563061.21 MWD+IFR-AK-CAZ-SC 6965.40 76.34 167.67 3570.98 3461.98 39.28 4307.76 5946071.54 563083.06 MWD+IFR-AK-CAZ-SC 7061.58 78.85 169.66 3591.64 3482.64 -52.81 4326.21 5945979.60 563102.23 MWD+IFR-AK-CAZ-SC 7071.00 79.11 168.78 3593.44 3484.44 -61.89 4327.94 5945970.53 563104.03 MWD+IFR-AK-CAZ-SC ~ 7110.68 79.31 169.89 3600.87 3491.87 -100.20 4335.15 5945932.29 563111.54 MWD+IFR-AK-CAZ-SC 7159.39 79.06 171.55 3610.01 3501.01 -147.42 4342.87 5945885.14 563119.63 MWD+IFR-AK-CAZ-SC 7209.25 78.47 171.25 3619.72 3510.72 -195.77 4350.18 5945836.85 563127.32 MWD+IFR-AK-CAZ-SC 7252.45 77.54 170.59 3628.70 3519.70 -237.50 4356.85 5945795.18 563134.31 MWD+IFR-AK-CAZ-SC 7346.78 82.54 171.74 3645.01 3536.01 -329.27 4371.10 5945703.53 563149.28 MWD+IFR-AK-CAZ-SC 7395.05 82.00 171.17 3651.51 3542.51 -376.57 4378.21 5945656.29 563156.76 MWD+IFR-AK-CAZ-SC j 7443.98 81.97 172.22 3658.33 3549.33 -424.52 4385.21 b945608.41 563164.13 MWD+IFR-AK-CAZ-SC 7534.08 78.98 175.26 3673.24 3564.24 -512.82 4394.91 5945520.19 563174.51 MWD+IFR-AK-CAZ-SC ', , 7629.17 81.59 176.34 3689.28 3580.28 -606.29 4401.77 5945426.79 563182.10 MWD+IFR-AK-CAZ-SC i 7707.00 81.16 176.49 3700.96 3591.96 -683.09 4406.58 5945350.03 563187.51 MWD+IFR-AK-CAZ-SC 7763.30 86.82 177.15 3706.85 3597.85 -738.97 4409.68 5945294.18 563191.05 MWD+IFR-AK-CAZ-SC 7855.14 90.53 178.22 3708.97 3599.97 -830.69 4413.39 5945202.50 563195.47 MWD+IFR-AK-CAZ-SC 7899.42 90.22 178.73 3708.68 3599.68 -874.95 4414.57 5945158.25 563197.00 MWD+IFR-AK-CAZ-SC 7945.61 91.52 178.77 3707.98 3598.98 -921.13 4415.58 5945112.09 563198.37 MWD+IFR-AK-CAZ-SC 8034.28 92.63 179.61 3704.77 3595.77 -1009.73 4416.83 5945023.51 563200.31 MWD+IFR-AK-CAZ-SC 8126.55 92.99 180.95 3700.25 3591.25 -1101.88 4416.38 5944931.37 563200.58 MWD+IFR-AK-CAZ-SC 8172.81 93.66 182.03 3697.56 3588.56 -1148.05 4415.18 5944885.20 563199.74 MWD+IFR-AK-CAZ-SC 8216.33 92.96 184.49 3695.05 3586.05 -1191.42 4412.71 5944841.81 563197.61 MWD+IFR-AK-CAZ-SC ~, 8262.15 94.07 184.00 3692.24 3583.24 -1237.03 4409.32 5944796.18 563194.58 MWD+IFR-AK-CAZ-SC 8305.45 96.16 182.00 3688.38 3579.38 -1280.09 4407.06 5944753.11 563192.66 MWD+IFR-AK-CAZ-SC ~ 8354.57 94.20 181.78 3683.95 3574.95 -1328.98 4405.45 5944704.21 563191.43 MWD+IFR-AK-CAZ-SC 8396.26 92.84 181.46 3681.39 3572.39 -1370.58 4404.27 5944662.61 563190.57 MWD+IFR-AK-CAZ-SC it ~ 8440.97 92.88 182.18 3679.16 3570.16 -1415.21 4402.86 5944617.98 563189,50 MWD+IFR-AK-CAZ-SC 8487.27 92.16 182.57 3677.12 3568.12 -1461.42 4400.94 5944571.75 563187.95 MWD+IFR-AK-CAZ-SC j 8537.01 90.06 181.79 3676.16 3567.16 -1511.12 4399.05 5944522.05 563186.45 MWD+IFR-AK-CAZ-SC 8578.69 90.39 182.48 3675.99 3566.99 -1552.77 4397.49 5944480.39 563185.22 MWD+IFR-AK-CAZ-SC 8624.68 91.25 182.08 3675.33 3566.33 -1598.72 4395.66 5944434.44 563183.75 MWD+IFR-AK-CAZ-SC 8671.03 92.16 182.44 3673.96 3564.96 -1645.01 4393.84 5944388.14 563182.28 MWD+IFR-AK-CAZ-SC 8719.70 91.59 181.97 3672.36 3563.36 -1693.62 4391.97 5944339.52 563180.79 MWD+IFR-AK-CAZ-SC 8764.57 91.83 183.05 3671.02 3562.02 -1738.42 4390.00 5944294.70 563179.18 MWD+IFR-AK-CAZ-SC 8820.82 91.73 182.50 3669.28 3560.28 -1794.58 4387.28 5944238.53 563176.89 MWD+IFR-AK-CAZ-SC 8913.42 92.53 183.01 3665.84 3556.84 -1887.01 4382.83 5944146.08 563173.17 MWD+IFR-AK-CAZ-SC 9008.45 90.80 185.50 3663.07 3554.07 -1981.72 4375.78 5944051.32 563166.86 MWD+IFR-AK-CAZ-SC 9101.88 89.63 183.62 3662.72 3553.72 -2074.85 4368.36 5943958.15 563160.16 MWD+IFR-AK-CAZ-SC 9194.42 92.47 184.86 3661.03 3552.03 -2167.11 4361.52 5943865.85 563154.04 MWD+IFR-AK-CAZ-SC I 9288.72 89.81 180.26 3659.15 3550.15 -2261.26 4357.31 5943771.67 563150.57 MWD+IFR-AK-CAZ-SC j Halliburton Company Survey Report Company: ConocoPhillips Alaska lnc. __ Date: 5117!2007 Time: 10:46:4E f'agc: t Eield: Kuparuk River Unit Co-ordinate(NE} Reference: WeIL' 7 J-105, True North Site: Kuparuk 1 J Pad Vertical (TVD) Reference: 1 J-105L1; 109.0 Well: 1 J-105 Section (VS} Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-105L1 Survey'Calculation Method: Minimum Curvature Dh: Oracle Sur~°cv - - ~1D fncl .a2im TVD - Sys 7ti'D - N/S -_ Ell1' ft deg deg ft ft ft ft 9381 .61 89.75 179.34 3659. 51 3550. 51 -2354. 15 4357. 63 9474 .51 88.76 178.09 3660. 72 3551. 72 -2447. 02 4359. 72 ~i 9522 .43 92.34 181.29 3660. 26 3551. 26 -2494. 92 4359. 98 9567 .58 89.32 181.36 3659. 60 3550. 60 -2540. 05 4358. 93 9661 .58 90.49 181.29 3659. 76 3550. 76 -2634. 02 4356. 76 9756 .30 90.00 181.07 3659. 35 3550. 35 -2728. 72 4354. 81 9849 .35 90.49 183.52 3658. 95 3549. 95 -2821. 69 4351. 08 9941 .49 89.07 184.31 3659. 31 3550. 31 -2913. 61 4344. 79 10034 .66 86.04 182.48 3663. 28 3554. 28 -3006. 52 4339. 28 10126 .14 89.82 180.36 3666. 59 3557. 59 -3097. 89 4337. 02 ', 10216 .96 91.05 180.94 3665. 90 3556. 90 -3188. 70 4335. 99 10307 .97 91.23 178.41 3664. 09 3555. 09 -3279. 68 4336. 50 10397 .59 90.99 181.01 3662. 35 3553. 35 -3369. 27 4336. 96 10488 .78 91.91 180.21 3660. 04 3551. 04 -3460. 43 4335. 99 10579 .77 92.34 179.15 3656. 67 3547. 67 -3551. 35 4336. 49 10671 .50 90.18 179.39 3654. 65 3545. 65 -3643. 05 4337. 66 10763 .23 90.31 179.03 3654. 26 3545. 26 -3734. 77 4338. 93 10850 .91 89.57 179.65 3654. 35 3545. 35 -3822. 44 4339. 94 10943 .51 90.00 180.61 3654. 70 3545. 70 -3915. 04 4339. 73 11034 .15 87.59 179.55 3656. 60 3547. 60 -4005. 65 4339. 60 11125 .08 91.05 181.87 3657. 68 3548. 68 -4096. 55 4338. 47 11215 .58 90.62 181.59 3656. 36 3547. 36 -4187. 00 4335. 74 11303 .36 88.27 180.62 3657. 21 3548. 21 -4274. 75 4334. 05 11393 .75 89.63 184.51 3658. 87 3549. 87 -4365. 01 4330. 00 11484 .59 90.00 184.06 3659. 17 3550. 17 -4455. 60 4323. 22 11529 .13 88.76 183.00 3659. 65 3550. 65 -4500. 05 4320. 47 11571 .00 88.76 183.00 3660. 55 ~ 3551. 55 -4541. 85 4318. 28 MapN - __ MapE Tool ft ft _ 5943678.80 _---_ 563151.62 MWD+IFR-AK-CAZ-SC 5943585.96 563154.43 MWD+IFR-AK-CAZ-SC 5943538.07 563155.06 MWD+IFR-AK-CAZ-SC 5943492.94 563154.37 MWD+IFR-AK-CAZ-SC 5943398.96 563152.93 MWD+IFR-AK-CAZ-SC 5943304.26 563151.72 MWD+IFR-AK-CAZ-SC 5943211.27 563148.72 MWD+IFR-AK-CAZ-SC 5943119.31 563143.14 MWD+IFR-AK-CAZ-SC 5943026.37 563138.36 MWD+IFR-AK-CAZ-SC 5942935.00 563136.81 MWD+IFR-AK-CAZ-SC 5942844.19 563136.49 MWD+IFR-AK-CAZ-SC 5942753.22 563137.71 MWD+IFR-AK-CAZ-SC 5942663.64 563138.87 MWD+IFR-AK-CAZ-SC 5942572.49 563138.61 MWD+IFR-AK-CAZ-SC 5942481.59 563139.82 MWD+IFR-AK-CAZ-SC 5942389.91 563141.71 MWD+IFR-AK-CAZ-SC 5942298.21 563143.69 MWD+IFR-AK-CAZ-SC 5942210.56 563145.38 MWD+IFR-AK-CAZ-SC 5942117.97 563145.89 MWD+IFR-AK-CAZ-SC 5942027.37 563146.48 MWD+IFR-AK-CAZ-SC 5941936.48 563146.06 MWD+IFR-AK-CAZ-SC 5941846.02 563144.03 MWD+IFR-AK-CAZ-SC 5941758.26 563143.02 MWD+IFR-AK-CAZ-SC 5941667.98 563139.69 MWD+IFR-AK-CAZ-SC 5941577.35 563133.61 MWD+IFR-AK-CAZ-SC 5941532.88 563131.21 MWD+IFR-AK-CAZ-SC 5941491.07 - 563129.35 PROJECTED to TD ~~ Time Lo s _~ _- - - Date From To Dur S Depth_E Depth Phase Code Subcode T COM____ __ 04/07/2007 15:45 17:00 1.25 7,017 7,820 PROD2 DRILL TRIP P Cont to RIH with WS from 7,017' and sat down on top of A2 sand ZXP packer at 7,820', sat down on packer prior to orientating, PU and had set WS. checked WS orientation and was set at 87 deg left of high side. Found DP to be mismarked, the decision was made to fish WS. 17:00 18:15 1.25 7,820 7,707 PROD2 DRILL OTHR T Sheared off and dry milled lug off the top of the WS. PU wt 145K, do wt 85K, rot wt 107K 18:15 18:30 0.25 7,707 7,707 PROD2 DRILL OWFF T Monitored well- static, blew down top drive. 18:30 22:30 4.00 7,707 0 PROD2 DRILL TRIP T POOH from 7,707' and stood back hybrid pushpipe and MWD, LD mills, calc fill on trip out 37 bbls, actual 41 bbls. 22:30 23:00 0.50 0 297 PROD2 FISH PULD T MU whipstock retrieving hook BHA #7 &RIH to 297'. 23:00 00:00 1.00 297 2,626 PROD2 FISH TRIP T RIH with BHA #7 from 297' to 2,626' and tested MWD. 04/08/2007 00:00 01:00 1.00 2,626 7,630 PROD2 FISH TRIP T Cont. to RIH from 2,626' to 7,630', st wt u 140K, do wt 80K. 01:00 02:30 1.50 7,630 7,712 PROD2 FISH FISH T Oriented hook with MWD and RIH, tagged top of WS at 7,707', worked hook past top of WS and while orienting hook to 87L latched onto WS at 7,712', worked jars up to 60K over st wt and WS ulled free. 02:30 02:45 0.25 7,712 7,712 PROD2 FISH OTHR T Monitored well-static, blew down top drive. 02:45 06:15 3.50 7,712 297 PROD2 FISH TRIP T POOH from 7,712' to BHA #8 at 279'. 06:15 07:30 1.25 297 0 PROD2 FISH PULD T POOH and stood back hybrid pushpipe and MWD, LD retrieving hook and whipstock slide, PU and ins ected seals and ck'd ok. 07:30 09:15 1.75 0 403 PROD2 DRILL PULD T MU new whipstock BHA #8 with MWD and oriented same, RIH to 403' and shallow tested MWD and ck'd ok. 09:15 15:00 5.75 403 7,707 PROD2 DRILL TRIP T RIH with WS from 403' to 7,770', made MADD pass thru K-13 from 6,925' to 6,965' while RIH. st wt up 140K, do wt 84K, oriented WS and RIH tagging up on A2 ZXP packer at 7,820', set WS to 12 deg left of high side with top of WS at 7,707'. 15:00 16:00 1.00 7,707 7,707 PROD2 DRILL CIRC P Displaced hole over from 8.4 ppg SFMOBM to 8.4 MOBM 16:00 16:30 0.50 7,707 7,707 PROD2 DRILL DHEQ P Tested anchor seals in top of the ZXP packer to 1,000 psi for 10 min and tested ok. ~ .w . ~ ~ ~._ _ ~Q.. .~ ~~y~ 1 ~~ 3 i i Time Logs Date From To Dur S Depth E. Depth Phase Code__ Subcode T_ COM _ _ 04/08/2007 16:30 00:00 7.50 7,707 7,726 PROD2 DRILL MILL P Milled window in "B" sand lateral from 7,707' to 7,720', cont to mill to 7,726', milled at 2-4K WOM, 100 rpm's, 260 gpm at 2,100 psi, off btm torque 4K, on btm 4-8K, rot wt 104K, up wt 140K, do wt 84K. 04/09/2007 00:00 00:15 0.25 7,726 7,735 PROD2 DRILL MILL P Fin. milling window in "B" lateral from 7,726' to 7,735' MD/3,702' TVD. 6' of gauge hole and 9' of under gauge hole out of window. 00:15 01:00 0.75 7,735 7,735 PROD2 DRILL CIRC P Circ hole clean while working mills thru the window, circ at 280 gpm, 2,270 psi, 100 rpm's with 5K ft-Ibs torque, rot wt 98K, up wt 135K, do wt 82K. 01:00 01:15 0.25 7,735 7,658 PROD2 DRILL OTHR P Took SPR's then stood back 1 std of DP, blew down to drive. 01:15 02:00 0.75 7,658 7,658 PROD2 DRILL LOT P RU and performed a LOT on "B" lat window to 13.0 ppg EMW, 880 psi, 3,699' TVD with 8.4 MOBM. 02:00 04:45 2.75 7,658 4,397 PROD2 DRILL TRIP P POOH from 7,658' to 6,539', POOH 21 stds to 4,397' removing 63 supersliders w/POOH. cleared rig floor. 04:45 06:30 1.75 4,397 297 PROD2 DRILL TRIP P Cont to POOH from 4,397' to BHA #8 at 297'. 06:30 08:15 1.75 297 0 PROD2 DRILL PULD P POOH standing back hybrid pushpipe, LD bumper sub, downloaded MWD and LD milling assembly, upper mill was in au e, cleared ri floor. 08:15 08:30 0.25 0 0 PROD2 DRILL PULD P Pulled wear bushing 08:30 09:15 0.75 0 0 PROD2 DRILL OTHR P MU stack washer and flushed out same, blew down top drive, choke and kill lines. 09:15 10:45 1.50 0 0 PROD2 RIGMN SVRG P Held PJSM then slip and cut 72' of drl line then serviced the to drive. 10:45 15:00 4.25 0 0 PROD2 WELCT BOPE P RU and tested BOPE, tested rams, manifold and valves to 250 psi low and 3,000 psi high, including annular, tested rams and annular with both 4" and 4 112" test jts, tested Koomey, init. press. 3,000 psi, after functioning, 1;600 psi, took 35 seconds to gain 200 psi, 3 min 29 sec. for full recovery, 5 nitrogen bottles ave. 2,150 psi. Note: Jeff Jones with AOGCC waived witnessin of the test. 15:00 15:30 0.50 0 0 PROD2 DRILL PULD P Installed wear bushing and cleared rig floor 15:30 15:45 0.25 0 0 PROD2 DRILL SFTY P Held PJSM with rig crew and Sperry Sun on PU and MU of the BHA. 15:45 18:00 2.25 0 369 PROD2 DRILL PULD NP MU 6 3!4" BHA #9 RIH to 369', MU Hycalog concretion bit on 5" motor with 1.5 deg. bend, MU MWD and oriented and uploaded same, RIH with NMFDC's and HWDP and 'ars. _ ~~ _.d ~ _.® ~ _ F'<~ge 1~ cif ~~ s~~~__ Time Logs Date From__To_ _ Dur S Depth _E Depth Phase Code Subcode T COM_ - -- - 04l12/2007 13:00 17:30 4.50 11,314 11,571 PROD2 DRILL DDRL P Continue Directional drill 6 3/4" hole in the B Lateral from 11314' - 11571' MD. TVD = 3660'. ADT = 4.2 HRS. 17:30 18:00 0.50 11,571 11,571 PROD2 DRILL CIRC P Circulate remaining Hi Visc sweep out of hole @ 305 GPM - 3425 PSI. Observed 15% increase in cuttings at surface. Reciprocate & rotate drill strip while circulate. 18:00 18:15 0.25 11,571 11,571 PROD2 DRILL OWFF P Monitor well -static. 18:15 23:15 5.00 11,571 7,649 PROD2 DRILL REAM P BROOH at drilling rates from 11571' - 7649'. Observed good hole condition & hole fill. No issues with BHA through window area. 23:15 00:00 0.75 7,649 7,649 PROD2 DRILL CIRC P Pump Hi visc sweep and circulate casing clean @ top of window area. Pumps @ 310 GPM's - 2350 PSI. Crew Chan e 04/13/2007 00:00 00:30 0.50 7,649 7,649 PROD2 DRILL CIRC P Continue pump Hi visc sweep and circulate casing clean @ top of window area. Pumps @ 310 GPM's - 2350 PSI. 00:30 00:45 0.25 7,649 7,649 PROD2 DRILL OWFF P Monitor well -static. Blow down Top drive & lines. 00:45 01:30 0.75 7,649 9,143 PROD2 DRILL TRIP P Trip in hole from 7649' - 9143'. No issues through window area, ran out of down wei ht at 9143'. 01:30 04:45 3.25 9,143 11,571 PROD2 DRILL REAM P Wash & ream into hole from 9143' - 11571'. 04:45 07:30 2.75 11,571 11,571 PROD2 DRILL CIRC P Circulate Hi visc sweep and two bottoms up at 310 GPM's - 3600 PSI. Reciprocate & rotate drill string while circulating. Rig up vac trucks fro dis lacement. Max ECD = 11.2 PPG 07:30 09:00 1.50 11,571 11,571 PROD2 DRILL CIRC P Held PJSM with crew, mud engineer, and vac truck drivers. Discuss safey & hazard recognition issues. Designate a Spill Champion. Displace well with SFMOBM @ 300 GPM's - 3600 PSI. Obtain new T&D parameters as per rig en ineer. 09:00 09:30 0.50 11,571 11,571 PROD2 DRILL CIRC P Record Slow pump rates. Drop drift in drill string & pick up single from shed for TOH. Monitor well -static. 09:30 12:00 2.50 11,571 7,860 PROD2 DRILL TRIP P POOH on elevators from 11571' - 7860'. Observed proper hole fill, and ood hole condiitons. Crew Chan e 12:00 15:30 3.50 7,860 368 PROD2 DRILL TRIP P Continue POOH on elevators from 7860' - 368'. Observed proper hole fill and good hole conditions. No issues with assembly going through the window area. Rack back HWDP & Flex drill collars. 15:30 16:30 1.00 368 368 PROD2 DRILL PULD P Plug in and down load MWD assembly. Prep to lay down remaining BHA. ~ ~~___~_ i e~ .® ~_ ~~~ ~~ ~sf s j ' . Time Logs -._. _ __ - Date From To Dur S__Lle th E. De th Phase Code SubcoJe T COM 04/13/2007 16:30 17:30 __ 1.00 368 0 PROD2 DRILL PULD P ___ Breakout ,inspect and lay down Geo-Pilot BHA. Grade bit to 0/1/CT/G/X/I/NOITD. Clean & clear floor area. 17:30 18:00 0.50 0 0 COMPZ CASINC RURD P Rig up casing equipment to run 4 1/2" slotted liner. Held PJSM with crew, casing hand, TP & Co. rep. Discuss safety & hazard recognition issues, and rocedure to run 4 1/2" liner. 18:00 20:30 2.50 0 3,732 COMPZ CASIN RNCS P Make up Shoe joint & continue RIH picking up 4 1/2" slotted liner assembly as per detail. Run 86 joints. Observed ro er hole fill. 20:30 21:30 1.00 3,732 3,732 COMPZ CASINC RNCS P Make up the Liner setting sleeve assembly with CSR and running & setttin tools.. 21:30 00:00 2.50 3,732 8,863 COMPZ CASIN RUNL P Continue run 4 1/2" slotted liner as per detail on drill pipe from 3732' - 8863'. No issues with assembly through the window area. Observed proper hole fill. Crew Chan e 04/14/2007 00:00 02:00 2.00 8,863 11,578 COMPZ CASINC RUNL P Continue run 4 1/2" slotted liner as per detail on drill pipe from 8863' to tag bottom @ 11578' (note: 7' deeper). Observed proper hole fill. Obtain T&D parameters as per rig engineer. Liner had to be rotated only through a couple of spots, in the drilled concretion depths. Max surface torque seen = 9500 fUlbs. 02:00 02:30 0.50 11,578 7,840 COMPZ CASINC RUNL P Set liner top on depth as per detail @ 7840.55' with shoe at 11571'. UP WT = 185K, SO WT = 40K. Drop 29/32" ball in drill string. Pump ball down, allow to seat. Pressure to 2300 PSI to release from liner as per BOT rep. Pick up to observe released from liner & loss of upweight now at 155K. Pressure to 4200 PSI to shear ball seat. Pull 2 stands. 02:30 02:45 0.25 7,840 7,840 COMPZ CASIN< OTHR P Monitor well -static. Blow down top drive & lines. Install wi er rubbers. 02:45 03:30 0.75 7,840 6,161 COMPZ CASINC RUNL P POOH from 7840' - 6161". Observed ro er hole fill. 03:30 10:15 6.75 6,161 466 COMPZ CASINC RUNL P POOH from 6161' - 466. Reposition super sliders on each joint as planned, with VWVf re .183 total. 10:15 10:30 0.25 466 0 COMPZ CASIN RURD P Breakout, inspect & lay down liner runnin & settin tools. 10:30 11:00 0.50 0 0 COMPZ STK PULD P Clean & clear floor area of OBM. Send tools out. Brin tools to floor. 11:00 12:00 1.00 0 0 COMPZ RIGMN SVRG P Held PJSM, discuss safety & hazard recognition issues. Slipe & cut 71.5' of drillin line. Crew Chan e ~L3 £~~ ~ ~ cf ~:1 L I Time Logs _ Date From To Dur S De th E De th Phase Code Subcode T _ COM 04/14/2007 12:00 12:30 0.50 0 243 COMPZ STK -- PULD - P - Held PJSM with crew & BOT rep. Discuss safety & hazard recognition issues. Discuss procedure to make up and run whipstock retrieving hook assembly. Make up BHA# 11, retrievin hook assembl . 12:30 15:00 2.50 243 7,695 COMPZ STK TRIP P Trip in hole with BHA # 11 from 7695'. Fill Drill strip eve 25 stands. 15:00 17:00 2.00 7,695 7,712 COMPZ STK OTHR P Locate & wash retriving slot in slide from 7707' - 7717'. Orient retrieving hook to locate & latch into slot @ 7712'. Work drill string firing jars in increments up to 70K, and straight pulling to 115K to pull free. Pull uphole 40'. Monitor well - staic, no swabbing issues. No fluid loss. 17:00 18:00 1.00 7,712 7,712 COMPZ STK CIRC P Circulate bottoms up. Monitor well - staic. 18:00 21:30 3.50 7,712 0 COMPZ STK TRIP P POOH with whipstock assembly. Rack back HWDP. Observed proper hole fill. No losses. 21:30 23:00 1.50 0 0 COMPZ STK PULD P PJSM with crew. Discuss procedure to lay down whipstock &BHA. Breakout & lay down BHA, and space out i e and seal assembl . 23:00 00:00 1.00 0 0 COMPZ STK PULD P Clean & clear rig floor of OBM. Send out tools. Pull tools to rig floor for next BHA. Crew Chan e 04/15/2007 00:00 00:15 0.25 0 0 COMPZ RPCOh SFTY P Held PJSM with crew, BOT, & Sperry Sun reps. Discuss safety & hazard recognition issues. Discuss procedure for make up of Hook Hanger assembly with MWD. 00:15 02:45 2.50 0 0 COMPZ RPCOh PULD P Make up B Lateral Hook Hanger assembly with MWD as per detail. Orient MWD to Hook, 18o Degrees out as er rocedure. 02:45 03:00 0.25 0 376 COMPZ RPCOh TRIP P Trip in hole with 2 stands. Perform shallow pulse test on MWD at 100 GPM's. 03:00 05:45 2.75 376 7,707 COMPZ RPCOR TRIP P Continue trip in hole with Hook Hanger assembly from 376' - 7707'. Observed ro er hole fill. 05:45 08:15 2.50 7,707 7,892 COMPZ RPCOh HOSO P Continue trip in hole working mule shoe at the bottom of window. Tag "A" Lateral Xo @ 7871'. Pul Iback up hole racking back 3 stands. orient bent joint to go through window area. RIH to tga top of "B" lat Liner, and then hook the Hook hanger on depth in the window @ 7720' at 24 Deg right of high side. Drop 29/32" ball down string, pump down allowing ball to seat. Pressure to 2800 PSI to inflate ECP with 3P4 SBL, and then to 3600 to release tools. Mule shoe @ 7892' as er detail. ~ f~a~ ~~ cif 3 ~_ L J l J Time Logs Date From _ To r D _ u S. De th E. De th Phase Code Subcode T __. -_ COM __ 04/15/2007 08:15 09:30 _ _ _ 1.25 7,892 7,892 COMPZ RPCOti HOSO P _ Pull up observing releasing tool still engaged. Work string to release. No success. Apply left hand turn in drill string for saftey off release with max torque at 5K on surface. Max staright pull = 30K over. Drop 2nd ball - 1 3/4" for safe out. Continue work strip . 09:30 09:45 0.25 7,720 7,695 COMPZ RPCOf~ CIRC P Circulate drill string volume @ 61 SPM - 1090 PSI, while pumping down 2nd ball dropped 1 3/4" OD as per BOT rep. Assembly pulled free before we we landed the second ball. 09:45 12:00 2.25 7,695 2,750 COMPZ RPCOh TRIP P Monitor well -static. POOH with running tool assembly from 7695' - 2750'. Crew Chan e 12:00 13:00 1.00 2,750 0 COMPZ RPCOh TRIP P Continue POOH from 2750' -surface. Observed no running tools to surface, and BHA only to 3 1/2" IF crossover. Observed ro er hole fill. 13:00 14:00 1.00 0 0 COMPZ RIGMN SVRG P Service rig & top drive. Service crown section. Discuss tions with town. 14:00 16:30 2.50 0 30 COMPZ FISH PULD T Make up fishing tools BHA # 12. Screw in sub assembly with stop sub, float sub, circulating sub & agitator. No 'ars. BHA = 30.39'. 16:30 19:15 2.75 30 7,639 COMPZ FISH TRIP T Trip in hole with fishing assembly from 30' - 7639'. Observed proper hole fill. Fill drill strip eve 25 stands. 19:15 20:00 0.75 7,639 7,639 COMPZ FISH FISH T Obtain parameters. UP WT = 135K, SO WT = 75K, ROT WT = 110K with 5K free torque. Tag fish on depth @ 7697'. Rotate slowly to screw into fish observing 14 RH turns and torque stalled at 8K. Pull up to verify Brewed in. Work drill string, and increase pump rates for agitator in increments to 7 BPM - 1900 PSI. Utilize bumper jar to hit down on running tool, and repeat until observed assembly pulling free with 8-10K steady drag, hole swabbing. Max pull = 25K over. Monitor well -static. 20:00 00:00 4.00 7,639 4,604 COMPZ FISH TRIP T POOH slow observing hole swabbing for first 5 stands with steady 8-10K overpull. Suspect ECP and Hook Hanger coming out. Observed overpull up to 25K @ 7280' while pulling and hole began to take fluid. Monitor hole fill close. Correct fill observed for next 10 stands and continued on TOH. Pull to 4604' with stead over ull. 04/16/2007 00:00 03:00 3.00 4,604 30 COMPZ FISH TRIP T Continue POOH from 4604' to 30'. Observed proper hole fill. Total loss on TOH = 4 BBLS. z___-___~®~~ ~ ~ ~ m_ ~ m .m~.~ -- ~._~ F7 ?; of3 E J Time Logs __ ___ ___ Date From To Dur S. De th E. De th Phase Code Subcode T COM 04/16/2007 03:00 03:15 0.25 30 30 COMPZ FISH SFTY T Held PJSM with crew. Discuss safety & hazard recogniiton issues. Discuss breakout & lay down fishing assembly with fish. 03:15 04:15 1.00 30 0 COMPZ FISH PULD T Breakout & lay down fishing assembly with fish. Fish =Running & setting tools with inner string including MWD assembly. Note: No setting balls recovered in ball catcher sub. 04:15 04:45 0.50 0 0 COMPZ FISH PULD T Clear & clean rig floor of OBM. Send tools out. 04:45 05:30 0.75 0 0 COMPZ FISH WOOR T Held conference call with town discussing options & equipment availability. Decision to run a stop sub assembl to to fish. 05:30 05:45 0.25 0 14 COMPZ FISH PULD T Make up Fishing assembly #2. Stop sub assembly to tag fish. Total BHA len th = 14.03'. 05:45 09:30 3.75 14 7,301 COMPZ FISH TRIP T Trip in hole with Fishing BHA #2 from 14' -tag top of hook hanger assembly @ 7301'. This depth indicated Hook Hanger assembly pulled up hole -400' as suspected. Set down 8K to verify tag depth & movement of Hook hanger assembly. UP WT = 130K, SO WT = 72K. 09:30 10:15 0.75 7,301 7,301 COMPZ FISH CIRC T Circulate bottoms up @ 266 GPM's - 1640 PSI. 10:15 12:00 1.75 7,301 5,876 COMPZ FISH TRIP T Monitor well -static. Blow down Top drive & lines. POOH from 7301' - 5876'. Observed proper hole fill. Crew Chan e 12:00 14:30 2.50 5,876 0 COMPZ FISH TRIP T Continue POOH from 5876' -surface. Breakout, inspect & lay down fishing tools. 14:30 15:30 1.00 0 0 COMPZ RIGMN SVRG T Service rig. Clean & clear floor of OBM. 15:30 17:30 2.00 0 0 COMPZ FISH PULD T Make up 2 3/8" 511 tbg space out i e. Drift same. 17:30 19:30 2.00 0 0 COMPZ FISH WOEQ T Held PJSM with crew, BOT rep, SWS tubing punch reps. Discuss safety & hazard recognition issues. Discuss make up of tubing punch assembly spaced out in BHA. Obtain correct crossovers for make u of BHA. 19:30 20:15 0.75 0 106 COMPZ FISH PULD T Make up SWS tubing punch assembly with Bow spring centralizer as per reps. Make up 2 3/8" hydril 511 space out tubing to Hook hanger running tools. Double check all measurements & s ace out. Total BHA = 106.86'. 20:15 22:45 2.50 106 7,245 COMPZ FISH TRIP T Trip in hole with fishing BHA #3 from 106' - 7245' .Observed proper hole fill. Break circulation & obtain parameters of UP WT = 134K, SO WT = 82K, with pump at 1 BPM - 230 PSI as per SWS re . ~. . ._._.~._..- m~_. e® e.~ ~ ~ ~ ~ i'i~~G' ~'2 t>f ~5 .~l ~ ! Time Logs ~ Date From To _ __ __ Dur S. De th E. De th Phase Code Subcode T _ COM 04/16/2007 22:45 00:00 1.25 7,245 COMPZ _ _ _ FISH FISH T Continue RIH with pumps off, with no tag indication of tubing punch tools going into Hook Hanger assmy @ 7301'. Slack off to allow running tool to engage on depth @ 7322'. Set down 10K. Pull to 15K over, observe weight slowly falling off to up weight. Pull 1/2 stand observed well swabbing. Up weight indicated little or no drag, we then slacked off in hole past the 7301' depth with no tag up indicating free movement up & down. Pull 1 more stand verifyinig well swabbing. Rack back stand. 04/17!2007 00:00 02:00 2.00 7,248 7,248 COMPZ FISH FISH T Drop 1/2" aluminum ball in drill string as per SWS rep. Pump @ 1 BPM 700 PSI to allow ball to seat in 1000 stks. Tubing punch spaced out to punch ECP 3' above crossover to pup. Did not "see" any indication of tubing punch firing, but confirmed with 200 PSI differrence in pump pressure after calculated strokes pumped. Monitor well, observed flow and drill string holding 400 PSI. Allow well to stabilize, flow slowed down, but not stopped. Note: Mud engineer added 50 BBIs of new SFMOBM to pits, and well bore out of balance. Stopped offload into its to monitor well better. 02:00 04:30 2.50 7,248 7,248 COMPZ FISH CIRC T Circulate bottoms up at 30 SPM - 1350 PSI as per BOTrep, to prevent increased pressure from releasing tool at Hook Hanger. Note: Running tool requires 2300 PSI to release. We maintained pressures under 1500 PSI on CBU. Monitor well -allowing well to balance out until static. Fluid loss while CBU = 23 BBLS. Suspect injecting fluid while pumping ball down and CBU. 04:30 07:45 3.25 7,248 4,774 COMPZ FISH TRIP T Pump out of hole from 7248' to 4774' MD. Pull 5 stands with a gain of 2.3 BBLS. Monitor well -static. Make Top drive connection & fill pipe & hole with 5.4 BBLS as calculated displacement & gain. Continue POOH pumping out 2 BPM - 225 PSI 07:45 10:00 2.25 4,774 60 COMPZ FISH TRIP T POOH on elevators from 4774' MD to 60' MD (BHA) -Well taking proper fill at this time. 10:00 10:30 0.50 60 60 COMPZ FISH PULD T Clean and Clear rig floor 10:30 11:00 0.50 60 60 COMPZ FISH PULD T R/U power tongs to UD fish (Hook HangerAssy) and 2 3/8" handling tools. ~ ~ ~~ ~ ~~~ ~~ ~ ~ ®eme ~;~~~ :~ ref ~ ! Time Logs i Date From To Dur S Ce th E. De th Phase Code Subcode T COM 04/17/2007 11:00 12:00 1.00 60 30 COMPZ FISH PULD T Break out and UD Fish and inner strin . 12:00 13:30 1.50 30 0 COMPZ FISH PULD T PJSM on Tbg pert strip gun - UD ECP prk, bent jt, and tail assy. -Clean tools from floor 13:30 14:30 1.00 0 30 COMPZ FISH PULD T P/U Clean Out assy -Globe reverse basket w/ tandem boot baskets, Jars, Bum er sub. 14:30 16:45 2.25 30 7,737 COMPZ FISH TRIP T RIH w/ Clean out assy #1 -Fill pipe @ 3956', Con't TIH to 7737' break circu - w/ 5 bpm, PP 1500 psi, Up wt 125k, Dn wt 75k, Rot wt 100k 16:45 17:45 1.00 7,737 7,820 COMPZ FISH WASH T Wach and Rotate to 7815' -Stop rotating @ 7815' -Continue to 7820' Top of ZXP -Circu w/Globe reverse basket for recovery -Possible 2' fill ?? - Pull back to 7817' MD ,Circu & Rotate for recovery @ 7.5 bpm, 2200 psi for 5 min -Monitor well "Static" - Blow do To Drive. 17:45 20:30 2.75 7,820 0 COMPZ FISH TRIP T POOH on elevators -Hole fill on caluated 20:30 21:30 1.00 0 0 COMPZ FISH PULL T 8k down and check boot baskets - UD 6.75" Globe reverse basket- Recovery 1.75" Baker PD ball, 1 wad of duck tape, small and large chuncks of rubber, small and larger chuncks of metal, several small pieces of brass and about 1 to 1.5 Ibs of metal cutting from milling window. -Clean tools from floor. 21:30 23:00 1.50 0 98 COMPZ FISH TRIP T PJSM - P/U & M/U 3 5/8" Globe reverse basket and clean out assy w/ 2 tandem 4.75" boot baskets. Clean floor - Ck well "Static" 23:00 00:00 1.00 98 480 COMPZ FISH TRIP T RIH w/Clean out assy #2 04/18/2007 00:00 00:15 0.25 2,075 2,075 COMPZ FISH SFTY T PJSM -TIH -Hazard recognition 00:15 01:15 1.00 2,075 7,628 COMPZ FISH TRIP T TIH f/ 2075' MD to 7628' MD (Fill Pipe 2635', 4969', 7628' MD 01:15 02:00 0.75 7,881 7,881 COMPZ FISH OTHR T Blow do Top Drive -Flow Ck well Static 02:00 02:15 0.25 7,628 7,881 COMPZ FISH CIRC T Circu do and work 3 5/8"Globe basket f/ 7628' MD to 7881' MD (10' below A lat XO sub) - PR 33 spm, PP1060, Up wt 132K, Dn wt 80K 02:15 05:45 3.50 7,881 302 COMPZ FISH TRIP T POOH f/ 7881' to 302' -Hole taking proper fill. Calcu 57 bbls, Actual 59 bbls 05:45 07:30 1.75 302 0 COMPZ FISH PULD T Break out and UD 3 5/8" OD Globe reverse basket, 3 - 3.5" boot baskets, bit sub, flt sub, bumper sub, jars, circu sub - St Bk 2 stds H b ush i e. 07:30 08:00 0.50 0 0 COMPZ FISH PULD T Clear tools & Clean rig floor ~~ Time Logs -_ __ _ __ Date From To Dur _____ 5,_pe th E. De th Phase Code Subcode T COM __ __ 04/18!2007 08:00 08:15 0.25 0 0 COMPZ FISH RURD T R/U csg tools 08:15 08:30 0.25 0 0 COMPZ FISH SFTY T PJSM -Discuss PU & MU New Hook Hanger assy. Discuss associated hazards 08:30 10:15 1.75 0 198 COMPZ CASIN RUNL T P/U & M/U New Hook Hanger Assy 10:15 12:00 1.75 198 2,999 COMPZ CASINC RUNL T TIH - 198' to 2999' MD 12:00 13:30 1.50 2,999 7,690 COMPZ CASIN( RUNL T PJSM - Con't TIH f/ 2999' to 7690' MD - PU 10' for space out of drill string. Up wt 135K, Dn wt 83K 13:30 15:00 1.50 7,690 7,893 COMPZ CASIN RUNL T Tag up @ 7871' (XO in mother bore) Pull back to 7680' -Orient Hook - On third attempt liner went out into B lateral and Hooked window on depth. Pick up orient hook 180 deg and slack off thru window. Tagged XO on depth 7900' -Pull back up to 7700' -Orient Hook and slack off and Hook Hanger on depth 7720' MD (Mule shoe @ 7893' MD. 35K on hook. 15:00 18:45 3.75 7,893 7,893 COMPZ CASINC RUNL T Drop & Pump ball to seat (888 stks) - Pressure up to 2600 psi and inflate ECP (.34 bbl) -Pressure up to 3000 psi. PU from 35K to 75K and slack back to 40K, Pressure up to 3450 psi and shear ball seat. PU 20K over 155K) Slack bk to 40K - PU to 30K over (165K) slack back to Block Weight (35K) Work to 155K up and back to 40' Dn wt. We did this several times( 15-18) - On # 17 or 18 it showed travel w/ 155K up wt and swabbing pulled 6' up hole. Slacked off to see if it would re-hook and it did hook with 30K do wt. After conference with all parties discission made to PU to 15' checking to make sure cup was not the reason for the swab. String swabbed all of 15'. At that time after talking with all parties the dicission was made to "Safety Off' the hook hanger. Worked 3 rounds of left hand torque do 1 round at a time. Torque was released slowly and we received 1 round back -With 40K on Hook gained all string wt bk to 75K. Could not re-hook hanger. Discission made to POOH 18:45 00:00 5.25 7,893 4,582 COMPZ FISH TRIP T Pump OOH @ .5 bpm, PP 60 psi Pull rate 20-30 f m to 4582' MD 04/19/2007 00:00 04:00 4.00 4,582 198 COMPZ FISH FISH T Pump OOH f/ 4582' MD to 198' MD - PR 1 bpm, PP 110 psi (assure hole fill below ECP 04:00 05:45 1.75 198 0 COMPZ FISH PULD T UD Hook Hanger assy #2 and Inter strin ~~ ~ ~ __ ~ ~ _ _ ~ _ m €*ag~ ~~ ref 3 a ~ \~ Time Logs _ _ Date From To Dur S. De th E. Depth Phase Code Subcode T COM ~_ __ 04/19/2007 05:45 06:00 0.25 198 198 COMPZ FISH SFTY T PJSM on UD Hook Hanger assy - Hazard recognition and problems that might occur with tool sheared and released. 06:00 06:30 0.50 0 0 COMPZ FISH OTHR T Clear tools & Clean rig floor 06:30 08:45 2.25 0 0 COMPZ FISH WOEO T Talking with operations in town and rig - Sent tools back to Baker Shop to be inspected and re-loaded -STOPS -Rig crew re laced shot in into drive 08:45 09:00 025 0 0 COMPZ RIGMN SFTY T Wait on tools -STOPS -PJSM on Slip & Cut drill line 09:00 10:00 1.00 0 0 COMPZ RIGMN SVRG P Wait on Tools -STOPS -Slip & Cut drill line - 71' cut 10:00 10:15 0.25 0 0 COMPZ RIGMN SFTY P Wait on Tools -STOPS -PJSM on testin BOPs & Choke manifold. 10:15 10:30 0.25 0 0 COMPZ WELCT BOPE P Wait on Tools -STOPS -Drain stack - Pull wear bushin 10:30 12:00 1.50 0 0 COMPZ WELCT BOPE P Install test plug -Test BOPs and Choke Manifold -Floor safety valves & Top drive valves Test Pressures 250 psi Lo and 3000 psi High on all component . AOGCC, Lou Grimaldi waived witness test. 12:00 15:00 3.00 0 0 COMPZ WELCT BOPE P Con't Test BOPs and Choke Manifold - Test Pressures 250 psi Lo and 3000 psi High on all component .All tested "OK" No failures. 15:00 16:00 1.00 0 0 COMPZ RIGMN SVRG T Service & Lub Rig, Blocks and Draw works -Inspect draw works chains - Change oil filter in draw works oiler s stem. 16:00 18:45 2.75 0 0 COMPZ CASIN( WOEO T Wait on tools -STOPS - PU csg tongs to run Hook Han er ass . 18:45 19:00 0.25 0 0 COMPZ CASINC SFTY T PJSM on PU new Hook Hanger assy and handlin same. 19:00 19:45 0.75 0 178 COMPZ CASINC PUTB T PU Hook Hanger assy #3 - PU bent jt, full length XO jt, 2 jts 4.5" 11.6# L80 BTC csg, Marker pup 6', Baker Flan ed Hook Han er 4.5" X 7-5/8" 19:45 00:00 4.25 178 7,630 COMPZ CASINC RUNL T RIH w/ B Lat Hook Hanger assy #3 to 7630' MD -Fill pipe every 20 stds - Crew Chan e 04/20!2007 00:00 00:15 0.25 7,630 7,630 COMPZ CASIN SFTY T PJSM on Tripping -Hazard recognition 00:15 01:15 1.00 7,630 7,703 COMPZ CASINC RUNL T Con't TIH -Tag @ 7871' MD (Mother Bore XO sub) Made 1 more attempt and tagged in the MB -After picking back up and orienting 90 deg the string was slacked off into the B lateral. Made two attemps to Hook Hanger and was successful on the second after orienting 120 deg. Set down 35K -Good solid hook. TOHH @ 7703.33' MD ~ ~ ~ ~- m~ ~ ~®-. ~ ~-~v~ ~~ e~f 3 z~ L.._____._ ~..~...._ Tirne Logs ~i Date From To Dur S Depth E Depth Phase Coae S~,ibco.i T COIs1 04/20/2007 01:T5 02:00 .0.75 7,703 7,703 COMPZ CASINC CIRC T Drop 29/32" bail -Pump down same - Total stks 856 orr seat -Pressure up to 4200 psi (No Shear) Bleed pressure off to 2000 psi and pressure up to 4487 psi -Sheared ball set - PU wt 135K -Tool released 02:00 02:15 . 0.25 7,703 7,703 COMPZ RPCOh TRIP P Blow down top drive -Monitor well Static) 02:15 06:00 3.75 7,703 0 COMPZ RPCOti TRIP P POOH - UD Running Tool -( Inspection of tool showed all worked well. 06:00 06:30 0.50 0 0 COMPZ RPCOh .PULD P Clear all Tools from Rig floor -Clean ri floor of OBM 06:30 07:00 0.50 0 0 COMPZ RPCOti RURD P R/U Csg tools to run LEM assy 07:00 11:00 .4.00 0 358 COMPZ RPCOf~ PULD P P/U LEM assy per detail and orient to MWD. RD casin tools and clear floor. 11:00 12:00, 1.00 358 500 COMPZ RPCOti SRVY P RIH to 500' MD -Shallow pulse test MWD 12:00 14:00 2.00 500 7,552 COMPZ RPCOti TRIP P PJSM & Con't TIH w/ LEM to 7552' MD - Break circu - PR 3 BPM -Orient to hi h side - U wt 135K, Dn wt 75K 14:00 17:00 3.00 7,552 7,862 COMPZ RPCOh CIRC P Pump in hole @ 4 deg left - PU single & 10' pup -Tag SBR @ 7851' -Work seals in w/ 10-15K do wt -Worked in 11' to 7862' MD -LEM showed good latch. When LEM latched the orientation changed from 4L to 8R - Put 35k on LEM. 17:00 18:00 1.00 7,862 7,465 COMPZ RPCOti CIRC P Drop Ball and Pump same on seat- 615 stks -Pressure up to 4100 -Set ZXP and shear off tool. PU 5' and test ZXP packer for 5 mins @ 2500 psi. "OK" - PU to up wt 128k tools loose. Blow down TD 18:00 21:30 3.50 7,465 40 COMPZ RPCOti TRIP P POOH -Hole fill 1 bbl long 21:30 23:00 1.50 40 0 COMPZ RPCOti PULD P UD Running tools and MWD -Clear & Clean ri floor. 23:00 23:30 0.50 0 0 PROD3 DRILL PULD P P/U Mill assy tools to rig floor 23:30 00:00 0.50 0 0 PROD3 DRILL SFTY P PJSM -Crew change -Baker rep discuss M/U of Mill ass 04/21/2007 00:00 00:15 0.25 0 0 PROD3 DRILL SFTY P PJSM -Hazard recognition P/U BHA Millin ass 00:15 02:00 1.75 0 0 PROD3 RIGMN SVRG P PJSM -Change out Top Drive saver sub. (Noted on inspection that threads were shar and worn 02:00 03:45 .1.75 0 210 PROD3 DRILL PULD P M/U Whipstock assy - PU seal, Trip anchor, whipstock, MWD and orient to same. 03:45 04:30 0.75 210 210 PROD3 DRILL SRVY P Program MWD 04:30 05:00 0.50 210 356 PROD3 DRILL PULD P Con't P/U BHA Mill assy. 05:00 09:15 4.25 356 7,097 PROD3 DRILL TRIP P TIH to 500' -Shallow test MWD 'OK" - Con't TIH to 709T MD ~. ~_ _- . --- --- i Time Logs_ - _ --__ Date Fro~~~ To Dur S Doh F Deo_t__h_ f'n~js~~ (;ode 5 iha~d~ ~ ~ ~?P,1 _ 04/21/2007 09:15 09:45 0.50 7,097 7,185 PRODS DRILL SRVY P Break Circu - MADD pass f/ 7111' to 7185' MD -Orient tool to Hi Side - Up wt 140k, Dn wt 85k. 09:45 10:45 1.00 7,185 7,348 PRODS DRILL TRIP P Con't TIH, Orient to 12L Hi side, work torque out, Tag TOL @ 7465' MD, Observed seal enter SBR, Set trip. anchor w/ 15k Dn wt. Shear off of slide w! 35k do wt.-All appear "OK" ~'`*Note"* Whipstock set 12 Left of High Side. TOW @ 7348', BOW 7361' MD 10:45 12:00 .1.25 7,348 7,348 PRODS DRILL MILL P Displace over to drilling fluid MOBM, Start Millimg after MOBM had turned the corner around started mill @ 11:00 hrs, PR 280 gpm, PP 2400 psi, RPMs ` 90, Torq 5k. TOW 7348' MD 12:00 15:45 3.75 7,348 7-,361 PRODS DRILL MILL P Crew Change -PJSM - Mill D lat window f/ 7348' MD 7361' MD , WOM 2-4k, PR 300 gpm, PP 2350 psi, RPMs 90, Troq 3-6k, (pumped hi vis sweep 7356' MD 15:45 21:00 5.25 7,361 7,380 PRODS DRILL MILL P Drill with Mills f/ 7361' to 7380' MD Full gauge hole 6.75" to 7370' MD) about 10' below slide. Dressed window well with several passes-with and without MP. Window in great shape. It appears the started Mill is worn out and cannot make our footage needed. After a discussion with all team members the decision was made to pull mill assy and go back with a mud motor. 21:00 21:30 0.50 7,380 7,380 PRODS DRILL CIRC T Monitor Well -Pump dry job. 21:30 00:00 2.50 7,380 850 PRODS .DRILL TRIP T POOH to 850' 04/22/2007 00:00. 00:15 0.25 850 110 PRODS DRILL TRIP T PJSM - Con't POOH f/ 850' to 110' MD 00:15 01:45 1.50 110 0 PRODS DRILL PULD T UD BHR - Dn load data f/MWD - L/D Mill Assy. -Upper Mill full gauge - Pilot Mill slick, very little cutrite remainin 01:45 02:45 1.00 0 0 PRODS DRILL OTHR T Pull wear bushing -Using stack clean tool flush BOPS and surface equipment to remove all metal cuttings - Re-Install wear bushin 02:45 03:00 0.25 0 0 PRODS DRILL PULD T Clean & Clear Rig Floor 03:00 04:00 1.00 0 160 PRODS DRILL PULD T PJSM - P/U BHA #18 04:00 04:30 0.50 160 160 PRODS DRILL SRVY T Program MWD 04:30 07:30 3.00 160 7,266 PRODS DRILL TRIP T TIH 160' to 458' MD -Shallow Test MWD - Con't TIH 458' to 7266.0 MD - U wt 118k, Dn wt 64k ~~ ~~~ E ~ ~ ,,~~, ~3 cf 3 i `~, 1J-105 'B' Sand Liner Detail Weu: 1J-105 COl"iOC0~11~~1p5 4-1/2"Slotted and Blank Liner Date: 4/12/2003 A'~~~~'°t- 2 Run System Rig: Doyon 141 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS 7832.30 Note; Top "B" Lateral window @ 7707'MD 7832.30 Bttm of window @ 7720'MD 7832.30 Top of B lat liner@ 7840.55' MD out in OPEN HOLE 7832.30 Liner XO sub ID 3.93" @ 7900.29' MD 7832.30 7832.30 4" DP to Surface =_> 7832.30 .. , 7832.30 7832.30 :: ~ 7832.30 7832.30 7832.30 XO 3 1/2 IF x 4" HT 39 1.83 7832.30 Baker Liner setting tool (Does not stay in hole) 6.42 7834.13 HR Liner Setting Sleeve w/ 10' TBR 5.5" (ID 5.0") 12.67 7840.55 Liner Pup Jt 5.5" 15.5# L80 5.5"Hyd 521 b X p (4.89") 7.37 7853.22 Receptacle Jt 5.5" 15.5# L80 5.5" Hdy b X p (ID 4.89") 39.70 7860.59 XO - 5.5" Hyd 521 box X 4.5" BTC pin w/ TR (ID 3.93") 1.40 7900.29 4 1/2" Pup Jt, 12.6 ppf, L-80 w/TR ID 3.98" 3.79 7901.69 Jts 86 to 86 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) w/ TR 43.08 7905.48 ..................................................................................................................................... tlilairker Pu)S'~<"1~2" Ri~pi.;lt")~1~ppf, L-88 w/TR 9.77 7948.56 Jts s1 to s5 5 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) w/ TR 197.06 7958.33 Jts 8o to 80 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing w/ TR 43.34 8155.39 Jts 79 to 79 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) w/ TR 37.74 8198.73 Jts 77 to 78 2 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing w/ TR 85.06 8236.47 Jts 76 to 76 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) w/ TR 40.10 8321.53 Jts 74 to 75 2 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing w/ TR 85.86 8361.63 Jts 73 to 73 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) w/ TR 39.99 8447.49 Jts 72 to 72 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 34.85 8487.48 Jts s7 to 71 5 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 199.77 8522.33 Jts 66 to 66 1 Jts 4-1/2" BTC 11.6 ppf, L$0 Slotted Casing 43.41 8722.10 Jts 65 to 65 1 Jts 4-1/2" BTC 11.6 ppf, L$0 Casing *(Blanks) 35.83 8765.51 Jts 64 to 64 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 42.90 8801.34 Jts 63 to 63 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 40.34 8844.24 Jts 61 to 62 2 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 85.59 8884.58 Jts 6o to so 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.89 8970.17 Jts 59 to 59 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 41.62 9013.06 Jts 58 to 5s 1 Jts 4-1/2" BTC 11.6 ppf, L$0 Casing *(Blanks) 39.81 9054.68 Ran total of 52 jts Blank( 2164.97') and 34 jts Slotted( 1440.63'), Plus the blank guide shoe joint. Slots are 0.125" wide x 2.5" long x 32 slo/ft w/ (32) 2.5" long x .125" @ Up Wt 185K 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends. Dn Wt 40K We will run 16 Torque Rings. Jts# 73 thru 86# Block Wt 35K Ran shoe joint slick. Torqued liner w/o torque rings to 4500 ft-Ibs, w/ torque rings to 8000 ft/lbs Used Run-N-Seal thread compound on all connections. All drifted w/ 3.875" rabbit. CJ Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 2 LENGTH TOPS Jts 57 to 57 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.40 9094.49 Jts 52 to 56 5 Jts 4-1/2" BTC 11.6 ppf, L$0 Casing *(Blanks) 210.39 9137.89 Jts 51 to 51 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.30 9348.28 Jts 5o to 50 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.88 9391.58 Jts 49 to 49 1 Jts 4-1/2" BTC 11.6 ppf, L$0 Slotted Casing 43.43 9434.46 Jts 4s to 48 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.04 9477.89 Jts 47 to 47 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 42.42 9520.93 Jts 46 to 46 1 Jts 4-1/2" BTC 11.6 ppf, L$0 Casing *(Blanks) 42.86 9563.35 Jts 45 to 45 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 41.20 9606.21 Jts 44 to 44 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 41.54 9647.41 Jts 43 to 43 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.50 9688.95 Jts 42 to 42 1 Jts 4-1/2" BTC 11.6 ppf, L$0 Casing *(Blanks) 43.44 9732.45 Jts 41 to 41 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 42.05 9775.89 Jts 35 to 40 6 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 257.49 9817.94 Jts 33 to 34 2 Jts 4-1/2" BTC 11.6 ppf, L$0 Slotted Casing 84.99 10075.43 Jts 32 to 32 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.89 10160.42 Jts 31 to 31 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing 43.61 10203.31 Jts 3o to 30 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.78 10246.92 Jts 29 to 29 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.39 10289.70 Jts 2s to 2s 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.79 10333.09 Jts 27 to 27 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.51 10375.88 Jts 26 to 26 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.87 10419.39 Jts 25 to 25 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.39 10462.26 Jts 24 to 24 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.88 10505.65 Jts 23 to 23 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.65 10548.53 Jts 17 to 22 6 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 257.70 10592.18 Jts 16 to 16 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.40 10849.88 Jts 15 to 15 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.32 10893.28 Jts 14 to 14 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.45 10936.60 Jts 13 to 13 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 38.72 10980.05 Jts 12 to 12 1 Jts 4-112" BTC 11.6 ppf, L-80 Slotted Casing 35.82 11018.77 Jts 11 to 11 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.76 11054.59 Jts s to 10 2 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 80.24 11097.38 Jts s to s 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.32 11177.62 Jts 7 to 7 1 Jts 4-1/2" BTC 11.6 ppf, L$0 Slotted Casing 43.40 11219.94 Jts s to 6 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.44 11263.34 Jts 5 to 5 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.25 11305.78 Jts 4 to 4 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.58 11349.03 Remarks: Total = 86 H ydraForm 4.5" X 6.125" & 86 Stop rings Ran 1 Hydraform per joint floating under a stop ring installed in the middle of each joint. Liner weight including hanger ???K up, ??K down. Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 3 LENGTH TOPS Jts 3 to 3 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.66 11391.61 Jts 2 to 2 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing "(Blanks) 42.64 11435.27 Jts 1 to 1 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 42.94 11477.91 4-1/2" BTC 11.6 ppf, L-80 Casing "(Blank shoe joint) 42.47 11520.85 41/2" Silver Bullet Shoe 1.68 11563.32 BOTTOM OF SHOE __> 11565.00 11565.00 11565.00 TD 6-3/4" hole @ 11,571' MD / 3660' TVD 11565.00 4-1/2" Shoe 11,565' MD / 3660' TVD (s' Rat hole) 11565.00 11565.00 "A" Lat Top of ZXP @ 7820' MD 11565.00 XO sub @ 7871' MD 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 11565.00 Remarks: R~ Req Est to pre produce new West Sak tri-lateral injector 1J-105... Subject: Re: Reduesttopre produce new West Sak tri-lateralinjector 1J-105 PTD #'s ~-027, ~i-028„~5-029 From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: f~~1on, 07 May 2007 14:>9:11 -0800 To: NSK Pr~blc;il~ Well Su~v <nl(,17ra'.conocop~lillips.com> CC: James Re~~~ <jii7~re~~(u-~admin.state.ak.us=° Perry, I forgot to mention in the earlier message, all the permit numbers should be 207 rather than 206. Tom Thomas Maunder wrote, On 5/7/2007 12:11 PM: Perry, The intent to pre-produce this well was described in the permit to drill. Sundries should be submitted to convert from producer to injector near the end of the production period. Call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 5/7/2007 9:54 AM: Tom, New West Sak injector 1 J-105 PTD #'s 206-027, 206-028, 206-029 is being prepared fora 30 day pre-production period to start later this week. CPAI would like to pre-produce 1J-105 via gas lift through the open sliding sleeve above the packer, intentional T X IA communication, and delay the tubing pressure test until after the pre-production period has ended. This plan is similar to previously approved pre-production plans for 1J-118, and 1J-160. The completion has a packer at 7296' with a sliding sleeve (CMD} at 6685' and gas lift mandrels at 2262' and 6387'. A gas lift valve will be installed in the station at 2262, a dummy will be left in the station at 6387' and the sleeve will be left open as the bottom lifting point. With the sleeve open there will be T x IA communication . The annulus (IA) will not be isolated from produced fluids per 20 AAC 25.200(d) while on pre-production. Gaslift will be injected down the IA preventing production fluids from entering the IA. Both surface and intermediate casing strings were tested to 3000 psi for 30 minutes prior to drilling ahead on 3/25/07 and 4/2/07 respectively. Rig testing has demonstrated sufficient integrity to prevent uncontrolled releases. The packer was tested to 2500 psi for 30 minutes on 4/28/07 just prior to running the completion. The tubing was not tested on the rig as the sleeve was run in the open position. Coiled tubing is required to shift the sleeve due to well bore deviation. The tubing will be tested when the sleeve is closed at the end of the pre-production period and again during the state witnessed MITIA once injection has stabilized. Please confirm it is acceptable to proceed as described above. Sincerely Perry Klein Problem Well Supervisor 1 of 2 5/7/2007 3:17 PM R~ Request to pre produce new West Sak tri-lateral injector 1J-105... • • office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617(c~conocophillips.com 2 of 2 5/7/2007 3:17 PM • Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 • SARA1~d PALI~, GOVERPlOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ' FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-105L1 ConocoPhillips Alaska, Inc. Permit No: 207-028 Surface Location: 2186' FSL, 2432' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 2358' FNL, 2124' FWL, SEC. 1, T10N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1J-105, Permit No. 207- 027, API No. 50-029-23346-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the C fission to witness any required test, contact the Commission's petroleum field ins ect rat (907) 659-3607 (pager). DATED this5 day of March, 2007 cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~,EIVEL r i~ 2 S 2007 ~~ :a~s~a Un Gas Cons. Corrxniss:a, 1 a. Type of Work: Drill ^/ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service ^/ ' Development Gas ^ Multiple Zone^ Single Zone ~ 1 c. Specify if well is proposed or: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-105L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 11565' ND: 3634' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 2186' FSL, 2432' FEL, Sec. 35, T11 N, R10E, UM ~ 7. Property Designation: ADL 25661 & 25662 ' West Sak Oil Pool " Top of Productive Horizon: 1758' FSL, 1920' FWL, Sec. 36, T11 N, R10E, UM 8. Land Use Permit: ALK 471 & 2177 13. Approximate Spud Date: 3/25/2007 Total Depth: 2358' FNL, 2124' FWL, Sec. 01, T10N, R10E, UM ' 9. Acres in Property: 2560 14. Distance to Nearest Property: > 2 miles ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558776 ~ y- 5945998 Zone- 4 10. KB Elevation 4 (]~ ~~ ~ ~ ~f / /NSL A ~~~ (Height above GL): 28' RKB feet 15. Distance to Nearest Well within Pool: 1J-14 , 343' 11284' ~ 16. Deviated wells: Kickoff depth: 744Q ~ ft. Maximum Hole Angle: g4° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1682 psig s Surface: 1271 psig ~' 18. Casing Program ti S ifi Setting Depth Quantity of Cement Size ons pec ca Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 3265' 28' 28' 3293' 2250' 570 sx AS Lite, 180 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 8487' 28' 28' 8515' 3850' 500 sx DeepCRETE 6.75" 4.5" 11.6# L-80 BTC 4125' 7440' 3728' 11565' 3634' see above 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length .Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): ? Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~ BOP Sketch ^ Drilling Program 0 Time v. Depth Plot ^ Shallow Hazard Analysis / Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^ 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name Rand~Tho'mas Title Greater Kuparuk Area Drilling Team Leader Signature i ~~ `~~~,~ Phone ~ ~6 $ 3 v Date ~ Z~, /O 7 Pre r d haro 11 Drak Commission Use Only Permit to Drill ~'7 Number: ~ { "'~~ API Number: 50- ~Z~.- 23 ~ ~~"~ Permit Approval Date: 3 ' S • ~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: ~~~ ,~ - ~ ~ ~" ~.(~~.- Qa~~ Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No [~ Other: H2S measures: Yes ^ No it tional svy req'd: Yes []~ No ^ 3c7U ~ ~, ~'~ ~©P ~~ APPROVED BY THE COMMISSION DATE: ~ ^V ~ 0 ,COMMISSIONER Form 10-401 Revised 12/2005 ~ , ~ ~ ~ ~ ~-y ~ ~~` P /~ ~ _`~ ~!. v Submi in Duplicate Ap~n for Permit to Drill, Well 1J-105 L1 Revision No.0 Saved: 23-Feb-07 Permit It -West Sak Well #1J-105 L1 •~~~~ r.~ ~'t Application. for Permit to Drill.Document, (~1t~W~ll ~taximix~ 1M~11 VG14e Table of Contents 1. Well Name ............................................................................._................................... 2 Requirements of 20 AAC 25.005 (i) .............................................................._:..:...:..:.........:.......::........:. 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ...................................;...........:...........:.......:............................... 2 Requirements of 20 AAC 25.050(b) .........................................,..........................:..................:............... 3 3. Blowout Prevention Equipment Information ........................................... ......... 3 ... Requirements of 20 AAC 25.005(c)(3) ..................................................................:................:............... 3 4. Drilling Hazards Information... ........................... ...................... ....... ...... 3 .... ... .... .... ... Requirements of 20 AAC 25.005 (c)(4) ....................................:...........---...................................-.---.-.--.- 3 5. Procedure for Conducting Formation Integrity. Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5).....-~---~-~-~-~-~-~ .....................:...........................................:........... 3 6. Casing and Cementing Program ............................................................................ 3 Requirements of 20 AAC 25.005(c)(6) ....................:.......................................................................:...... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ..............................................................:.....................:.............. 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) .............................................:...........:......................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil Base) .........................................:.:............................... 4 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .....................................................................:......:......:.............. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ............................................................:...:....:.............:...........: 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ..............................................................................................:: 5 12. Evidence of Bonding ....................... .......................... ................................. 5 . .... ........ Requirements of 20 AAC 25.005 (c)(12)....: ...................................................:..................................:.... 5 1J-105L1 PERMIT IT Page 1 of 6 Printed: 23-Feb-07 .~°L ~ ~ ~ • Ap~n for Permit to Drill, Well 1J-105 L1 Revision No.O Saved: 23-Feb-07 13. Proposed Drilling Program ............................................. ... .............................. 5 ... ... Requirements of 20 AAC 25.005 (c)(13)............e ................................................................................._, 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ..............................................................:................................. 6 15. Attac h me nts ............................................................................................................. 6 Attachment 1 Directional Plan ............................................................................................................:... 6 Attachment 2 Drilling Hazards Summary ............................................................................................... 6 Attachment 3 Wel! Schematic ..............................................................................................................., 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each wet! must be identified by a unique name designated by the operator and a unique,4Pl number assigned by the commission under 20 AAC 25. ®40(b). Fora well with mu/tip/e well branches, each branch must Simi/ar/y be identified 6y a unique name andAP1 number by adding a suffix to the name designated far the well by the operator and to the number assigned to the we// by the commission.. The well for which this.Application is submitted will. be designated as iJ-105 L1. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An app/ication for a Permit to Drill must be accompanied 6y each of the fo/lowr`ng items, except far an item. already on file wr"th the commission and identified in the app/ication; (1) a plat identifying the properly and the property's owners and showing (A)the coordinates of the proposed location of the wel/ at the surface, at the top of each objective formation, and at fatal depth, referenced to govemmenta/section lines. (B) the coordinates of the proposed location of the wet! at the sun`ace, referenced to the state plane coordinate system for this state as maintained by the Natianat Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the wel/ at the top of each objective formation and at tata/ depth; ~~3~r Location at Surface 2187 FSL & ~&' FEL -Sec 35 - T11N - R10E ASP zone 4 NAD 27 Coordinates RKB E/evation 109' AMSL Northings; 5,945,998 Eastings; 558,776 Pad Elevation 81' AMSL Location at Top of Productive Interval West Sak "B" Sand 1758' FSL & 1920' FWL -Sec 36 - T11N - R10E ASP Zone 4 NAD 27 Coordinates MeaSU/'el/ De th, RKB.' 7,441 Northings; 5,945,604 Eastings; 563,131 Tota/ t/ertica/De th, RKB,• 3,729 Tota/ vertical De th, SS.• 3,619 Location at Total De th 2358' FNL & 2124' FWL -Sec 1 - T10N - R10E ASP Zone 4 NAD 27 Coordinates MedSUred De - th RKB; 11, 565 Northings; 5,945,604 Eastings; 563,371 Tota/ l/erticalDe th, RKB; 3,634 Total l/ertical De th, SS.' 3,525 and (D) other information required by20 AAC 25.115®(b); 1J-105L1 PERMIT IT Page 2 of 6 Pnnted.• 23-Feb-07 • Ap~n for Permit to Drill, Well1J-105 L1 Revision IVo.O Saved: 23-Feb-07 Requirements of 20 AAC 25.050(b) Ifa well is to be intentionally deviated, the application for a Permit to Drili (Form 10-4f11) must (1) include a plat, drawn to a suitable scale, showing the pafh of tiae proposed wellbore, including all adjacent weilbores within 2011 feet ofany portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within ZtJfJ feet of the proposed wel/bore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a cagy of the application by certr`fred mai/; or (B) state that the applicant is the only ah`ected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item a/ready on h/e with the commission and identified in the application; (3) a diagram and description of the blowout prevention. equipment (Bt7PE) as required by 20 AAC 25 IJ35, ZO A,4C 25. l13b, or 20 AAC 2s.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to dri l and complete well iJ-105 L1. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An app/ication for a Permit to Drill must be accompanied by each of the fo//awing items, except for an item already on fr/e with the commission and identified in the app/ication: (~#} r"nformation on drilling hazards, including (A} the maximum downho% pressure that maybe encountered, criterr`a used to determine it, and maximum potential surface pressure based on a methane gradient; r The expected reservoir pressures in the West Sak sands in the 1J area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak "B" sand formation is 1,271 psi, calculated: MPSP =(3,738 ft TVD)(0.45 - 0.11 psi/ft) =1,271 psi .~ (B) data on potentia/gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potentia/ causes of ho% problems such as abnormally geo pressured strata, lost circulatr`on zones, and zones that have a propensity for difi`erentia/sticking; Please see Attachment 2: 1J-105 L1 Drilling Hazards Summary. 5. Procedure for Conducting Formation Lntegrity Tests Requirements of 20 AAC 25.005 (c)(5) An app/ication for a Permit to Dri11 must be accompanied by each of the fallowing items, except for an item already on frte with the commission and identified in the appication.• (s) a description of the procedure for conducting formation. integrity tests, as required under 2f1 AAC 25.03t1(t}; The parent wellbore, 1J-105, will be completed with 7-5/8" intermediate casing landed in the West Sak A-' Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the °Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 1J-105L1 PERMIT IT Page 3 of 6 Printed: 23-Feb-07 °~~~~. Ap~n for Permit to Drill, Well 1J-105 L1 Revision No.O Saved: 23-Feb-07 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application far a Permit to Orill must be accompanied by each of the fallowing items, except for an item already an fi/e with the commission and identified in the application,• (G) a complete proposed casr`ng and cementing program as required by 20 RAC ZS. Q3(J, and a description of any slotted liner, pre- perfarated liner, or screen to be installed; Casino and Cementing Pronram Hole Top etm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in in t Ib/ft Grade Connection ft ft ft Cement Pro ram 4-1/2 6-3/4" A Sand ff}-~1 11.6 L-80 BTC CSG _u_. 4,184 7,540 / 3,745 11,724 / 3,798 Slotted- no cement ~ 4-1/2 slotted 6-3/4" B Sand Lateral (iJ-105 L1) 11:6 L-80 BTC CSG 4,125 .7,440/ 3,728 ~ a-~O ~~ 11,565/ 3,634 Slotted- no cement _1/ Slotted 6-3/4" D Sand Lateral (1J-105 L2) 11.6 L-80 BTC CSG 4,429 7,092/ 3,662 11,521 / o e - no cement C 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An app/ication for a Permit to Drill must be accompanied by each of the fa/laving items, except far an item a/ready an fr/e dvith the commission and identified in thhe app/ication: (7) a diagram and description of the diverter system as required by 20 AAC X5.435, unless this rec7uirement is valved by the commission under2lJAAC25.(I35(h)(2); No diverter system will be utilized during operations on iJ-105 Li. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An app/ication for a Permit to Dri/l must be accompanied by each of the fallowing items, except for an item already an file with the commr"ssian and identified in the application; (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC2s.l133; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 1J-105L1 PERMIT IT Page 4 of 6 Printed: 23-Feb-07 i \ 4,.~ Value Density (ppg) 8.6 Plastic Viscosity Ib/100 s1J 15 - 25 Yield "Point - cP 18 28 HTHP Fluid loss- (ml/30 min @ 200psi & <4.0 150° Oil /Water Ratio 70 / 30 Electrical Stabilit 650-900 Ap~n for Permit to Drill, Well 1 J-105 L1 Revision No.0 Saved: 23-Feb-07 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each ofthe fo/%wing items, except for an item already an fr/e with the commission and idertti~ed in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo pressured strata as required by ~0 AAC25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application far a Permit to Dri1/ must be accompanied by each of the fo1loiving items, except for an item already on frle with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection anafysis as required by 20 AAC25, 061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to gill must be accompanied by each of the following items, except for an item already on file with the commission and identr"fled in the application: (i1) fora well drilled from an ofshore platform, mobile bottom-founded structure, jack-up rig, or floating dri/ling vessel, an analysis of seabed conditionsas required by ZO AAC 25.06i(b); Not applicable: Application is not for an offshore well 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An applicatr"on for a Permit to Drill must be accompanied by each of the following items, except foran item a/ready on file. with the commission and identified in the application.• (Z2) evidence showing that the requirements af20AAC25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the appliccation: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-105 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 7,440 MD / 3,728' TVD, the top of the B sand. 2. Mill 6-3/4"window. POOH.. i 3. Pickup 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of B sand lateral at 11,565' MD / 3,634' TVD, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 7J-905L1 PERMITlT Page 5 of 6 Printed: 23-Feb-07 Ap~n for Permit to DriIF, Well 1J-105 L1 Revision No.O Saved: 23-Feb-07 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient. and set packer atop assembly and release from assembly. 11. POOH and prepare to drill the "D" sand lateral 1J-105L2. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .Requirements of 20 AAC 25.005 (c)(14) An app/icatian far a Permit to Drill mustc be accompanied by each of the following items, except for an itetrf already ort file with the commissian and identified in the applicafion: (14) a general description of how the operatar plans to dispose of dril/r`ng mud and cuttr`ngs and a statement of whether the operator intends to request authorizatidn under 20 AAC Z5, 11811 far an annu/ar dispasa! operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on iJ Pad, or by hauling the fluids to a KRU Class II disposal well Ail cuttings .generated will be disposed of either down a permitted annulus. on 1J Pad, hauled to the. Prudhoe .Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved .disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances). used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska: may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 .Well Schematic 1J-105L1 PERMIT IT Page 6 of 6 Hwy Printed: 23-Feb-07 • ConocoPhillips Alaska Plan: 1J-105 L1 (wp04) Sperry Drilling Services Proposal Report -Geographic 23 February, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-105 1J-105 L1 Local Coordinate Origin: Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Plan 1J-105 Plan RKB @ 109.OOft (Doyon 141 (28+81)) N True API - US Survey Feet 3p®rry Driliing Services HAL.LIBURTON Sperry Grilling Services Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-105 Wellbore: 1J-105 L1 Plan: 1J-105 L1 (wp04) WELL DETAILS: Plan 11-105 Ground Level: 31.00 +N/-S +E/-W Northing Fasting Latittude Longitude Slot 0.00 0.00 5945993.64 553776.16 70'15'47.036N 149°3l'2939W FORMATION TOP DETAILS No .TVDPath TVDSS MDPath Formation 1 1512.00 1403.00 1648.94 Pfrost 2 1660.00 1551.00 1876.16 T3 3 1960.00 1851.00 2561.79 K15 4 2250.00 2141.00 3293.57 Casing Pt 5 2910.00 2801.00 4947.61 Ugnu C 6 3266.00 3157.00 5830.31 Ugnu B 7 3322.00 3213.00 5980.64 Ugnu A 8 3455.00 3346.00 6347.45 K 13 9 3662.00 3553.00 7092.04 W Sak D 10 3703.00 3594.00 7289.25 W Sak C 11 3728.54 3619.54 7440.73 W Sak B I CASING DETAILS I No MD TVD TVDss Nazne Size I 3293.57 2250.00 2141.00 10 3/4" 10-3/4 2 7440.75 3728.54 3619.54 75/8" TOW 7-5/R 3 1156528 3634.00 3525.00 41/2" 4-Ii.L 2000 / 10 3/4" Casing @ 3294' MD, 2250' ND: 2066' FEL, 783' FEL - Sec35-T11 N-R10E 2500 L1 - 7 5/8" TOW @ 7441' MD, 3729' ND: 1758' FSL, 1920' FWL - Sec36-T11 N-R10E ~ L1 - BHL @ 11565' MD, 3634' ND: 2358' FNL, 2124' FWL - Sec01-T10N-R10E - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7 - - - - - - - - - - - - - - - - - - - - - -t' - - - - - - - - - - - - - - - - - - - - - 3000 r ~ ~ t ~ t ~ _ QO ~ ~ ,~ -Cp - - - - - - - - - - - - - - - - 1 - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - L - - - - - - - - - - - - - - - - - - - - - v - - - - - - - - - - - - - - - - - 1' - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - O - - - - ~ - - - - - - - - - - - - h I O O ---- --~ --- pp (rj -p-----i-- I~ 3500 ~ o o rn ~ ~ _ 1J-105 L2 (wp04) r~ o r-- L ~ ~ o. ------------- --- ~ -------- -__- ------ -O--O--- -------~----1d-M1OSL~ p04)------------- ------------------------- w o ° o , i i ~ ~ ~ - - 1J-105 (wp04) m i , ~ ~ U i i i ~ ~ ~ 4000 ~~ ~ ~ ~ ~ ~ ~ I ' ~ 1J-105 MB B Heel 01/19/07 ~ ~ ' ' ' ~ ~ - i ~ i i ~ i , i i H ~ i i i i i 1 J-105 B Top (wp04) i ; ~ ~, ~ ~ 4500 ~ i 1J-105 MB_B CP3 01/19/07 'i 1J-105 MB_B CP5 01/19/07 'i i , , ~ 1J-105 MB B CP1 01/19/07 1J-105 MB B CP2 01/19/07 1J-105 MB B CP4 01/19107 1J-105 D Toe 01/19/07 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 Vertical Section at 180.00° (750 ft/in) w' ConocoPhillips A'~ H!-.LL IBURTOIV WELLDF."CAILS: PIanIJ-105 Cxound Level: 81.00 Sperry Drilling Services +N/-s ;L -~~ ,~~ !,~~, Fasting 12ti[tude Longitude slot 0.00 000 ~9a„)9fi.64 558776-1G 70°I5'47.036N 149°31'29.39W Project: Kuparuk River Unit Site: Kuparuk 1J Pad zooo Well: Plan 1J-105 10 3/4" Casing @ 3294' MD, 2250' TVD: 2066' FEL, 783' FEL -Sec35-TI IN-RIDE Wellbore: 1 J-105 L1 Plan: 1J-105 L1 (wp04) tsoo o M $I1L: 218T FSL, 2432'FEL-Sec35-TII N-RIOE ~ " ~ r ~ o ``~ "'~ 1000 ~ r ~ \'~` o - i , i o °o s00 ~ ~ ~ ~SO~ , i~ 1 v0 I I J` ~O I ~ ~ ~P ~ _ 0 250 11-10~ AIl3 61leel UI 19;0 _____~ _ _ _ _ I J- 105 B Top (wp04) -s00 LI - 7 5/8" TOW (r~ 7441' MD, 3729' 1l'D: 1758' FSL, 1920' FWL - Sec36-Tl 1 N-RI OE- - - - - - ------- u-IOSnIB BcPlol lra -1000 G ^ -IS00 ------- I1-I Oi 51!313 CP~01.19D7 - - ~ - ~- -_~ O -2000 - 70 O -2SOO --------{IJ-IO~Vf3 [3 CP3 DL1907 -3000 -------I1-105 ,1113 F3 CI'J Oll90 -3500 - - - - - -- ~- - I I-IOi \II3 R CPS OU19:07 -4000 - _- -- -4soo -__-_- - ----- _ 34 I1-I r~>[3 Toe 01.196 LI - BFIL~ 11565' MD, 3634' TVD: 2358' FNL, 2124' FWL - Sec01-TlON-RlOE i -5000 CASING DETAILS Pl i an I1-105/IJ-105 LI (wp04) No MD TVD TVDss Name Size T - I 3293.57 2250.00 2141.00 10 3/4" 10-3/4 M Azimuths to True North 2 7440.7s 3728.s4 3619.s4 7 5/8" 'TOW 7-s/8 Magnetic North: 24.04° - 1156s.28 3634.00 3s2s.00 41/2" 4-1/2 -ss00 - Magnetic Field Strength: 57564.3nT Dip Angle: 80.77° Date: 7/5/2006 - Model: BGGM2005 000 - -6 -- ~ i ~ i i ~ i i ~ -s00 0 s00 1000 1500 2000 2s00 3000 3500 4000 4s00 5000 5500 6000 West(-)/East(+) (900 ft/in) ~~ ConocoPhillips Alaska 7(/'\j~ ,^~ lp~~(Y'~~I Ct3t1UCOP~1~1~5 Alaska Hallibffrton Company Planning Report -Geographic Database: Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-105 Company: ConocoPhillips Alaska. Inc. TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Sitc: Kuparuk 1J Pad North Reference: True Well: Plan 1J-105 Survey Caieulation Method: Minimum Curvature ~ Wellbore: 1J 105 L1 Design: IJ-105 L1 (wp04) Project Kul~~~n ik F'iv= r Unit North Slope Alaska, U nited States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-105 Well Position +N/-S 0.00 ft Northing: 5,945,998.64 ft Latitude: 70° 15' 47.036" N +E/-W 0.00 ft Easting: 558,776.16 ft Longitude: 149° 31' 29.390" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore n.,,,~ ~~ ,~ 1J-105 L1 ..<.. __~ ~~,- ~u, ~ , Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 7/5/2006 24.04 80.77 57,564 Design Audit Notes: Version: Vertical Section: 1J-105 L1 wou4r Phase: Depth From (TVU) (ft) 28.00 Plan Summary Measured Depth Inclination Azimuth 7,440.73 82.55 178.92 7,452.73 84.46 178.92 7,482.73 84.46 178.92 7,670.85 93.71 172.44 7,780.66 93.71 172.44 7,916.41 92.60 177.76 8,516.41 92.60 177.76 8,565.82 92.11 177.76 9,816.86 92.11 177.76 9,918.36 91.12 178.01 10,282.45 91.12 178.01 10,465.06 90.44 176.32 10,917.02 90.44 176.32 11,009.68 89.59 176.67 11,565.29 89.59 176.67 PLAN +N/-S (ft) 0.00 Tie On Depth: +E/-W (ft) 0.00 Sperry f~ri[ffng S®rvfces Direction (` ) 180 ~:_~0 7,440.73 Vertical Dogleg Build Turn Depth +N/-S +E/-W Rate Rate Rate TFO (ft) (ft) (ft) (°I100ft) (°/100ft) (°/100ft) (°) - 3,728.54 -427.72 4,352.32 0.00 0.00 0.00 0.00 3,729.90 -439.64 4,352.55 15.90 15.90 0.00 0.00 3,732.79 -469.50 4,353.11 0.00 0.00 0.00 0.00 3,735.79 -656.76 4,367.28 6.00 4.91 -3.45 -35.14 3,728.69 -765.38 4,381.70 0.00 0.00 0.00 0.00 3,721.22 -900.38 4,393.28 4.00 -0.82 3.92 101.62 3,694.00 -1,499.31 4,416.71 0.00 0.00 0.00 0.00 3,691.97 -1,548.64 4,418.64 1.00 -1.00 -0.01 -179.60 3,646.00 -2,797.87 4,467.58 0.00 0.00 0.00 0.00 3,643.14 -2,899.26 4,471.32 1.00 -0.97 0.25 165.41 3,636.00 -3,263.06 4,483.95 0.00 0.00 0.00 0.00 3,633.50 -3,445.42 4,492.98 1.00 -0.37 -0.93 -111.84 3,630.00 -3,896.44 4,522.01 0.00 0.00 0.00 0.00 3,629.98 -3,988.92 4,527.68 1.00 -0.93 0.38 157.95 3,634.00 -4,543.58 4,560.00 0.00 0.00 0.00 0.00 2/23/2007 10:20:41AM Page 2 of 6 COMPASS 2003.11 Build 48 • C©nocal~hit~ips Alaska Compass 2003.11 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-105 1J-105 L1 1J-105 L1 (wp04) Database: Company: Project: Site: Well: Wcllbore: Design: Planned Survey 1J-105 L1 (wp04) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/_yl/ Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft1 (°1100ft) (ft) 7,440.73 82.55 178.92 3,728.54 3,619.54 -427.72 4,352.32 5,945,604.94 563,131.26 0.00 427.72 L1 - 7 5/8" TOW @ 7441' MD, 3729' TVD: 1758' FSL, 1920' FWL - Sec36-T11 N-R10E - W Sak B - 7 5/8" TOW - 1J-105 B Top (wp04) 7,452.73 84.46 178.92 3,729.90 3,620.90 -439.64 4,352.55 5,945,593.03 563,131.58 15.90 439.64 7,482.73 84.46 178.92 3,732.79 3,623.79 -469.50 4,353.11 5,945,563.18 563,132.37 0.00 469.50 7,500.00 85.31 178.32 3,734.33 3,625.33 -486.69 4,353.52 5,945,545.99 563,132.92 6.00 486.69 7,600.00 90.23 174.88 3,738.23 3,629.23 -586.40 4,359.46 5,945,446.35 563,139.63 6.00 586.40 7,670.85 93.71 172.44 3,735.79 3,626.79 -656.76 4,367.28 5,945,376.06 563,148.00 6.00 656.76 7,700.00 93.71 172.44 3,733.91 3,624.91 -685.59 4,371.11 5,945,347.26 563,152.06 0.00 685.59 7,780.66 93.71 172.44 3,728.69 3,619.69 -765.38 4,381.70 5,945,267.56 563,163.27 0.00 765.38 7,800.00 93.55 173.20 3,727.47 3,618.47 -784.53 4,384.12 5,945,248.43 563,165.84 4.00 784.53 7,900.00 92.74 177.12 3,721.98 3,612.98 -884.00 4,392.55 5,945,149.04 563,175.04 4.00 884.00 7,916.41 92.60 177.76 3,721.22 3,612.22 -900.38 4,393.28 5,945,132.66 563,175.90 4.00 900.38 8,000.00 92.60 177.76 3,717.43 3,608.43 -983.82 4,396.54 5,945,049.26 563,179.82 0.00 983.82 8,100.00 92.60 177.76 3,712.89 3,603.89 -1,083.64 4,400.45 5,944,949.49 563,184.50 0.00 1,083.64 8,200.00 92.60 177.76 3,708.35 3,599.35 -1,183.46 4,404.35 5,944,849.71 563,189.18 0.00 1,183.46 8,300.00 92.60 177.76 3,703.82 3,594.82 -1,283.28 4,408.26 5,944,749.93 563,193.86 0.00 1,283.28 8,400.00 92.60 177.76 3,699.28 3,590.28 -1,383.10 4,412.16 5,944,650.15 563,198.55 0.00 1,383.10 8,500.00 92.60 177.76 3,694.74 3,585.74 -1,482.92 4,416.06 5,944,550.38 563,203.23 0.00 1,482.92 8,516.41 92.60 177.76 3,694.00 3,585.00 -1,499.31 4,416.71 5,944,534.00 563,204.00 0.00 1,499.31 1J-105 MB B CP2 01/ 19/07 8,565.82 92.11 177.76 3,691.97 3,582.97 -1,548.64 4,418.64 5,944,484.69 563,206.32 1.00 1,548.64 8,600.00 92.11 177.76 3,690.72 3,581.72 -1,582.76 4,419.97 5,944,450.58 563,207.92 0.00 1,582.76 8,700.00 92.11 177.76 3,687.04 3,578.04 -1,682.62 4,423.89 5,944,350.77 563,212.61 0.00 1,682.62 8,800.00 92.11 177.76 3,683.37 3,574.37 -1,782.48 4,427.80 5,944,250.95 563,217.30 0.00 1,782.48 8,900.00 92.11 177.76 3,679.69 3,570.69 -1,882.33 4,431.71 5,944,151.14 563,221.99 0.00 1,882.33 9,000.00 92.11 177.76 3,676.02 3,567.02 -1,982.19 4,435.62 5,944,051.33 563,226.68 0.00 1,982.19 9,100.00 92.11 177.76 3,672.34 3,563.34 -2,082.04 4,439.53 5,943,951.52 563,231.37 0.00 2,082.04 9,200.00 92.11 177.76 3,668.67 3,559.67 -2,181.90 4,443.44 5,943,851.70 563,236.06 0.00 2,181.90 9,300.00 92.11 177.76 3,664.99 3,555.99 -2,281.75 4,447.36 5,943,751.89 563,240.75 0.00 2,281.75 9,400.00 92.11 177.76 3,661.32 3,552.32 -2,381.61 4,451.27 5,943,652.08 563,245.45 0.00 2,381.61 9,500.00 92.11 177.76 3,657.64 3,548.64 -2,481.47 4,455.18 5,943,552.27 563,250.14 0.00 2,481.47 9,600.00 92.11 177.76 3,653.97 3,544.97 -2,581.32 4,459.09 5,943,452.45 563,254.83 0.00 2,581.32 9,700.00 92.11 177.76 3,650.29 3,541.29 -2,681.18 4,463.00 5,943,352.64 563,259.52 0.00 2,681.18 9,800.00 92.11 177.76 3,646.62 3,537.62 -2,781.03 4,466.92 5,943,252.83 563,264.21 0.00 2,781.03 9,816.86 92.11 177.76 3,646.00 3,537.00 -2,797.87 4,467.58 5,943,236.00 563,265.00 0.00 2,797.87 1J-105 MB B CP3 01/ 19/07 9,900.00 91.30 177.97 3,643.53 3,534.53 -2,880.91 4,470.68 5,943,152.99 563,268.75 1.00 2,880.91 9,918.36 91.12 178.01 3,643.14 3,534.14 -2,899.26 4,471.32 5,943,134.65 563,269.54 1.00 2,899.26 10,000.00 91.12 178.01 3,641.54 3,532.54 -2,980.83 4,474.15 5,943,053.11 563,273.00 0.00 2,980.83 10,100.00 91.12 178.01 3,639.58 3,530.58 -3,080.76 4,477.62 5,942,953.23 563,277.25 0.00 3,080.76 10,200.00 91.12 178.01 3,637.62 3,528.62 -3,180.68 4,481.09 5,942,853.35 563,281.50 0.00 3,180.68 10,282.45 91.12 178.01 3,636.00 3,527.00 -3,263.06 4,483.95 5,942,771.00 563,285.00 0.00 3,263.06 1J-105 MB B CP4 01/ 19/07 10,300.00 91.06 177.85 3,635.67 3,526.67 -3,280.60 4,484.58 5,942,753.47 563,285.77 1.00 3,280.60 10,400.00 90.69 176.92 3,634.14 3,525.14 -3,380.48 4,489.14 5,942,653.64 563,291.11 1.00 3,380.48 10,465.06 90.44 176.32 3,633.50 3,524.50 -3,445.42 4,492.98 5,942,588.73 563,295.45 1.00 3,445.42 2/23/2007 10:20:41AM Halliburton Company Planning Report -Geographic Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: • Sperry Drilling Seruices Well Plan 1J-105 Plan RKB @ 109.OOft (Doyon 141 (28+81)) Plan RKB@ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature Page 3 of 6 COMPASS 2003.11 Build 48 ~"ir~~~°~~~~ r~~'~~~ ~~' Halliburton Company H.iI~L.if~4,.~~~°t~ CQt'1C)Ct?Pf"11~~lp5 Planning Report -Geographic Sperry Drittingl Service Alaska Database: Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-105 Company: ConocoPhillips Alaska, Inc. ND Reference: Plan RKB @ 109.OOft (Doyon 141 (28+g1)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad. North Reference: True Well: Plan 1J-105 Survey Calculation Method: Minimum Curvature Wellbore: 1J-105 L1 Design: 1J-105 L1 (wp04) ~ Planned Survey 1J-105 L1 (wp04) Map Map MD Inclination Azimuth ND SSND +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°I100ft) (ft) 10,500.00 90.44 176.32 3,633.23 3,524.23 -3,480.29 4,495.22 5,942,553.89 563,297.97 0.00 3,480.29 10,600.00 90.44 176.32 3,632.46 3,523.46 -3,580.08 4,501.65 5,942,454.16 563,305.17 0.00 3,580.08 10,700.00 90.44 176.32 3,631.68 3,522.68 -3,679.87 4,508.07 5,942,354.43 563,312.37 0.00 3,679.87 10,800.00 90.44 176.32 3,630.91 3,521.91 -3,779.66 4,514.49 5,942,254.70 563,319.57 0.00 3,779.66 10,900.00 90.44 176.32 3,630.13 3,521.13 -3,879.45 4,520.91 5,942,154.98 563,326.77 0.00 3,879.45 10,917.02 90.44 176.32 3,630.00 3,521.00 -3,896.44 4,522.01 5,942,138.00 563,328.00 0.00 3,896.44 1J-105 MB B CP5 01/ 19/07 11,000.00 89.67 176.63 3,629.91 3,520.91 -3,979.26 4,527.11 5,942,055.23 563,333.75 1.00 3,979.26 11,009.68 89.59 176.67 3,629.98 3,520.98 -3,988.92 4,527.68 5,942,045.57 563,334.39 1.00 3,988.92 11,100.00 89.59 176.67 3,630.63 3,521.63 -4,079.08 4,532.93 5,941,955.46 563,340.35 0.00 4,079.08 11,200.00 89.59 176.67 3,631.35 3,522.35 -4,178.91 4,538.75 5,941,855.69 563,346.94 0.00 4,178.91 11,300.00 89.59 176.67 3,632.08 3,523.08 -4,278.74 4,544.57 5,941,755.92 563,353.54 0.00. 4,278.74 11,400.00 89.59 176.67 3,632.80 3,523.80 -4,378.57 4,550.38 5,941,656.15 563,360.14 0.00 4,378.57 11,500.00 89.59 176.67 3,633.53 3,524.53 -4,478.40 4,556.20 5,941,556.38 563,366.73 0.00 4,478.40 11,565.29 89.59 176.67 3,634.00 3,525.00 -4,543.58 4,560.00 5,941,491.24 563,371.04 0.00 4,543.58 L1 - BHL @ 11565' MD, 3634' ND: 2358' FNL, 2124' FWL - Sec01-T10N -R10E - 4 1/2" - 1J-105 B Toe 01/19/07 2/23/2007 10:20:41AM Page 4 of 6 COMPASS 2003.11 Build 48 ~ ~ E Halliburton Company ~o,t„ ~~~1T;'s~ at1t3C 1t ~15 Q Planning Report -Geographic Sperry Clritling Services Database: ..Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-105 Company: ConocoPhillips Alaska, Inc. TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-105 Survey Calculation Method: Minimum Cu rvature Wellbore: 1J-105 L1 Design: 1J-105 L1 (wp04) Geologic Targets 1J-105 L1 TVD Target Narne +N/-S +E/-W Northing Fasting (ft) -Shape ft ft (ft) (ft) 3,630.00 1J -105 MB_B CP5 01/19/07 -3,896.44 4,522.01 5,942,138.00 563,328.00 - Polygon Point 1 0.00 0.00 5,942,138.00 563,328.00 Point 2 -647.39 37.99 5,941,491.00 563,371.04 3,798.00 1J-105 A Toe 01/09/07 -4,695.96 4,575.77 5,941,339.00 563,388.00 -Point 3,739.00 1J -105 MB_B CP1 01/19/07 -509.73 4,359.42 5,945,523.00 563,139.00 - Polygon Point 1 0.00 0.00 5,945,523.00 563,139.00 Point 2 -990.59 57.34 5,944,534.00 563,204.00 3,646.00 1J -105 MB_B CP3 01/19/07 -2,797.87 4,467.58 5,943,236.00 563,265.00 - Polygon Point 1 0.00 0.00 5,943,236.00 563.,265.00 Point 2 -465.20 16.37 5,942,771.00 563,285.00 3,694.00 1J -105 MB_B CP2 01/19/07 -1,499.31 4,416.71 5,944,534.00 563,204.00 - Polygon Point 1 0.00 0.00 5,944,534.00 563,204.00 Point2 -1,298.62 50.87 5,943,236.00 563,265.00 3,634.00 1J-105 B Toe 01/19/07 -4,543.58 4,560.00 5,941,491.24 563,371.04 - Point 3,562.00 1J-105 D Toe 01/19/07 -4,504.78 4,555.97 5,941,530.00 563,366.71 - Point 3,749.00 1J -105 MB_B Heel 01/19/07 -85.59 4,347.73 5,945,947.00 563,124.00 - Polygon Point 1 0.00 0.00 5,945,947.00 563,124.00 Point 2 -424.47 11.69 5,945,523.00 563,139.00 3,636.00 1J -105 MB_B CP4 01/19/07 -3,263.06 4,483.95 5,942,771.00 563,285.00 - Polygon Point 1 0.00 0.00 5,942,771.00 563,285.00 Point 2 -633.39 38.06 5,942,138.00 563,328.00 3,728.54 1J-105 B Top (wp04) -427.72 4,352.32 5,945,604.95 563,131.26 - Point Prognosed Casing Points Measured Vertical Casing Hoie Depth Depth Diameter Diameter (ft) (ft) ("} ~~•} 3,293.57 2,250.00 10-3/4 13-1/2 7,440.75 3,728.54 7-518 9-7/8 11,565.28 3,634.00 4-112 6-3/4 2/23/2007 10:20:41AM ge 5 of 6 P COMPASS 2003.11 Build 48 a ~~ ~'` Halliburton Company ;=w~~~~~~i~~~~ ®i'10CO~i[~~1~35 Planning Report -Geographic Alaska Sp®rry Drifting S®Irvices Database: Compass 2003.11 f , _ Local Co-ordinate Reference: Well Plan 1J-105 Company: ConocoPhillips Alaska, Inc. TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81 )) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81 )) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-105 Survey Calculation Method: Minimum Curvature Wellbore: 1J-105 L1 Design: 1J-105 L1 (wp04) Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W {ft) (°) (°) (ft) (ft) (ft) Name 1,648.94 47.24 56.34 1,512.00 301.03 387.17 Pfrost 1,876.16 53.76 56.34 1,660.00 396.48 530.50 T3 2,561.79 66.64 58.76 1,960.00 734.75 1,043.66 K15 3,293.57 66.70 67.00 2,250.00 1,027.24 1,647.66 Casing Pt 4,947.61 65.84 96.03 2,910.00 1,291.13 3,127.83 Ugnu C 5,830.31 68.13 134.13 3,266.00 951.23 3,843.76 Ugnu B 5,980.64 68.13 134.13 3,322.00 854.09 3,943.89 Ugnu A 6,347.45 69.87 147.85 3,455.00 594.82 4,165.04 K 13 7,092.04 78.00 179.32 3,662.00 -85.59 4,347.73 W Sak D 7,289.25 78.03 179.32 3,703.00 -278.47 4,350.02 W Sak C 7,440.73 82.55 178.92 3,728.54 -427.72 4,352.32 W Sak B Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W Comment (ft) (ft) (ft) (ft~ 7,440.74 3,728.54 -427.73 4,352.32 L1 - 7 5/8" TOW @ 7441' MD, 3729' TVD: 1758' FSL, 1920' FWL - Sec36-T11 11,565.29 3,634.00 -4,543.57 4,560.00 L1 - BHL @ 11565' MD, 3634' TVD: 2358' FNL, 2124' FWL - Sec01-T10N-R1( 2/23/2007 10:20:41AM Page 6 of 6 COMPASS 2003.11 Build 48 tk tai ~~~~~~ ~~ • ConocoPhillips Alaska L~ Plan: 1 J-105 L1 (wp04) Sperry Drilling Services Anticollision Summary 23 February, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-105 1J-105 L1 Local Coordinate Origin: Centered on Well Plan 1J-105 Viewing Datum: Plan RKB @ 109.OOft (Doyon 141 (28+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet ,;~,~ Sperry Driliing Services nRicin~~i SURVEY PROGRAM Date: 2007-02-21700:00:00 Validated: Yes Version: Depth FromDepth'Fo Survey/Plan Tool 28.UU SUU.OU CB-GYRO-SS 800.00 74x0.73 MWT)+1FR .46-CA! SC' 7440.73 11565.29 1J-IOS Ll (wp04) DIVVIT+IFR _aK-CA! SC u , , 1 J-14 vo tao COMPANY DETAILS: ConocoPhillips Alaska, Inc. Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based so Travelling Cylinder Azimuth (TFO+AZI) (°~ vs Centre to Centre Separation ~ 1~0 ft/ink NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1)•105 Ground Level: 81.00 +NI-S+EI-W Northing Easting Latittude Longitude Slot 0.00 0.00 5945998.64 558776.16 70°15'47.036N 149°31'29.39W REFERENCE INFORMATION Co-ordinate (N1E) Reference: Well Plan 1)•105, True North Vertical (TVD) Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Section (VS) Reference: Slot • (O.OON, O.OOE) Measured Depth Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Calculation Method: Minimum Curvature From Colour To MD 0 250 250 500 500 750 750 1000 1000 1250 1250 1500 1500 1750 1750 2000 2000 2250 2250 2500 2500 3000 3000 4000 4000 5000 5000 6000 6000 7000 7000 8000 8000 9000 9000 10000 10000 13900 ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: SOStations Depth Range From: 7440.73 To 11565.292568976 Maximum Range:1353.7292512976 Reference: Plan: 1J-105 L1 (wp04) 0 180 90 Travelling Cylinder Azimuth (TFO+ALI) ~°( vs Centre to Centre Separation (50 ft/in( 6ECTIDN DETAILS Sec MD Irrc An ND +W-5 ~E/-W Oleg TFace VSac Taigat 1 ]440.]3 82.55 1]892 3]2854 -02].]2 4352.)2 0.00 000 42].]2 2 ]452.)3 84.46 1]892 3]2990 -0)964 4352.55 1590 3 )482.]3 84.46 1]6.52 3]32]9 -06950 435).11 000 0.00 439.64 000 469.50 )6)065 93.]1 1]244 3]35]9 -656.]6 436].28 600 5 )]80.66 9J ]I 1]254 3)2869 -]6538 4381.]0 0.00 -)5.14 656.)6 0.00 )65.38 6 )91641 92.60 1]])6 3]2122 -900.38 4393.18 4.00 101.62 900.38 6516.41 52.60 1]T ]6 369400 -1499.31 4416]1 0.00 B 8565.82 92.11 1)]]6 36919] -1548.fid 4418.54 1.00 0.00 1499.31 -1]9.80 1548 fi4 IJ-tO51.1B_B CP20t15.0] 9 961686 92.11 1]7]6 364'°.00 -2]9].8] 446].58 000 000 2)9]0] IJ-105 MB_B CP301119:0] 10 9918.36 91.12 1]001 364314 -1899.2fi 44)1 J2 100 1 10282.45 91.12 1]001 363600 -326306 4463.95 0.00 16541 1099.26 000 32630fi tJ~105 MB_B CP401I19I0] 12 1046506 9D.44 1]fi.33 3633.50 X44542 449190 100 131091].02 90.44 1)6.32 36)000 -3896.44 452]01 000 111 Bd 3645.42 000 3696.44 IJ-106 MB BCP501/110] 14 11009.68 89.59 176 6] 3629 99 -3988.92 452) 68 100 1511565.29 89.59 1]66] 3634.00 >543.58 456000 000 15].95 3986 92 000 454358 1J-105 BT°a 01/19/0] f 'CCl1'1000~11 ~ ~ t ~"JS Alaska Company: ConocoPhillips Alaska, Inc Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-105 Well Error: O.OOft Reference Wellbore 1J-105 L1 Reference Design: 1J-105 L1 (wp04) • Halliburton Company ~~i,-~1~~~"~'~~' Anticollision Repoli gperry Drilling Servtce:s Local Co-ordinate Reference: Well Plan 1J-105 ND Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 2.00 sigma Database: Compass 2003.11 Offset TVD Reference: Offset Datum Reference 1J-105 L1 (wp04~~ Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: 7,440.73 to 11,565.29ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,353.73ft Error Surtace: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 2~23r (`i17 From To (ft) (ft} Survey (Wellbore) Tool Name Description 28.00 800.00 1J-105 (wp04) (1J-105) CB-GYRO-SS Camera based gyro single shot 800.00 7,440.73 1J-105 (wp04) (1J-105) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,440.73 11,565.29 1J-105 L1 (wp04) (1J-105 L1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 2/23/2007 3:52:17PM Page 2 of 5 COMPASS 2003.11 Build 48 ~~~~N • ;~ CQlnacaPhi[lips Alaska Company: Project: Reference Site: Site Error: Reference Well: Well Error: Reference Wellbore LReference Design: Summary ConocoPhillips Alaska. Inc Kuparuk River Unit Kuparuk 1J Pad O.OOft Plan 1J-105 O.OOft 1 J-105 L1 1J-105 L1 (wp04) Halliburton Company Anticollision Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calcufafion Method: Output errors are at Sperry Orilliing S®rvices Database: Offset ND Reference: Well Plan 1J-105 Plan RKB @ 109.OOft (Doyon 141 (28+81)) Plan RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature 2.00 sigma Compass 2003.11 Offset Datum Site Name Offset Well -Wellbore -Design Kupa~u'r 1J f ad • Reference Measured Depth (ft) Offset Centre to No-Go Allowable Measured Centre Distance Deviation Depth Distance (ft) from Plan Warning 1J-10L - 1J-102 - 1J-102 Out of range 1J-102 - 1J-102 L1 - 1J-102 L1 Out of range 1J-102 - 1J-102 L2 - 1J-102 L2 Out of range 1J-102 - 1J-102 L2 PB1 - 1J-102 L2 P61 Out of range 1J-102 - 1J-102 L2 PB2 - 1J-102 L2 PB2 Out of range 1J-102 - 1J-102 PB1 - 1J-102 PB1 Out of range 1J-102 - 1J-102 P62 - 1J-102 PB2 Out of range 1J-102 - 1J-102 P63 - 1J-102 PB3 Out of range 1J-109 - 1J-109 - 1J-109 Out of range 1J-109 - 1J-109 PB1 - 1J-109P61 Out of range 1J-109 -Plan 109a L1 - 1J-109a L1 (wp02) 11,508.82 11,882.72 1,181.48 209.45 972.04 Pass -Major Risk 1J-109 -Plan 1J-109a - 1J-109a (wp02) 11,454.81 11,833.05 1,197.05 222.36 974.69 Pass -Major Risk 1J-109 -Plan 1J-109a L2 - 1J-109a L2 (wp02) 11,453.16 11,824.14 1,184.87 213.65 971.22 Pass -Major Risk l 1J-14 - 1J-14 - 1J-14 11,283.77 7,500.00 342.52 159.13 183.38 Pass -Major Risk 1J-152 - 1J-152 - 1J-152 Out of range 1J-152 - 1J-152 L1 - 1J-152 L1 Out of range 1 J-152 - 1 J-152 L2 - 1 J-152 L2 Out of range 1J-152 - 1J-152 PB1 - 1J-152 PB1 Out of range 1J-152 - 1J-152 PB2 - 1J-152 P62 Out of range 1 J-154 - 1 J-154 - 1 J-154 Out of range 1J-154 - 1J-154 L1 - 1J-154 L1 Out of range 1J-154 - 1J-154 L2 - 1J-154 L2 Out of range 1J-156 - 1J-156 - 1J-156 Out of range 1J-156 - 1J-156L1 - 1J-156L1 Out of range 1J-156- 1J-156L1PB1 - 1J-156L1PB1 Out of range 1J-156 - 1J-156L2 - 1J-156L2 Out of range 1J-159 - 1J-159 - 1J-159 Out of range 1J-159 - 1J-159 L1 - 1J-159 L1 Out of range 1J-159 - 1J-159 L1 PB1 - 1J-159 L1 PB1 Out of range 1J-159 - 1J-159 L1 P62 - 1J-159 L1 PB2 Out of range 1J-159 - 1J-159 L2 - 1J-159 L2 Out of range 1J-159 - 1J-159 PB1 - 1J-159 PB1 Out of range Plan 1J-105 - 1J-105 - 1J-105 (wp04) 7,450.00 7,450.00 0.12 0.60 -0.48 FAIL - No Errors Plan 1J-105 - 1J-105 L2 - 1J-105 L2 (wp04) 7,448.48 7,450.00 55.34 0.47 54.87 Pass - No Errors Plan 1J-107 -Plan 1J-107 - 1J-107 (wp03) 11,545.68 11,975.00 1,190.42 202.03 988.40 Pass -Major Risk Plan 1J-107 -Plan 1J-107 L1 - 1J-107 L1 (wp03) 11,551.89 11,975.00 1,176.54 213.86 962.69 Pass -Major Risk Plan 1J-107 -Plan 1J-107 L2 (wp03) - 1J-107 L2 ~ 11,555.48 11,975.00 1,176.99 215.97 961.02 Pass -Major Risk Plan 1J-120 -Plan 1J-120 - 1J-120 (wp06) 7,834.67 6,025.00 911.46 126.47 784.99 Pass -Major Risk Plan 1J-120 -Plan 1J-120 L1 - 1J-120 L1 (wp06) 7,834.67 6,025.00 911.46 126.47 784.99 Pass -Major Risk Plan 1 J-120 -Plan 1J-120 L2 - 1J-120 L2 (wp06) 7,834.67 6,025.00 911.46 126.47 784.99 Pass -Major Risk Plan 1J-122 - 1J-122 L1 - 1J-122 L1 (wp03) 8,402.76 6,000.00 1,196.80 124.37 1,072.43 Pass -Major Risk Plan 1J-122 - 1J-122 L2 - 1J-122 L2 (wp03) 8,402.76 6,000.00 1,196.80 124.37 1,072.43 Pass -Major Risk Plan 1J-122 -Plan 1J-122 - 1J-122 (wp04) 8,215.21 5,975.00 1,162.11 123.53 1,038.59 Pass -Major Risk Plan 1J-124 -Plan 1J-124 - 1J-124 (wp02) 8,714.09 6,075.00 1,206.20 129.40 1,076.80 Pass -Major Risk Plan 1J-130 -Plan 1J-130 - 1J-130 (wp02) 11,268.19 7,475.00 464.89 171.43 293.46 Pass -Major Risk Plan 1J-133 - 1J-133 - 1J-133 Intermediate Out of range Plan 1J-158 - 1J-158 - 1J-158 (wp07) Out of range Plan 1J-158 - 1J-158 Lf - 1J-158 L1 (wp07) Out of range Plan 1J-158 - 1J-158 L2 - 1J-158 L2 (wp07) Out of range Plan 1J-160 -Plan 1J-160 - 1J-160 (wp08) Out of range Plan 1J-160 -Plan 1J-160 L1 - 1J-160 L1 (wn081 Out of ranoe CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 2/23/2007 3:52:17PM Page 4 of 5 COMPASS 2003.11 Build 48 ORIGINAL `~°' Halliburton Company $~~i"`.'.~~.~~+~.?~~"~~~~ Cor~ocaP~~l~~ps~ Anticollision Report Sperry C~riiliing Services Company, ConocoPhillips Alaska, Inc. Local Co-ordinate Reference: Well Plan 1J-105 ,Project: Kuparuk River Unit ND Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Reference Site: Kuparuk 1J Pad MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28+81)) Site Error: O.OOft North Reference: True Reference Well: Plan 1J-105 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 2.00 sigma Reference Wellbore 1J-105 L1 Database: Compass 2003.11 j Reference Design: 1 J-105 L1 (wp04} Offset ND Reference: Offset Datum Summary iite Name Offset Well -Wellbore -Design Kuparuk 1J Pad Plan 1J-160 -Plan 1J-160 LL - 1J-160 L2 (wp08) Rig: 1J-103 - 1J-103 - 1J-103 Rig: 1J-103 - 1J-103 L1 - 1J-103 L1 Rig: 1J-103 - 1J-103 L1 P61 - 1J-103 L1 PB1 Rig: 1J-103 - 1J-103 L2 - 1J-103 L2 Rig: 1J-103 - 1J-103PB1 - 1J-103PB1 Rig: 1J-103 - 1J-103PB2 - 1J-103PB2 Rig: 1 J-103 - 1 J-103PB3 - 1 J-103PB3 Reference Offset Centre to Measured Measured Centre Depth Depth Distance 7,524.02 6,700.00 1,233.78 9,833.42 9,000.00 1,298.83 7,453.25 6,600.00 1,247.68 7,449.28 6,600.00 1,214.58 7,524.02 6,700.00 1,233.78 7,524,02 6,700.00 1,233.78 7,524.02 6,700.00 1,233.78 No-Go Allowable Distance Deviation Warning (ft) from Plan (ft) Out of range 106.67 1,127.10 Pass -Major Risk 156.67 1,142.15 Pass -Major Risk 103.81 1,143.87 Pass -Major Risk 103.66 1,110.92 Pass -Major Risk 106.67 1,127.10 Pass -Major Risk 106.67 1,127.10 Pass -Major Risk 106.67 1,127.10 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 2/23/2007 3:52:17PM Page 5 of 5 COMPASS 2003.11 Build 48 1~-105L rillin Hazard~umma (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Oaen Hole / 4-1/2" Liner Lnterval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low / Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo , LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin ~ 1J-105L1 Drilling Hazards Summary 2/23/2007 6:04 PM 20" 94.0#x34" Insulated ConducW r, K-55, sat at+p 80' 10.3/4" x 41n" Wellhead, 5,1100 psi ~/y ~e+(/''~ ~ Tubing, 41n", 12.8#, IBTM, Special Drift to +/• 500' , ~~~~ ~`r" 3.875"DBNipple, forPOasibleSSSV,+/.500' West Sak 7-5/8e1 ~1~,je'QtQI' BskerOllToola GLM,CamcoKBMG,41/2"X1" 1,J.1Q5 6 /,~'~' PIC+IIII~P.~ M GLM,CamcoKBMG,41/2"Jt1" TI'I~Latel'8~ COIIICJ~@tlOn 10.3/4", 888, BTC '' ,'';; . CMD Sliding Sleeve, w/ 3.81."DBNipple, +/• 1 Jt above seals ~•°•° Shoe set @ .3293' MD, 225p'TVD CasingSealboreReceptacle,2orLangm Late ral Entrv Modtale (LEM1 Tubing String Lateral. Entry Module(LEM) With Diverters and Isalatl n 4.112" 12.8#, L•80, IBTM ' D•sand Window ~ Gsftunning roe 8tdng ' Lateral Aaceas DNerter Lateral Isolaton DNerter inats0ed Installed 3.958" ID, 3.833" Drift 7092' MD, 3662' TVD 'D' San at (3A9^ Lat.rel Ddx) (z.6a" ID Mainbore lxlft) $eal 5.112" X 7.518" ZXP Liner Assembly Payzone ECP 4-0n" 11.3# L•80 Slotted "! Call Connector ' 'GS'Profllefor ; ~RunninglRetdeving ~ ,' Top Packer w/ Hold 4.75" Seal OD Liner Every Oih~ Joint (1.00 Length) .; ; I ~ Downs 4.1/2" Guide Shoe -,J ~ ) Seek Pressure Valve ' ~i r~PosHlve LocatMg~ ~ "~ ~"~ - ,. ... ~ (4,80'Length) ' Collet :':I Las Il tb -^"' ' ~ ~ " 41/2"LJnerShoe, 11.6#,L-80 BTC ' rFlrnvfiruSVrWeI t2 ' $ ws~a n 1 „~ 5.11T Tieback Sleeve Set ~ 11521 MD, 3562' TVD ( 6 Lsngth) ~ Lateral quarter I I ;: 4.1n" X 7.5/8" Seal Bores Model'B'HOOK Hanger 3.88"ID &1 n" X 7.5/8" zxP Lln er Top Padkar wl Hold Downs Lateral Entrv Module (LEM1 e bl 5.112" X 7.518" ZXP Liner lop Packer with Hold Downs ---•--, Casing 3edbore Receptacle 4,75"ID OdenBng Profile Automa8c Alignment of LEM Poshive Latching Collet r--'~~ Indicates Correct Location Seal Bore for Lateral laolatlon • 3.88" ID Access Window Positive Lateral Access Vla Thru•Tubing Dlverter. Seal Bora far Lateral Isolation • 3.88" ID IsoleBon Seal Asembly 4.75" Seal OD 3.875" Seal ID Casing S~ Recap c 20' Le Ot 4.1n" bent muleshoe ~ Hydreulla <i Dlawnnect ' t ~ ~ ' ' f Ramp ;:I L; Isolati /M l b ~ Seal As (1.60 Langth) ~ on e n ore ~ sal OD ~ ~~-GS Spear 5 Dlverter Sleeve ~~ , / Lateral Entry Module(LEM) ~,•., t o~ i~ ` (1.69'LengthJ ~roz. .~~ Lateral Isolatlon~ Saals ~~;/ t. B-sandWindow at 7440' MD, 3728' TVD ~` Sand Lateral •Jarsmaybarequhadlnh deviated a deep app"Gagne (6' approx ), d iii 18.6DIvanxlength 18.5'SleaveLanth 9 ~'~ ~ 4.1n" 11 6# L•80 Slotted Payzone ECP Liner Every Other Joint `°~~ , ' 7.5/8" "-• ~~ I, 4dn" Guide Shoe r ~, r .;.~ .._ d =G 41/2" Liner Shoe, 11.6#, L-80 BTC Seal Bores ~°. ~, 5.1/2" Tieback Sleeve Set ~ 11565' MD, 3634' TVD 3.88"ID 4.1 "bent muleshoe 4.112" 12.8# Tubin 3.582" DB p 3.833" DHfY 3.958"ID 3.1n" X 7.5/8" ZXP ~ Mainbore Ddit: 3.BS" Liner Top Packer Mainbore Dnft, wt Isolation sleeve: 2.50" wHh Hold Downs l Seal Assembly Lateral Drift, w/ colt diveHer: 3.OD" / 4.73" Seal OD OD of Diverter andSleeve;+!• 3.89"" ' ~ 'A' Sand Und dating a e~al DNerterandsleeyeLength:+/.,8s' 5.1n" x 7.3/s" Liner Hanger /Packer Assembly at Flex Lodk 41n" 11.8# L•8D Slotted 4dn" EccentHc +/• 7340' MD Liner Hanger Liner Every Other Joint ~Gulda Shoe Casing Sealbore Receptacle, _ f J 4.1/2" Casing Shoe, 11.6#, L•80 BTC 20• Length ,~{ Set (c~ 11724' MD, 3850' TVD '' 75/8" 29.7# Casing, L-80, BTCM, Sat ®6ekx NUgasa 20a37111sdecumem rrwy not be reprotlueed ortllealbubd, In whoN ork p~d,M erry tormwbY at1~8815'MD, 3850'TVD (84 tleg) °'"sr"" a,.ama aa: re mina Nedronk or macbanlesl, kclutling paolooopyMg, reCOrtll~,or by airy lnfomudbn sMrega and Watt Sek 7.39"7d•Meral COmMalbn•MJeelor ' Irievel eyetem now known orhxeNxlnvanlad, wphoul wdaen pomiMabn rrom Baker liughee MC. I$ no. p. o A Fab ry29 2007 •••"•,-'• M rae K k "•naon n ~Pa ' .: op n s r ~tl~l IprnPnt SDeGIT fleat1011S 4-1/2" X 7.518'" HOOK Hanger Mainbore Odit 5.32" Mainbore Drift, with diverter: 4,g3" Lateral Ddit, no dNertar or LEM: 3.88" .Lateral Drift, w/ dlverter, no LEM: 3.88" LaterallMalnbore Diverter OD: 6.75" 4.712" Lateral Entry Module • • ~ ~ T~2AoiS1dIIT~'AI. I.ETTEIS CH~CKY.IST ~l/LL r alvlE ~/2 GC /,I-~O~ L PT~~ Zak - ~2 g ®evelopment / Service Exploratory Stratigraphic Vest Yon-Conventional Wett Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK j ADD-ONS TEXT FOR APPROVAL LETTER ,' Vb'HAT ; (OPTIONS) APPLIES ~ ~ I MliLTI LATERAL ~ The permit is for a new wel~ore~ment of existing ~ well ~~ ~"~ ~ j ~ ~ (If last two digits in I Permit No. LD?' 02~ API No. 50-G~ - i API number are ! --~ ' between 60-69) Production should continue to be reported as a function of the ' ~ original API number stated above. PILOT HOLE [n accordance with 20 AAC 25.005(f), all records, data and logs !acquired for the pilot hole must be clearly differentiated in both i ;welt name ( Pf-n and API number ' (SO- - -_~ from records, data and togs ~ ~ acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 125.45. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing j i j exception. assumes the I liability of any protest to the spacing exception that may occur. DRY D[TCH ~ At[ dry ditch sample sets submitted to the Commission must be in i SAMPLE I no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals j through target zones. ' ;Please note the following, special condition of this permit: Non-Conventional i production or production testing of coal bed methane is not allowed i Well ~ for (name of welU until after (Com~anv Name) has designed and I implemented a water well testing program to provide baseline data j on water quality and quantity. lCom~any Name) must contact the 'Commission to obtain advance approval of such water well testing program. I Rev: l '25106 C:`jody~transmittal_checklist r 11!', m N rn o a ~: N ~ o ~, p ~ ~ ~ ~,, a. n c o ,~ : ~ ~: - , o, ~ ~ ~ ~ ~ ~ ~ ~ a ~ ~ ~ 3 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ o, ~ ~ 3 3' I I ~ a, ~, o ; •o ~ i ~ O ~ N N, ~ .~ Y ~ r d L 'a. _, 4 v 3 0 wll to ~ u d a. d, +. ~ m. ~ .N cn, ~ - a o °~ 3, co -o. 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E °, a. c c E' ~ ~ o M' c c in, F- c o otS m ~= c w l ar °: N r o. c c ~ ~ o o a` ~ o a m. ~. 3' ~ ., ~. c a~ rn ~ ,~, o Q I ~ ~ a v m. ~ N o o Q o° rn °, U .4 n a m .~ g y D. °- ~ '3 i o, y m ~' ~ •y 4. I c4~ a~ o c c o c, ai c a o m c a~ ~ Q ~~ m N, I a o, ~ o', •x m •~ i~ ~ o, °~ $ >, o ~ ~ ~.- a' m m o' Y ~ o' o' o o E io m ~ i >~ m ~ ~ g E o, v a~' ~~ o o a~ c a~ a .,- 2 0 E ~' 3 a~ a~ r m. 3 v a~. .~ E Y Qi °? o~ m m ~ m. m' ~ s r .Q ~ ~ °, N a. ~ ~ c. m o, ~.- m •- a~ rn o ~ °' a 3' ~ o ° 3' c E m. c, a. m. ~ ~ a a, E ~ a~~ c ~ M ,~ t o, o c >, ~ ~ a ~, N N; ~~ o, a ~ 3 •3 ~ ~ m .. o i ~ ~. 'v °~ o' m ~ °v °' o' ~' ~ a a ~ ~ o. 3. ~' ~ a~ o w U °o a o c, +c. v =o. > m. .Q a s w ~ o m. o, m e a. o ~, Z n. a m. o m ~; v. o m m o m~ `o 0 0~ o o Y° o o N' ~° E' a~ o E r o' a~ a .~ N' c' -~I r. ~ a~, a' a ~ o o a ti oil a c '~ .v, ~. °- ° a..°' ~~ - ~~ o °'; a `~ ~~~ c v N~ " ~ ~~~ a °~ c .°c °tS =i c~ ca. E. 0 0 o rn aY ~ p. .N N p ~ ~, m vi 'a m m ia' ~ m' o ~ ai >. 3 2 v' ~. 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O O O N M st ~fi (O f~ W O O N M I to (D I~ M O (•, U O N M I t!7 CO Imo- 00 O r ~ ~ ~ ~ ~ ~ ~ ~ r ~ N N N N N N N N N N M M M M M M M_ M M M ..._.___.___- __. ___-_- --.____ __._ ______ ___. __._ .__..__- __.. ___ -_ ._... ___- t_~__-.._. ___. _.. U I ~ ^ .. c m °o m °o a; °o c C C +'' N r+ N U p ~ a0 O O O ~ N ~', ~ °O rn O 1_ Q. Or' w N C M~ ~I~ N N •~ /' C O W D E G~ ~ 2 W 1` O Q~ U 4. Q Q cn w Q F- ? U, Q fn • Well History File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 1J105L1o04122007SSN.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Jun 25 20:40:00 2007 Reel Header Service name ............. LISTPE Date . ................... 07/06/25 Origin ................... STS Reel Name. .... ........ UNKNOWN continuation Number...... 01 Previous Reel Name....... UNKNOWN Comments ................. STS LIS Tape Header Service name ............. LISTPE Date . ................... 07/06/25 Origin ................... STS Tape Name...... ........ UNKNOWN continuation Number...... 01 Previous Tape Name....... UNKNOWN Comments ................. STS LIS Physical EOF comment Record TAPE HEADER west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: writing Library. Scientific Technical services writing Library. scientific Technical services 1J-105 L1 500292334660 ConocoPhillips Alaska, Inc. Sperry Drilling Services 25-JUN-07 MWD RUN 2 MWD RUN 3 MWD RUN 8 w-0004912996 w-0004912996 w-0004912996 S. GREENE S. GREENE R. REPLOGLE G. WHITLOCK G. WHITLOCK D. GLADDEN MWD RUN 9 MWD RUN 10 w-0004912996 w-0004912996 R. REPLOGLE R. REPLOGLE D. GLADDEN D. GLADDEN 35 11N l0E 2186 2432 Page 1 • ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1J105L1004122007SSN.txt 109.00 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 3387.0 2ND STRING 6.750 7.625 7707.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 7707' MD/3701`TVD, WITHIN THE RUN 3 INTERVAL OF THE 1J-105 WELLBORE. THE WHIP- STOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 8. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,9,10 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUN 9 ALSO INCLUDED AT- BIT INCLINATION (ABI), AND MWD RUN 10 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-3,8-10 REPRESENT WELL 1J-105 L1 WITH API#: 50-029-23346-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11571'MD/3660'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). Page 2 u 17105L1o041220075SN.txt SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name... .......STSLIB.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 comment Record FILE HEADER. FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPM RPX FET RPD RPS ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 3351.0 3371.0 3371.0 3371.0 3371.0 3371.0 3396.5 STOP DEPTH 11514.0 11521.0 11521.0 11521.0 11521.0 11521.0 11571.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP 2 3351.0 3 7071.5 8 7707.5 9 7735.0 10 8811.0 REMARKS: MERGED MAIN PASS. MERGE BASE 7071.0 7707.0 7735.0 8811.0 11571.0 Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Log~iny Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 Page 3 17105L1o041220075SN.txt RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3351 11571 7461 16441 3351 11571 RPD MWD OHMM 3.64 2000 35.0858 16301 3371 11521 RPM MWD OHMM 4.31 2000 30.2348 16301 3371 11521 RPS MWD OHMM 0.46 2000 29.1264 16301 3371 11521 RPX MWD OHMM 0.84 1511.84 28.8288 16301 3371 11521 FET MWD HOUR 0.19 284.28 1.42065 16301 3371 11521 GR MWD API 19.07 180.45 65.1464 16327 3351 11514 RoP MwD FT/H 0.29 1464.34 178.71 16350 3396.5 11571 First Reading For Entire File..........3351 Last Reading For Entire File...........11571 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLI6.002 service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3351.0 7071.0 RPD 3371.0 7071.0 FET 3371.0 7071.0 RPS 3371.0 7071.0 RPx 3371.0 7071.0 RPM 3371.0 7071.0 Page 4 ! ~ 17105L1o04122007SSN.txt ROP 3396.5 7071.0 LOG HEADER DATA DATE LOGGED: 27-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7071.0 TOP LOG INTERVAL (FT): 3396.0 BOTTOM LOG INTERVAL (FT): 7071.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 65.2 MAXIMUM ANGLE: 82.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 134745 EWR4 ELECTROMAG. RESIS. 4 121079 .BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3387.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 58.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 7.000 63.0 MUD AT MAX CIRCULATING TERMPERATURE: 5.070 89.6 MUD FILTRATE AT MT: 6.500 63.0 MUD CAKE AT MT: 2.800 63.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units .. .. ..... Datum Specification Block sub-type...0 Page 5 • 17105L1004122007SSN.txt Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 RoP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3351 7071 5211 7441 3351 7071 RPD MWD020 OHMM 3.64 2000 21.2179 7401 3371 7071 RPM MWD020 OHMM 4.31 2000 15.4362 740.1 3371 7071 RPS MWD020 OHMM 0.46 201.6 13.1711 7401 3371 7071 RPX MWD020 OHMM 0.84 174.92 12.5591 7401 3371 7071 FET MWD020 HOUR 0.19 136.62 1.62178 7401 3371 7071 GR MWD020 API 19.07 161.75 63.5015 7441 3351 7071 ROP MWD020 FT/H 0.83 706.16 184.483 7350 3396.5 7071 First Reading For Entire File..........3351 Last Reading For Entire File...........7071 File Trailer Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLiB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 7071.5 7707.0 ROP 7071.5 7707.0 GR 7071.5 7707.0 Page 6 • i 17105L1o04122007SSN.txt RPD 7071.5 7707.0 RPS 7071.5 7707.0 RPX 7071.5 7707.0 RPM 7071.5 7707.0 LOG HEADER DATA DATE LOGGED: 29-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7707.0 TOP LOG INTERVAL (FT): 7071.0 BOTTOM LOG INTERVAL (FT): 7707.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 77.5 MAXIMUM ANGLE: 89.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 134745 EWR4 ELECTROMAG. RESIS. 4 121079 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3387.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (s): 58.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 7.000 63.0 MUD AT MAX CIRCULATING TERMPERATURE: 5.070 89.6 MUD FILTRATE AT MT: 6.500 63.0 MUD CAKE AT MT: 2.800 63.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ..,.........60 .lIN Max frames per record .............undefined Absent value ......................-999 Page 7 • 17105L1004122007SSN.txt Depth Units .. .. ..... Datum specificat ion Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MwD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min MdX Mean Nsam Reading Reading DEPT FT 7071.5 7707 7389.25 1272 7071.5 7707 RPD MWD030 OHMM 5.2 86.3 16.8871 1272 7071.5 7707 RPM MWD030 oHMM 4.75 80.67 15.2812 1272 7071.5 7707 RPS MWD030 OHMM 4.56 82.51 14.8416 1272 7071.5 7707 RPX MWD030 OHMM 4.52 85.08 14.0876 1272 7071.5 7707 FET MWD030 HOUR 0.34 23.5 0.9968 1272 7071.5 7707 GR MWD030 API 53.11 111.35 84.3551 1272 7071.5 7707 ROP MWD030 FT/H 0.29 1464.34 182.628 1272 7071.5 7707 First Reading For Entire File..........7071.5 Last Reading For Entire File...........7707 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EoF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH Page 8 • 1)105L1o04122007SSN.txt ROP 7707.5 7735.0 LOG HEADER DATA DATE LOGGED: 09-APR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7735.0 TOP LOG INTERVAL (FT): 7707.0 BOTTOM LOG INTERVAL (FT): 7735.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .O TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7707.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 48.0 MUD PH: 1.6 MUD CHLORIDES (PPM): 75000 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 88.9 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ........0 Data Specification Block Type.....0 Logging Direction............ ....Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 Page 9 • 1]105L1o04122007SSN.txt ROP MWD080 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7707.5 7735 7721.25 56 7707.5 7735 ROP MWD080 FT/H 0.38 26.38 8.14571 56 7707.5 7735 First Reading For Entire File..........7707.5 Last Reading For Entire File...........7735 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.005 Physical EOF File Header service name... .......STSLI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit.run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7707.5 8746.5 RPx 7707.5 8753.5 RPS 7707.5 8753.5 FET 7707.5 8811.0 RPM 7707.5 8753.5 RPD 7707.5 8753.5 ROP 7735.5 8811.0 LOG HEADER DATA DATE LOGGED: 10-APR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8811.0 TOP LOG INTERVAL (FT): 7735.0 Page 10 i • 17105L1o04122007SSN.txt BOTTOM LOG INTERVAL (FT): 8811.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.8 MAXIMUM ANGLE: 96,2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 EWR4 Electromag Resis. 4 159436. ABI AT-BIT INCLINATION 149845 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILtER'S CASING DEPTH (FT): 7707.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 67.0 MUD PH: 2.8 MUD CHLORIDES (PPM): 31000 FLUID LOSS (C3): $.$ RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 96.8 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name Service Order units, size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD090 OHMM 4 1 68 4 2 RPM MWD090 OHMM 4 1 68 8 3 RPS MWD090 OHMM 4 1 68 12 4 RPX MWD090 OHMM 4 1 68 16 5 FET MWD090 HOUR 4 1 68 20 6 GR MWD090 API 4 1 68 24 7 ROP MWD090 FT/H 4 1 68 28 8 Page 11 • • 17105L1o041220075SN.txt First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7707.5 8811 8259.25 2208 7707.5 8811 RPD MWD090 OHMM 11.2 593.12 46.2257 2093 7707.5 8753.5 RPM MWD090 OHMM 10.66 90.77 42.0278 2093 7707.5 8753.5 RPS MWD090 OHMM 9.98 2000 42.3788 2093 7707.5 8753.5 RPX MWD090 OHMM 10.18 1511.84 42.6829 2093 7707.5 8753.5 FET MWD090 HOUR 0.35 284.28 2.70269 2208 7707.5 8811 GR MWD090 API 34.98 180.45 63.0312 2079 7707.5 8746.5 ROP MWD090 FT/H 3.95 331.71 194.858 2152 7735.5 8811 First Reading For Entire File..........7707 Last Reading For Entire File...........8811 File Trailer Service name... .......STSLI6.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLI6.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE GR RPD FET RPM RPX RPS ROP LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 8747.0 8754.0 8754.0 8754.0 8754.0 8754.0 8811.5 SURFACE SOFTWARE VERSION: STOP DEPTH 11514.0 11521.0 11521.0 11521.0 11521.0 11521.0 11571.0 Page 12 12-APR-07 Insite • • 1.7105L1o04122007SSN.txt DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11571.0 TOP LOG INTERVAL (FT): 8811.0 BOTTOM LOG INTERVAL (FT): 11571.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (s): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logyin Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service Order DEPT RPD MWD100 RPM MWD100 RPS MWD100 RPX MWD100 FET MWD100 Units Size Nsam FT 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 OHMM 4 1 HOUR 4 1 86.0 92.5 TOOL NUMBER 203301 159436 6.750 7707.0 Mineral oil Base 8.50 68.0 1.8 34500. 9.2 .000 .0 .000 111.2 .000 .0 .000 .0 Rep code offset channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 Page 13 • 17105L1o041220075SN.txt GR MWD100 API 4 1 68 24 7 ROP MWD100 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 8747 11571 10159 5649 8747 11571 RPD MWD100 OHMM 13.38 120.49 53.5988 5535 8754 11521 RPM MWD100 OHMM 9.4 103.12 48.9995 5535 8754 11521 RPS MWD100 OHMM 7.81 122.82 48.7322 5535 8754 11521 RPX MWD100 OHMM 7.81 122.82 48.7322 5535 8754 11521 FET MWD100 HOUR 0.2 13.54 0.984397 5535 8754 11521 GR MWD100 API 32.68 116.07 63.738 5535 8747 11514 ROP MWD100 FT/H 1.63 339.86 165.556 5520 8811.5 11571 First Reading For Entire File..........8747 Last Reading For Entire File...........11571 File Trailer Service name... .......STSLIB.006 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/25 Maximum Physical Record,.65535 File Type ................Lo Next File Name.........,.STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/06/25 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN comments.... ..............STS LIS writing Library. scient ific Techni cal services Reel Trailer Service name .............LISTPE Date . ...................07/06/25 Ori9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......,01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scient ific Technical Services Physical EOF Physical EOF Page 14 End Of LIS File n 17105L1o04122007SSN.txt Page 15
